HomeMy WebLinkAbout2022-01-11; Municipal Water District; ; Agreements with San Diego Gas & Electric and the Clean Energy Alliance allowing the Carlsbad Municipal Water District to Transfer Renewable Energy Generation Credits to t Meeting Date: Jan. 11, 2022
To: President and Board Members
From: Scott Chadwick, Executive Manager
Staff Contact: Shoshana Aguilar, Senior Management Analyst
shoshana.aguilar@carlsbadca.gov, 760-814-0241
Dave Padilla, District Engineer
dave.padilla@carlsbadca.gov, 760-603-7356
Subject: Agreements with San Diego Gas & Electric and the Clean Energy Alliance
allowing the Carlsbad Municipal Water District to Transfer Renewable
Energy Generation Credits to the Alliance
Districts: All
Recommended Action
Adopt a resolution authorizing the Executive Manager or designee to execute agreements with
the Clean Energy Alliance, San Diego Gas & Electric, Western Renewable Energy Generation
Information System and the California Energy Commission in order to transfer renewable
energy generation credits produced by the Carlsbad Municipal Water District to the Clean
Energy Alliance.
Executive Summary
The CMWD has been operating a hydroelectric turbine generator at the Maerkle Reservoir site
since 2015. This generator is connected to SDG&E’s electrical system in accordance with the
SDG&E program in which the district receives credits on its bills for the renewable energy it
generates and sends into the system. It uses the force of potable water moving through a
conduit to spin the rotator shaft of a generator that converts this mechanical energy into clean,
renewable energy, which SDG&E credits back to the CMWD to offset electrical demands at
other CMWD sites. Because of the CMWD transition to the Clean Energy Alliance as its energy
provider, the Executive Manager or designee needs to execute a series of related agreements
that authorize the CMWD to sell energy to the CEA and receive energy credits from the CEA at
the Maerkle Reservoir and other metered locations.
Discussion
On April 13, 2021, the City Council and the CMWD Board of Directors voted to purchase electric
service from the Clean Energy Alliance, including electric service for the CMWD accounts. The
accompanying Resolution No. 1650 and the CMWD ordinances do not expressly authorize the
Executive Manager to execute the agreements necessary to transition the renewable energy
credits (Exhibit 2).
The Clean Energy Alliance’s energy credit transfer program agreement (Exhibit 3) prohibits its
governmental customers, such as the CMWD, from selling renewable energy to any other
Jan. 11, 2022 Item #8 Page 1 of 22
electrical corporation during the term of the agreement and does not require the generation of
a minimum amount of electricity. In these times of drought, it must also be noted that in 2013,
the San Diego County Water Authority informed the CMWD that it could not guarantee to
provide the specific water pressure needed to generate electricity at the Maerkle Reservoir.
However, the hydroelectric generator has operated with enough pressure since its completion
in 2015.
Staff request that the CMWD Board of Directors authorize the Executive Manager or designee
to execute the following:
1. The energy credit transfer agreement with the CEA to accept clean energy from CMWD
and credit other CMWD accounts (Exhibit 3)
2. Any documents or agreements needed to terminate the energy credit transfer
agreement with SDG&E, including a new generating facility interconnection agreement
for energy export (Exhibit 4)
3. The net energy metering agreement with SDG&E to receive credit for electricity
transmission produced by the hydroelectric generator
4. Any documents or agreements to receive facility certification from the California Energy
Commission for eligibility under the SDG&E net energy metering program
5. All documents and agreements to list the hydroelectric facility with the Western
Renewable Energy Generation Information System, which is needed to qualify for
California Energy Commission certification
6. Other documents and agreements to maximize credits for the hydroelectric generator,
which provides a local source of clean renewable energy and a savings for the CMWD
ratepayers
Staff recommend that the CWMD Board of Directors authorize the Executive Manager or
designee to execute these agreements necessary to transfer to the CEA’s energy credit transfer
program to continue to receive renewable energy credits produced by the hydroelectric
generator.
Options
Staff provide the following options for the CMWD Board of Directors’ consideration:
1. Authorize the Executive Manager or designee to execute agreements with the CEA,
SDG&E, Western Renewable Energy Generation Information System and the California
Energy Commission to transition the CMWD hydroelectric turbine generator at the
Maerkle Reservoir from SDG&E’s renewable energy program to the CEA
Pros
• The CMWD will receive credit from SDG&E for clean energy produced since the
effective date of transfer to the CEA as the energy provider on June 18, 2021 and
will apply that credit to offset the energy demands at the Maerkle Reservoir and
four other sites
• The CMWD will continue to produce clean, renewable energy, reducing its
demand for electricity produced by non-renewable energy sources
Cons
• None identified
Jan. 11, 2022 Item #8 Page 2 of 22
2. Do not authorize the Executive Manager or designee to execute agreements to
transition the CMWD hydroelectric turbine generator at the Maerkle Reservoir from
SDG&E’s renewable energy program to the CEA
Pros
• None identified
Cons
• The CMWD will forfeit renewable energy credits from the SDG&E produced since
June 18, 2021
• The CMWD will not receive renewable energy credits from the CEA
• Ratepayers will bear the costs to purchase electricity which would have been
offset by clean energy produced by the hydroelectric generator
• Energy from non-renewable sources will be used to produce electricity, resulting
in more greenhouse gas emissions
Fiscal Analysis
The hydroelectric generator produced approximately $32,000 of credits per year with the
SDG&E program. Staff anticipate a similar credit amount with the CEA program. This credit
offsets electricity demands at the Maerkle Reservoir and other CMWD accounts designated by
the CMWD, thereby reducing the budget outlay for electricity each year.
Next Steps
Staff will execute the agreements listed above to transfer from the SDG&E’s energy credit
transfer program to the CEA’s energy credit transfer program to continue to receive credits for
clean energy produced by the CMWD’s hydroelectric generator.
Environmental Evaluation
This action does not constitute a “project” within the meaning of the California Environmental
Quality Act under Public Resources Code section 21065 in that it has no potential to cause
either a direct physical change in the environment or a reasonably foreseeable indirect physical
change in the environment and therefore does not require environmental review.
Public Notification
Public notice of this item was posted in keeping with the Ralph M. Brown Act and it was
available for public viewing and review at least 72 hours before the scheduled meeting date.
Exhibits
1. CMWD Board resolution
2. April 13, 2021, staff report Clean Energy Alliance Product Selection for City of Carlsbad,
Carlsbad Public Financing Authority and Carlsbad Municipal Water District Electric
Service Accounts
3. Clean Energy Alliance energy credit transfer agreement
4. SDG&E Generating Facility Interconnection Agreement
5. Appendices A-B to Exhibit 4 – SDG&E Generating Facility Interconnection Agreement (on
file with the City Clerk’s Office)
Jan. 11, 2022 Item #8 Page 3 of 22
RESOLUTION NO. 1666
A RESOLUTION OF THE BOARD OF DIRECTORS OF THE CARLSBAD
MUNICIPAL WATER DISTRICT, AUTHORIZING THE EXECUTIVE MANAGER OR
DESIGNEE TO EXECUTE AGREEMENTS WITH VARIOUS ENTITIES IN ORDER TO
TRANSFER RENEWABLE ENERGY GENERATION CREDITS PRODUCED BY THE
CARLSBAD MUNICIPAL WATER DISTRICT TO THE CLEAN ENERGY ALLIANCE
WHEREAS, the Carlsbad Municipal Water District (CMWD) operates a hydroelectric turbine
generator at the Maerkle Reservoir that produces clean renewable energy and is connected to the San
Diego Gas & Electric (SDG&E) electrical system; and
WHEREAS, surplus energy produced was previously credited by the SDG&E to other CMWD
electric meter accounts; and
WHEREAS, on April 13, 2021, the City Council and the CMWD Board of Directors approved the
purchase of electricity from the Clean Energy Alliance (CEA) for all accounts in the CEA's service area,
and the SDG&E recognizes such purchase effective on June 18, 2021; and
WHEREAS, staff must execute a series of agreements and related documents to transfer from
SDG&E's renewable energy credit program to the CEA's program.
NOW, THEREFORE, BE IT RESOLVED by the CMWD Board of Directors of the City of Carlsbad,
California, as follows:
1.That the above recitations are true and correct.
2.That the CMWD Board of Directors hereby authorizes the Executive Manager or
designee to execute the following agreements and related documents, with the General
Counsel's prior review and approval as to form, to transfer from SDG&E's Renewable
Energy Self-Generation Bill Credit Transfer (RES-BCT) program to the CEA's RES-BCT
program:
a.The RES-BCT agreement with the CEA to accept clean energy and credit other CMWD
accounts.
b.Any documents or agreements needed to terminate the RES-BCT agreement with
SDG&E including a new Generating Facility Interconnection Agreement for energy
export.
c.The Net Energy Metering (NEM) agreement with SDG&E to receive credit for
electricity transmission produced by the hydroelectric generator.
Jan. 11, 2022 Item #8 Page 4 of 22
d.Any documents or agreements to receive facility certification from the California
Energy Commission (CEC) for eligibility under the SDG&E NEM program.
e.All documents and agreements to list the hydroelectric facility with the Western
Renewable Energy Generation Information System, which is needed to qualify for
CEC certification.
f.Any other related documents or agreements needed to transition the CMWD
hydroelectric turbine generator from SDG&E's renewable energy program to the
CEA.
PASSED, APPROVED AND ADOPTED at a Special Meeting of the Board of Directors of the
Carlsbad Municipal Water District of the City of Carlsbad on the 11th day of January 2022, by the
following vote, to wit:
AYES: Hall, Blackburn, Bhat-Patel, Acosta, Norby.
NAYS: None.
ABSENT: None.
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Jan. 11, 2022 Item #8 Page 5 of 22
Exhibit 2
April 13, 2021, staff report Clean Energy Alliance Product
Selection for City of Carlsbad, Carlsbad Public Financing
Authority and Carlsbad Municipal Water District Electric
Service Accounts
(on file in the Office of the City Clerk)
Jan. 11, 2022 Item #8 Page 6 of 22
Adopted 3/25/21 1
RENEWABLE ENERGY SELF-GENERATION
BILL CREDIT TRANSFER PROGRAM (CEA-RESBCT)
TERMS AND CONDITIONS OF SERVICE
A.PURPOSE
The purpose of the Clean Energy Alliance Renewable Energy Self-Generation Bill Credit Transfer
Program (CEA-RESBCT) Program terms & conditions (T&C) is to provide a process for how
eligible governmental customers are enrolled in CEA-RESBCT and how the program is
administered.
B.APPLICABILITY
The CEA-RESBCT program is available to local government CEA customers with an eligible
renewable electrical generating facility (defined in Section D Definitions) within CEA service
territory. Eligible customers who take service under the CEA-RESBCT program shall not be
eligible for any other program that requires an electrical corporation to purchase generation
from the customer’s eligible renewable generation facility enrolled in this program.
C.TERRITORY
Applicable in the CEA service area.
D.DEFINITIONS
ELIGIBLE RENEWABLE ELECTRICAL GENERATION FACILITY: A facility that generates
electricity from a renewable source listed in paragraph (1) of subdivision (a) of Section
25741 of the Public Resources Code. These sources are biomass, solar thermal,
photovoltaic, wind, geothermal, fuel cells using renewable fuels, small hydroelectric
generation (only if facility will not cause an adverse impact on instream beneficial uses or
cause a change in the volume or timing of streamflow), digester gas, municipal solid waste
conversion, landfill gas, ocean wave, ocean thermal, or tidal current, and any additions or
enhancements to the facility using that technology.
The eligible renewable electrical generation facility must also meet all of the following
criteria:
a. is a generation facility with a generation capacity of not more than five
megawatts;
b.is located within the geographical boundaries of Clean Energy Alliance service
territory;
c.is owned, operated or located on property under the control of the local
government customer. Under certain circumstances when a local government
customer is a lessee in a lease agreement, leased property within the
EXHIBIT 3
Jan. 11, 2022 Item #8 Page 7 of 22
CEA RESBCT Terms & Conditions
Adopted March 25, 2021
2
geographical boundaries of the local government customer shall be considered
under the control of the local government customer;
d. is sized to offset all or a part of the electrical load of the Generating account; and
e. is interconnected and operates in parallel with SDG&E’s transmission and
distribution systems.
Eligible generators utilized to receive service under the terms of this rate schedule shall be
in compliance with SDG&E’s Electric Rule 21, Interconnection Standards for Non-Utility
Owned Generation. The local government customer shall have installed a meter capable of
recording net generation output in 15-minute intervals to interconnect with the generator,
and which must be approved by SDG&E. The Local Government must execute and comply
with the applicable SDG&E Interconnection Agreement, SDG&E tariffs, and any other
regulations and laws governing the interconnection of the Eligible Renewable Generating
Facility.
Eligible generators participating on this schedule are not eligible for service under CEA’s Net
Energy Metering program.
LOCAL GOVERNMENT: A city, county, (whether general law or chartered, city and county)
special district, school district political subdivision, other local public agency Per PU Code §
2830,or a joint powers authority formed pursuant to the Joint Exercise of Powers Act
(Chapter 5 (commencing with Section 6500) of Division 7 of Title 1 of the Government Code)
that has as members public agencies located with the CEA territory, but shall not mean the
state or any agency or department of the state, other than an individual campus of the
University of California or the California State University.
GENERATING ACCOUNT: A Generating Account is the SDG&E electricity billing account at
the location of the eligible renewable generation facility served under a time-of-use (TOU)
rate schedule with bills rendered in the name of the local government customer.
Generating accounts will be allowed to take service under Schedule DG-R.
BENEFITING ACCOUNT: A Benefiting Account is a service account, or more than one service
account, located within Clean Energy Alliance service territory, in the name of the local
government agency and served under a time-of-use (TOU) rate schedule. The number of
Benefiting Accounts is limited to 50. Benefiting Accounts will not automatically be eligible
to receive service under Schedule DG-R, unless the Benefiting Account is already a host
facility to a distributed generation project.
POWER DELIVERED: The Power Delivered is the metered output measured in kilowatt-
hours, exported to the grid, as recorded by the net generator output meter and validated by
the SDG&E billing processes during the specific billing period.
Jan. 11, 2022 Item #8 Page 8 of 22
CEA RESBCT Terms & Conditions
Adopted March 25, 2021
3
E. PROGRAM
In order to initiate service under this program, the local government customer must submit a
CEA-RESBCT Allocation Request Form (Exhibit A - Request Form). The Request Form designates
how the credits from the Generating Account will be allocated amongst the customer’s
Benefiting Accounts. The customer may submit an updated Form within a Relevant Period in
the event there is a change in eligibility of a Benefiting Account (such as account closure) and
which must be received by CEA at least 30 days prior to when the reallocation of Generating
Account credits is to be effective. Local Government customers requesting to terminate CEA-
RESBCT service shall provide written notice to CEA, which must be received at least 30 days in
advance of the termination date.
Only the energy charge rate component of the Generating Account’s CEA service charge shall
be used in the calculation of credits to be applied under this program. Credits will be calculated
by multiplying the Power Delivered by the appropriate CEA TOU rate in effect at the time the
Power Delivered was produced and exported to the grid. Credits will be applied to Benefiting
Accounts based on the Request Form. CEA will not compensate a local government for
electricity generated from an eligible renewable facility in excess of the bill credits applied to
the designated benefiting account.
A Benefiting Account Relevant Period is a twelve-month period, or portion thereof,
corresponding to that of the Generating Account Relevant Period. However, due to possible
differences in billing (and meter read) cycles, the Benefiting Account Relevant Period may lag in
time behind the Generating Account Relevant Period by any number of days up to one full
billing cycle.
For purposes of applying Bill Credit, the Bill Credit Relevant Period ends at the same time as the
Benefiting Account Relevant Period (noted in the Request Form) that is lagging the most behind
the Generating Account Relevant Period, up to one Billing Cycle.
For a new Benefiting Account Credit arrangement, the initial Benefiting Account Relevant
Period for a Benefiting Account that does not have the same Billing Cycle as the Generating
Account, will start its Relevant Period at the start of its first full billing cycle that falls after that
of the Generating Account. During the less-than-one-full billing-cycle period between the start
of the Generating Account’s Relevant Period and that of the Benefiting Account, no bill credit
will be applied to that Benefiting Account’s usage. The Benefiting Account’s normal Relevant
Period will consist of a twelve-month period, starting with the first full bill cycle.
Credits will be applied to the Generating Account and the Benefiting Account(s) based on whole
percentages provided by the Local Government on the Request Form. The process of allocating
credits shall commence on the effective date of the Request Form and shall continue for 12
consecutive billing periods (Relevant Period). Credits remaining at the end of the Relevant
Period will be applied toward remaining eligible CEA electric generation charges during the
Jan. 11, 2022 Item #8 Page 9 of 22
CEA RESBCT Terms & Conditions
Adopted March 25, 2021
4
Relevant Period. At the end of the Relevant Period, any remaining credit shall be reset to zero.
Each subsequent 12-month period of service under this schedule shall be considered a new
Relevant Period. The Local Government will not be compensated for electricity generated from
an eligible renewable facility in excess of the bill credits applied to the Benefiting Accounts.
The Local Government is responsible for all charges due on the Benefiting Account bill in excess
of the Generating Account applied credits.
Jan. 11, 2022 Item #8 Page 10 of 22
CEA RESBCT Terms & Conditions
Adopted March 25, 2021
5
EXHIBIT A
CLEAN ENERGY ALLIANCE
RENEWABLE ENERGY SELF-GENERATION BILL CREDIT TRANSFER REQUEST FORM
DATE: ______________________________
LOCAL GOVERNMENT CUSTOMER NAME: ______________________________________________
MAILING ADDRESS: ________________________________________________________________
CONTACT NAME: __________________________________________________________________
CONTACT PHONE NUMBER: _________________________________________________________
CONTACT EMAIL ADDRESS: __________________________________________________________
REQUESTED EFFECTIVE DATE: ________________________________________________________
_________ Check here if this is an initial request
__________ Check here if this is an update to an existing CEA-RESBCT Request Form
During the 12-month Relevant Period, updates to an existing CEA-RESBCT Request Form will
only be considered in the event of a change in eligibility of a Benefiting Account, such as
account closure. Changes to allocation in subsequent 12-month Relevant Periods must be
received at least 30 days prior to the start of the next Relevant Period.
________________________________________ ______________________________
Signature Date
Jan. 11, 2022 Item #8 Page 11 of 22
CEA RESBCT Terms & Conditions
Adopted March 25, 2021
6
Generating Account Information.
Credits available as determined by the rates and terms of the CEA-RESBCT program are to be
allocated in the following whole percentages to the following authorized Benefiting Accounts
(located within CEA service territory boundaries).
ACCOUNT
NUMBER
ACCOUNT NAME SERVICE ADDRESS SERVICE DELIVERY
POINT
PERCENTAGE
Benefiting Account Information.
Credits available from the Generating Account, as determined by the rates and terms of the
CEA-RESBCT program, are to be allocated to the Benefiting Accounts within CEA territory, in the
following whole percentages. Percentages may not sum to more than 100%.
ACCOUNT
NUMBER
ACCOUNT NAME SERVICE ADDRESS SERVICE DELIVERY
POINT
PERCENTAGE
Additional sheets may be attached as needed for additional Benefiting Account and
percentages.
Jan. 11, 2022 Item #8 Page 12 of 22
EXHIBIT 4
1 142-0545 (06/06)
GENERATING FACILITY INTERCONNECTION AGREEMENT
(CONTINUOUS EXPORT)
This Generating Facility Interconnection Agreement (“GFIA”) is entered into by and between (“Electricity Producer” or “EP”) and San Diego Gas & Electric Company (“SDG&E”). The EP and SDG&E are sometimes also referred to in this GFIA jointly as “Parties” or individually as “Party.”
In consideration of the mutual promises and obligations stated in this GFIA and its attachments, the Parties agree as follows:
1. SCOPE AND PURPOSE
This GFIA provides for EP to interconnect and operate a Generating Facility (described below) in parallel with SDG&E’s Distribution System to 1) deliver to SDG&E on a non-compensated basis or 2) sell energy produced by such Generating Facility directly to SDG&E pursuant to
. N/A dated N/A .
2. SUMMARY AND DESCRIPTION OF EP’s GENERATING FACILITY
2.1 A description of the Generating Facility, including a summary of its significant
components and a single-line diagram showing the general arrangement of how EP’s
Generating Facility and loads are interconnected with SDG&E’s Distribution System, is
attached to and made a part of this GFIA as Appendix A.
2.2 Generating Facility identification number: . (Assigned by SDG&E)
2.3 SDG&E’s customer electric service account number: (Assigned by SDG&E)
2.4 Name and address used by SDG&E to locate the electric service account used to
interconnect the Generating Facility with SDG&E’s Distribution System:
CITY OF CARLSBAD
5300 SUNNY CREEK RD C
CARLSBAD, CA 92010
2.5 The Gross Nameplate Rating of the Generating Facility: 149 kW
2.6 The Net Nameplate Rating of the Generating Facility: 149 kW
2.7 The expected annual energy production of the Generating Facility is kWh
2.8 For the purpose of securing the Competition Transition Charge (“CTC”) exemption
available under Section 372 of the California Public Utilities (“PU”) Code, EP hereby
declares that the Generating Facility does does not meet the requirements for
“Cogeneration” as such term is used in Section 216.6 of the PU Code.
2.9 The Generating Facility’s expected date of Initial Operation is .
The expected date of Initial Operation shall be within years of the date of this GFIA.
Jan. 11, 2022 Item #8 Page 13 of 22
EXHIBIT 4
2 142-0545 (06/06)
3. DOCUMENTS INCLUDED; DEFINED TERMS
3.1 This GFIA includes the following exhibits that are specifically incorporated herein and made a part of this GFIA by this reference:
Appendix A - Description of Generating Facility and Single-Line Diagram
Appendix B - Copy of SDG&E's Electric Rule 2 and Rule 21
Appendix C – Copy of interconnection facilities financing and operation agreement
3.2 When initially capitalized, whether in the singular or in the plural, the terms used herein shall have the meanings assigned to them either in this GFIA or in Rule 21 of SDG&E’s tariffs.
4. TERM AND TERMINATION
4.1 This GFIA shall become effective as of the last date entered in Section 17, below. The
term of the GFIA shall continue in full force and effect until the earliest date that one of the following events occurs:
(a) The Parties agree in writing to terminate the GFIA; or
(b) The N/A dated N/A terminates for any reason.
4.2 SDG&E may elect to terminate this GFIA for one or more of the following additional reasons:
(a) A change in applicable rules, tariffs, and regulations, as approved or directed by the CPUC, or a change in any local, state or federal law, statute or regulation, either of
which materially alters or otherwise affects SDG&E’s ability or obligation to perform SDG&E’s duties under this GFIA; or,
(b) EP fails to take all corrective actions specified in SDG&E’s Notice that EP’s Generating Facility is out of compliance with the terms of this GFIA within the time
frame set forth in such Notice; or,
(c) EP abandons the Generating Facility. SDG&E shall deem the Generating Facility to
be abandoned if SDG&E determines, in its sole opinion, the Generating Facility is non-operational and EP does not provide a substantive response to SDG&E’s Notice
of its intent to terminate this Agreement as a result of EP’s apparent abandonment of the Generating Facility affirming EP’s intent and ability to continue to operate the
Generating Facility.
4.3 Any agreement attached to and incorporated into this GFIA shall terminate concurrently
with this GFIA unless the Parties have agreed otherwise in writing.
5. GENERATING FACILITY OPERATION AND CERTIFICATION REQUIREMENTS
5.1 EP is responsible for operating the Generating Facility in compliance with all of SDG&E’s
tariffs, including but not limited to SDG&E’s Rule 21, and any other regulations and laws governing the Interconnection of the Generating Facility.
5.2 EP shall not deliver reactive power to SDG&E’s Distribution System unless the Parties have agreed otherwise in writing.
5.3 The Generating Facility shall be operated with all of EP's Protective Functions in service whenever the Generating Facility is operated in parallel with SDG&E’s Distribution System. Any deviation from these requirements may occur only when the Parties have agreed to such deviations in writing.
Jan. 11, 2022 Item #8 Page 14 of 22
EXHIBIT 4
3 142-0545 (06/06)
6. INTERCONNECTION FACILITIES
6.1 EP and/or SDG&E, as appropriate, shall provide Interconnection Facilities that adequately protect SDG&E’s Distribution System, personnel, and other persons from
damage or injury, which may be caused by the operation of EP’s Generating Facility.
6.2 EP shall be solely responsible for the costs, design, purchase, construction, operation, and maintenance of the Interconnection Facilities that EP owns.
6.3 If the provisions of SDG&E’s Rule 21, or any other tariff approved by the Commission, require SDG&E to own and operate a portion of the Interconnection Facilities, EP and SDG&E shall promptly execute an agreement that establishes and allocates responsibility for the design, installation, operation, maintenance, and ownership of the Interconnection Facilities. 7. LIMITATION OF LIABILITY/INDEMNITY
Each Party’s liability to the other Party for any loss, cost, claim, injury, liability, or expense, including reasonable attorney’s fees, relating to or arising from any act or omission in its
performance of this agreement, shall be limited to the amount of direct damage actually incurred. In no event shall either Party be liable to the other Party for any indirect, special, consequential,
or punitive damages of any kind whatsoever.
As between SDG&E and EP, EP shall be solely responsible for and EP shall indemnify, defend and hold SDG&E , and its current and future parent company, subsidiaries, affiliates and their
respective directors, officers, shareholders, employees, agents, representatives, successors and assigns harmless from and against any and all claims, actions, suits, proceedings, losses,
liabilities, penalties, fines, damages, cost or expenses including without limitation, reasonable attorney’s fees (including fees and disbursements of in-house and outside counsel) of any kind
whatsoever resulting from (a) injuries to or death of any and all individuals, including, without limitation, members of the general public, or any employee, agent, independent contractor or
consultant or affiliate of either SDG&E or EP, arising out of or connected in any manner with EP’s performance of services, or (b) damage to and/or destruction of property of SDG&E or EP arising
out of or connected in any manner with EP’s performance of services, or (c) third party claims of any kind, whether based on negligence, strict liability, or otherwise, arising out of or connected in
any manner to EP’s or any of its subcontractors acts or omissions in breach of this Agreement.. This indemnification obligation shall not apply to the extent that injuries, death, loss, damage or
destruction is caused by either the willful misconduct by SDG&E or SDG&E’s sole negligence. 8. INSURANCE
8.1 In connection with EP’s performance of its duties and obligations under this GFIA, EP
shall maintain, during the term of the GFIA, general liability insurance with a combined single limit of not less than:
(a) Two million dollars ($2,000,000) for each occurrence if the Gross Nameplate Rating of EP’s Generating Facility is greater than one hundred (100) kW;
(b) One million dollars ($1,000,000) for each occurrence if the Gross Nameplate Rating of EP’s Generating Facility is greater than twenty (20) kW and less than or equal to
one hundred (100) kW; and
(c) Five hundred thousand dollars ($500,000) for each occurrence if the Gross
Nameplate Rating of EP’s Generating Facility is twenty (20) kW or less.
(d) Two hundred thousand dollars ($200,000) for each occurrence if the Gross Nameplate Rating of EP’s Generating Facility is ten (10) kW or less and EP’s Generating Facility is connected to an account receiving residential service from SDG&E.
Such general liability insurance shall include coverage for “Premises-Operations, Owners and Contractors Protective, Products/Completed Operations Hazard, Explosion, Collapse, Underground, Contractual Liability, and Broad Form Property Damage including Completed Operations.”
Jan. 11, 2022 Item #8 Page 15 of 22
EXHIBIT 4
4 142-0545 (06/06)
8.2 The general liability insurance required in Section 8.1 shall, by endorsement to the policy or policies, (a) include SDG&E, its affiliates/parent companies and their respective officers, directors, employees, agents, representatives, successors and assigns as an
additional insured; (b) contain a severability of interest clause or cross-liability clause; (c) provide that SDG&E shall not by reason of its inclusion as an additional insured incur liability to the insurance carrier for payment of premium for such insurance; and (d) provide for thirty (30) calendar days’ written notice to SDG&E prior to cancellation,
termination, alteration, or material change of such insurance.
8.3 If EP’s Generating Facility is connected to an account receiving residential service from
SDG&E and the requirement of Section 8.2(a) prevents EP from obtaining the insurance required in Section 8.1, then upon EP’s written Notice to SDG&E in accordance with
Section 9.1, the requirements of Section 8.2(a) shall be waived.
8.4 Evidence of the insurance required in Section 8.2 shall state that coverage provided is primary and is not in excess to or contributing with any insurance or self-insurance maintained by SDG&E.
8.5 EP shall furnish the required insurance certificates and endorsements to SDG&E prior to Initial Operation of the Generating Facility. Thereafter, SDG&E shall have the right to
periodically inspect or obtain a copy of the original policy or policies of insurance.
8.6 If EP is self-insured with an established record of self-insurance, EP may comply with the
following in lieu of Sections 8.1 through 8.4:
(a) EP shall provide to SDG&E, at least thirty (30) calendar days prior to the date of
Initial Operation, evidence of an acceptable plan to self-insure to a level of coverage equivalent to that required under Section 8.1.
(b) If EP ceases to self-insure to the level required hereunder, or if EP are unable to provide continuing evidence of EP’s ability to self-insure, EP agrees to
immediately obtain the coverage required under Section 8.1.
8.7 All insurance certificates, statements of self-insurance, endorsements, cancellations,
terminations, alterations, and material changes of such insurance shall be issued and submitted to the following:
San Diego Gas & Electric Company
Attn: Customer Generation
8316 Century Park Court, 52F
San Diego, CA 92123-1582
. 9. NOTICES
9.1 Any written notice, demand, or request required or authorized in connection with this GFIA (“Notice”) shall be deemed properly given if delivered in person or sent by first class
mail, postage prepaid, to the person specified below:
If to SDG&E: San Diego Gas & Electric Company
Attn: Customer Generation
8316 Century Park Court, 52F
San Diego, CA 92123-1582
.
Phone: (619) 696 - 2000 FAX: (858) 654 - 8292
If to EP: Phone: FAX:
Jan. 11, 2022 Item #8 Page 16 of 22
EXHIBIT 4
5 142-0545 (06/06)
9.2 A Party may change its address for Notices at any time by providing the other Party
Notice of the change in accordance with Section 9.1.
9.3 The Parties may also designate operating representatives to conduct the daily
communications, which may be necessary or convenient for the administration of this GFIA. Such designations, including names, addresses, and phone numbers may be communicated or revised by one Party’s Notice to the other.
10. ISO DECLARED EMERGENCIES
EP shall comply with all ISO protocols, including but not limited to the following: if the ISO declares a Stage 2 or Stage 3 System Emergency, as defined in the ISO Tariff and Protocols,
SDG&E may dispatch EP to operate the Generating Facility and EP shall make all commercially reasonable efforts to comply with such request within the physical limitations of the Generating
Facility.
11. REVIEW OF RECORDS AND DATA
11.1 SDG&E shall have the right to review and obtain copies of EP’s operations and maintenance records, logs, or other information such as, unit availability, maintenance outages, and circuit breaker operation requiring manual reset, relay targets and unusual
events pertaining to EP’s Generating Facility or its Interconnection with SDG&E’s Distribution System.
11.2 EP authorizes SDG&E to release to the California Energy Commission (CEC) information regarding EP’s facility, including customer name, location, size, and operational characteristics of the unit, as requested from time to time pursuant to the CEC’s rules and regulations.
12. ASSIGNMENT
EP shall not voluntarily assign its rights nor delegate its duties under this GFIA without SDG&E’s
written consent. Any assignment or delegation EP makes without SDG&E’s written consent shall not be valid. SDG&E shall not unreasonably withhold its consent to EP’s assignment of this
GFIA.
13. NON-WAIVER
None of the provisions of this GFIA shall be considered waived by a Party unless such waiver is given in writing. The failure of a Party to insist in any one or more instances upon strict
performance of any of the provisions of this GFIA or to take advantage of any of its rights hereunder shall not be construed as a waiver of any such provisions or the relinquishment of any
such rights for the future, but the same shall continue and remain in full force and effect.
14. GOVERNING LAW, JURISDICTION OF CPUC, INCLUSION OF SDG&E’s TARIFFS AND RULES
14.1 This GFIA shall be interpreted, governed, and construed under the laws of the State of California as if executed and to be performed wholly within the State of California without
giving effect to choice of law provisions that might apply to the law of a different jurisdiction.
14.2 This GFIA shall, at all times, be subject to such changes or modifications by the CPUC as it may from time to time direct in the exercise of its jurisdiction.
14.3 The interconnection and services provided under this GFIA shall at all times be subject to the terms and conditions set forth in the tariff schedules and rules applicable to the
electric service provided by SDG&E, which tariff schedules and rules are hereby incorporated into this GFIA by this reference.
14.4 Notwithstanding any other provisions of this GFIA, SDG&E shall have the right to unilaterally file with the CPUC, pursuant to the CPUC’s rules and regulations, an
application for change in rates, charges, classification, service, tariff or rule or any agreement relating thereto.
Jan. 11, 2022 Item #8 Page 17 of 22
EXHIBIT 4
6 142-0545 (06/06)
15. AMENDMENT AND MODIFICATION
This GFIA can only be amended or modified in writing and signed by both Parties.
16. ENTIRE AGREEMENT
This GFIA, including any incorporated tariff schedules and rules, contains the entire agreement and understanding between the Parties, their agents, and employees as to the subject matter of this GFIA. Each party also represents that in entering into this GFIA, it has not relied on any promise, inducement, representation, warranty, agreement or other statement not set forth in this GFIA or in the incorporated tariff schedules and rules.
17. SIGNATURES
IN WITNESS WHEREOF, the Parties hereto have caused two originals of this GFIA to be executed by their duly authorized representatives. This GFIA is effective as of the last date set forth below.
CUSTOMER NAME SAN DIEGO GAS & ELECTRIC COMPANY
By: By:
Name: Name: Ken Parks
Title: Title: Customer Generation Manager
Date: Date:
Jan. 11, 2022 Item #8 Page 18 of 22
EXHIBIT 4
7 142-0545 (06/06)
APPENDIX A
DESCRIPTION OF GENERATING FACILITY
AND SINGLE-LINE DIAGRAM
(Supplied by EP)
Jan. 11, 2022 Item #8 Page 19 of 22
EXHIBIT 4
8 142-0545 (06/06)
APPENDIX B
RULES: “2” and “21”
(Provided by SDG&E)
(Note: SDG&E’s tariffs are included for reference only and shall at all times be
subject to such changes or modifications by the Commission as the Commission
may, from time to time, direct in the exercise of its jurisdiction. A copy of Rule 2 has
not been provided. A copy may be obtained from SDG&E’s website:
www.sdge.com)
Jan. 11, 2022 Item #8 Page 20 of 22
EXHIBIT 4
9 142-0545 (06/06)
APPENDIX C
INTERCONNECTION FACILITIES FINANCING AND OWNERSHIP AGREEMENT
(Provided by SDG&E)
Jan. 11, 2022 Item #8 Page 21 of 22
Exhibit 5
Appendices A-B to Exhibit 4 – SDG&E Generating
Facility Interconnection Agreement
(on file in the Office of the City Clerk)
Jan. 11, 2022 Item #8 Page 22 of 22
Revised Cal. P.U.C. Sheet No. 15591-E
San Diego Gas & Electric Company Revised 6147-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6148-E
RULE 2 Sheet 1
DESCRIPTION OF SERVICE
(Continued)
1C15 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
A. General
1. The character of service available at any particular location should be ascertained by inquiry
at the Utility's office.
2. The Utility's rate schedules are applicable for service where the customer purchases his
entire electrical requirements from the Utility, except when such schedules specifically
provide otherwise.
3. Alternating current service of approximately 60-cycle frequency will be supplied.
4. Voltages referred to in the tariff schedules are nominal voltages.
B. Phase and Voltage Specifications
1. Standard voltages of the Utility are as follows:
a. Distribution voltages -- 120, 120/208, 120/240, 240, 480, 277/480, 2400, 4160, 6930
and 12,000 volts, where available and applicable.
b. Voltages of 69,000 volts and above are transmission voltages.
For its operating convenience, the Utility may elect to supply a customer from lines
of transmission voltage.
2. Customer Service Voltages
a. Under all normal load conditions, distribution circuits will be operated so as to
maintain secondary service voltage levels to customers within the voltage ranges
specified below:
Nominal Maximum Service Maximum Service
Two-Wire Voltage On Voltage On
And Minimum Residential Agricultural
Multi-Wire Voltage And Commercial And Industrial
Service To All Distribution Distribution
Voltage Services Circuits Circuits
120 114 120 126
208 197 208 218
240 228 240 252
277 263 277 291
480 456 480 504
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Revised Cal. P.U.C. Sheet No. 15592-E
San Diego Gas & Electric Company Revised 6148-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6149-E
RULE 2 Sheet 2
DESCRIPTION OF SERVICE
(Continued)
2C16 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
B. Phase and Voltage Specifications (Continued)
2. Customer Service Voltages (Continued)
b. Exceptions to Voltage Limits. Voltage may be outside the limits specified when the
variations:
(1) Arise from the temporary action of the elements.
(2) Are infrequent momentary fluctuations of a short duration.
(3) Arise from service interruptions.
(4) Arise from temporary separation of parts of the system from the main
system.
(5) Are from causes beyond the control of the Utility.
3. Customer Utilization Voltages
a. All customer-owned utilization equipment must be designed and rated in accordance
with the following utilization voltages specified by the American National Standard
C84.1 if customer equipment is to give fully satisfactory performance:
Nominal Minimum Maximum
Utilization Utilization Utilization
Voltage Voltage Voltage
120 110 125
208 191 216
240 220 250
277 254 289
480 440 500
b. The difference between service and utilization voltages are allowances for voltage
drop in customer wiring. The maximum allowance is 4 volts (120 volt base) for
secondary service.
c. Minimum utilization voltages from American National Standard C84.1 are shown for
customer information only as the Utility has no control over voltage drop in
customer's wiring.
d. The minimum utilization voltages shown in 3.a. above, apply for circuits supplying
lighting loads. The minimum secondary utilization voltages specified by American
National Standard C84.1 for circuits not supplying lighting loads are 90 percent of
nominal voltages (108 volts on 120 volt base) for normal service.
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Revised Cal. P.U.C. Sheet No. 15593-E
San Diego Gas & Electric Company Revised 6149-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6150-E
RULE 2 Sheet 3
DESCRIPTION OF SERVICE
(Continued)
3C18 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
B. Phase and Voltage Specifications (Continued)
3. Customer Utilization Voltages (Continued)
e. Motors used on 208 volt systems should be rated 200 volts or (for small single-
phase motors) 115 volts. Motors rated 230 volts will not perform satisfactorily on
these systems and should not be used. Motors rated 220 volts are no longer
standard, but many of them were installed on existing 208 volt systems on the
assumption that the utilization voltage would not be less than 187 volts (90 percent
of 208 volts).
4. Single-phase Service
a. General
Minimum Connected Maximum Connected
Volts Load Required Load Allowed
120 None 1-15 amp & 1-20 amp
branch circuit
120/240 None 400 amp main switch
or 240
480 15 kva Varies with location
2400 or Varies with Varies with location
or over location
b. Where the Utility maintains a 4-wire wye-connected 120/208 volt transformer, single-
phase service is supplied at 120/208 volts, 3-wire, for which the maximum size main
switch allowed is 200-ampere capacity. Loads on single-phase service must be
balanced between phases in accordance with good engineering practice, as
determined by the utility; however, in no case will the load on any one phase exceed
twice that on any other phase. Loads requiring in excess of a 200-ampere main
switch will be supplied at 120/208 volts, 3-phase, 4-wire.
c. The maximum size 120 volt single-phase motor allowed is 1 1/2 hp. The maximum
size single-phase motor permitted is 10 hp.
d. Single-phase service may be supplied to installations having a proposed main
switch in excess of the limits or switch capacities specified above, provided approval
of the Utility has been first obtained as to the number and size of switches, circuits
and related facilities. 120/240 volt installations may be supplied from two or three
separate 120/240 volt service connections to one meter. The connected load on
any service connection shall not be greater than twice that on any other connection.
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Revised Cal. P.U.C. Sheet No. 15594-E
San Diego Gas & Electric Company Revised 6151-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6152-E
RULE 2 Sheet 4
DESCRIPTION OF SERVICE
(Continued)
4C20 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
B. Phase and Voltage Specifications (Continued)
5. Three-phase Service
a. The minimum connected load requirement for 3-phase service is dependent on the
nature and availability of the Utility's facilities at any specific location.
Maximum Main Switch
Volts Maximum Demand Allowed Capacity Allowed
208 1,000 kva 4,000 amperes
240 1,000 kva 4,000 amperes
480 3,000 kva 4,000 amperes
4,160 Varies with location Varies with location
12,000 Varies with location Varies with location
b. Loads on 3-phase service must be balanced between phases in accordance with
good engineering practice, as determined by the Utility; however, in no case will the
load on any one phase exceed twice that on any other phase.
c. Three-phase service may be supplied to installations having a proposed main
service switch in excess of the switch capacities specified above, provided approval
of the Utility has first been obtained as to the number and size of switches, circuits
and related facilities. Such service may be supplied from two or three separate
service connections to one meter. The connected load on any service connection
shall not be greater than twice that on any other service connection.
6. Three-phase, 4-wire Service
a. Service may be supplied at 120/208 volts 4-wire wye-connected where the Utility
does not maintain 4-wire secondary 3-phase mains, provided: (1) written application
is made for such service by the customer; (2) the customer's load is of such a size
as to require an individual transformer installation of not less than 75 kva of
transformer capacity; and (3) the customer provides space acceptable to the Utility
on his premises to accommodate the installation of the Utility's facilities.
b. In underground areas where the Utility maintains 120/208 volt or 240 volt 3-phase
mains, service may be supplied at 277/480 volts, 4-wire wye provided: (1) written
application is made for such service by the customer; and (2) the customer's load is
of such a size as to require an individual transformer installation of not less than 75
kva, and (3) the customer provides space acceptable to the Utility on his premises to
accommodate installation of the Utility's facilities.
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Revised Cal. P.U.C. Sheet No. 15595-E
San Diego Gas & Electric Company Revised 6152-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6153-E
RULE 2 Sheet 5
DESCRIPTION OF SERVICE
(Continued)
5C20 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
B. Phase and Voltage Specifications (Continued)
6. Three-phase, 4-wire Service (Continued)
c. Service may be supplied at 120/240 volts 4-wire delta-connected where the Utility
does not maintain 4-wire secondary 3-phase mains, provided: (1) written application
is made for such service by the customer; (2) the customer's load is of such a size
and characteristic as to require in the opinion of the Utility an individual transformer
installation; (3) the unbalance between phases is acceptable to the Utility; and (4)
the customer provides space acceptable to the Utility on his premises for installation
of the Utility's facilities when, in the opinion of the Utility, such space is necessary.
7. At the option of the Utility, the above voltage and phase specifications may be modified
because of service conditions at the location involved.
8. The Utility may limit the size of the largest motor that may be operated on any part of its
system.
9. Existing customers receiving electric service at 480-volts, or less shall provide written
notification to the Utility a minimum of 30 days in advance of connecting all new electric
loads with a rating of 20kW, or greater, or smaller loads added over a 12-month period of
time with aggregate ratings totaling 20kW, or greater.
10. Existing customers receiving electric service at over 480-volts shall provide written
notification to the Utility a minimum of 30 days in advance of connecting all new electric
loads with a rating of 200kW, or greater; or smaller loads added over a 12-month period of
time with aggregate ratings totaling 200kW, or greater.
C. Motor Protection and Equipment
Customer's motor equipment must conform with the following requirements:
1. Motors that cannot be safely subjected to full rated voltage on starting, or that drive
machinery of such a nature that the machinery itself or the product it handles will not permit
the motor to resume normal speed upon restoration of normal supply voltage, shall be
equipped with devices that will disconnect them from the line on failure of supply voltage and
that will prevent automatic reconnection of the motors on restoration of normal supply
voltage.
2. All motors of 1 hp or larger shall be equipped with thermal relays, fuses, or other automatic
overcurrent interrupting devices to disconnect completely such motors from the line as a
protection against damage due to overheating.
3. All three-phase motors shall be provided with reverse-phase and open-phase protection to
completely disconnect the motors from the line in the event of phase reversal or loss of one
phase. The Utility assumes no liability for equipment damaged by a loss of phase or a
phase reversal condition.
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Revised Cal. P.U.C. Sheet No. 15596-E
San Diego Gas & Electric Company Revised 6153-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6154-E
RULE 2 Sheet 6
DESCRIPTION OF SERVICE
(Continued)
6C19 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
C. Motor Protection and Equipment (Continued)
4. Multiple installations of wind machines thermostatically controlled with automatic reclosing
switches must be equipped, at the customer's expense, with suitable time-delay devices as
hereinafter specified to permit the required adjustment of the time of reclosure after
interruption of service.
A suitable time-delay device, within the meaning of this rule, is a relay or other type of
equipment that can be preset to delay with various time intervals the reclosing of automatic
switches (and the consequent starting up of electric motors on the wind machines) and to
stagger the reconnection of the load on the Utility's system. Such device must be
constructed so as effectively to permit a variable over-all time interval of not less than five
minutes, with adjustable time increments of not greater than ten seconds. The particular
setting to be utilized for each separate installation is to be determined by the Utility from time
to time in accordance with its operating requirements, and the customer must obtain from
the Utility, the setting for each installation as thus determined.
D. Allowable Motor Starting Currents
1. The starting current drawn from the Utility's lines shall be considered the nameplate locked
rotor current, or that guaranteed by the manufacturer. At its option, the Utility may determine
the starting current by test, using a stop ammeter with not more than 15% overswing; or an
oscillograph disregarding the value shown for the first 10 cycles subsequent to energizing
the motor.
If the starting current for a single motor exceeds the value stated in the following tables,
reduced voltage starting or other suitable means must be employed, at the customer's
expense, to limit the current to the value specified, except where specific exemptions are
provided in Section D.2 or 3.
TABLE 1
Alternating Current - - Single-Phase Motors
Allowable Locked Rotor Currents
Rated Size 120 Volts 208 Volts 240 Volts
1 hp & less 46 amperes 32 amperes 27 amperes
11/2 hp 40 amperes 34 amperes
2 hp 53 amperes 46 amperes
3 hp 79 amperes 69 amperes
5 hp 133 amperes 115 amperes
7 1/2 hp 187 amperes 163 amperes
10 hp 250 amperes 218 amperes
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Revised Cal. P.U.C. Sheet No. 15597-E
San Diego Gas & Electric Company Revised 6154-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6155-E
RULE 2 Sheet 7
DESCRIPTION OF SERVICE
(Continued)
7C20 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
D. Allowable Motor Starting Currents (Continued)
TABLE 2
Alternating Current - - Three-Phase Motors
Allowable Locked Rotor Currents
Rated Size 208 Volts 240 Volts 480 Volts
3 hp 69 amperes 60 amperes 30 amperes
5 hp 100 amperes 87 amperes 43 amperes
7 1/2 hp 131 amperes 115 amperes 58 amperes
10 hp 161 amperes 141 amperes 71 amperes
15 hp 230 amperes 201 amperes 100 amperes
20 hp 308 amperes 268 amperes 134 amperes
25 hp 380 amperes 335 amperes 168 amperes
30 hp 456 amperes 402 amperes 201 amperes
40 hp 608 amperes 536 amperes 268 amperes
50 hp 770 amperes 670 amperes 335 amperes
over 50 hp -- The Utility should be consulted for allowable locked rotor currents.
2. Where service conditions permit, subject to the Utility's approval, reduced-voltage starters
may be omitted in the original installation until such time as the Utility may require the
installation of a reduced-voltage starter to be made. Similarly, the Utility may at any time
require starting current values lower than set forth herein, where conditions at any point on
its system require such reductions to avoid interference with service to the customer or any
other customer.
3. Reduced-voltage starters may be omitted on any motor of a group installation, provided its
starting current without starter does not exceed the allowable starting current of the largest
motor of the group.
E. Interference With Service
1. Customers who operate equipment that causes detrimental voltage fluctuations (such as, but
not limited to, hoists, welders, radio transmitters, X-ray apparatus, elevator motors,
compressors, and furnaces) must reasonably limit such fluctuations upon request by the
Utility or discontinue service at the request of the Utility. The customer will be required to
provide whatever corrective measures are necessary.
2. Arc furnace service installations are subject to the Utility's approval.
3. Any customer who superimposes a current of any frequency upon any part of his electrical
system, other than the current supplied by the Utility, shall, at his expense, prevent the
transmission of such current beyond his electrical system.
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Revised Cal. P.U.C. Sheet No. 15598-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 6156-E
RULE 2 Sheet 8
DESCRIPTION OF SERVICE
(Continued)
8C18 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
F. Welder Service
1. Rating of Welders: Electric welders will be rated for billing purposes as follows:
a. Motor Generator Arc Welders.
The horsepower rating of the motor driving a motor generator type arc welder will be
taken as the horsepower rating of the welder.
b. Transformer Arc Welders.
Nameplate maximum kva input (at rated output amperes) will be taken as the rating
of transformer type arc welders.
c. Resistance Welders.
Resistance welder ratings will be determined by multiplying the welder transformer
nameplate rating (at 50% duty cycle) by the appropriate factor listed below:
Factor
Transformer Utility- Customer-
Nameplate Owned Owned
Rating @ 50% Distribution Distribution
Type of Welder Duty Cycle Transformers Transformers
___________________________________________________________________________
Rocker Arm, Press or
Projection Spot 20 kva or less .60 .50
Rocker Arm or Press Spot Over 20 kva .80 .60
Projection Spot 21 to 75 kva, incl. .80 .60
Flash or Butt 100 kva or over .80 .60
Seam or Portable Gun All sizes .80 .60
Flash or Butt 67 to 100 kva, incl * *
Projection Spot Over 75 kva 1.20 .90
Flash or Butt 66 kva or less 1.20 .90
___________________________________________________________________________
* Each flash or butt welder in this group will be rated at 80 kva where distribution transformer is owned
by the Utility or 60 kva where distribtuion transformer is owned by the customer.
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Revised Cal. P.U.C. Sheet No. 15599-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 9101-E
RULE 2 Sheet 9
DESCRIPTION OF SERVICE
(Continued)
9C17 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
F. Welder Service (Continued)
1. Ratings of Welders. (Continued)
d. Ratings prescribed by a., b., and c., above normally will be determined from
nameplate data or from data supplied by the manufacturer. If such data are not
available or are believed by either the Utility or customer to be unreliable, the rating
will be determined by test.
e. If established by seals approved by the Utility, the welder rating may be limited by
the sealing of taps which provide capacity greater than the selected tap and/or by
the inter-locking lockout of one or more welders with other welders.
f. When conversion of units is required for tariff application, one welder kva will be
taken as one horsepower for tariffs stated on a horsepower basis and one welder
kva will be taken as one kilowatt for tariffs stated on a kilowatt basis.
2. Billing of Welders. Welders will be billed at the regular rates and conditions of the tariffs on
which they are served, subject to the following provisions:
a. Connected Load Type of Schedule.
Welder load will be included as part of the connected load with ratings as
determined under Section 1. above, based on maximum load that can be connected
at any one time, and no allowance will be made for diversity between welders.
b. Demand Metered Type of Schedule.
Where resistance welders are served on these schedules the computation of
diversified resistance welder load shall be made as follows:
Multiply the individual resistance welder ratings, as prescribed in Sections F.1.c. to
F.1.f. inclusive, above, by the following factors and add the results thus obtained:
1.0 times the rating of the largest welder
0.8 times the rating of the next largest welder
0.6 times the rating of the next largest welder
0.4 times the rating of the next largest welder
0.2 times the rating of all additional welders
If this computed diversified resistance welder load is greater than the metered
demand, the diversified resistance welder load will be used in lieu of the metered
demand for rate computation purposes.
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Revised Cal. P.U.C. Sheet No. 15600-E
San Diego Gas & Electric Company Revised 11451-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 9103-E
RULE 2 Sheet 10
DESCRIPTION OF SERVICE
(Continued)
10C17 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
G. Power Factor. The Utility may require the customer to provide, at the customer’s expense,
equipment to increase the operating power factor at the Utility’s service connection point to the
customer to not less than 90%, lagging or leading.
H. Wave Form. The Utility may require that the wave form of current drawn by equipment of any kind
be in conformity with good engineering practice (such as the Institute of Electrical and Electronics
Engineer’s (IEEE) Recommended Practice 519).
I. Special Facilities and Maintenance
1. Special facilities are considered to be existing, enlarged or new facilities installed, used
and/or maintained by the Utility at the applicants request in addition to, as enlargements of,
as alternate to, or in substitution for, the standard facilities which the Utility would normally
install, maintain or use and which represent additional costs to the Utility over normally
installed facilities. These facilities can include but are not limited to power quality
conditioning equipment, peaking equipment, customer connection costs, installation and/or
maintenance of facilities downstream of the meter, facilities where the cost is in excess of
the standard extension allowances, and alternate service equipment. Except where
provided by rate schedule, installation and/or maintenance of special facilities will be made
at the Utility's option, provided the type of special facilities requested is acceptable to the
Utility and the Utility agrees to the installation and/or maintenance of the special facilities,
under the following conditions:
a. The applicant for special facilities is also an applicant for permanent electric service
or is a customer for permanent electric service at the same location.
b. The Utility will install/maintain the requested facility so long as the facility does not
pose, in the opinion of the Utility, a hardship on the Utility.
c. The applicant will execute a contract covering the installation and/or maintenance of
special facilities. In addition to providing for the payment of charges as determined
under a regularly filed rate schedule, the contract will provide for the following:
(1) an estimate of the cost of the special facility that the applicant is requesting
the Utility to install and/or maintain;
(2) the one-time payment amount, if applicable, equal to the portion of the total
estimated cost to be paid through a one-time payment adjusted by the
factors in section d;
(3) a calculation of any remaining balance of the total estimated cost that the
Utility will incur that will be paid by the applicant through a monthly charge;
(4) the cost to operate and maintain the special facility will be paid by the
applicant through a monthly charge;
(5) the term mutually agreed upon by the applicant and Utility, over which the
applicant will make payments identified in paragraph 3 and 4 above.
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Revised Cal. P.U.C. Sheet No. 15601-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 9103-E
RULE 2 Sheet 11
DESCRIPTION OF SERVICE
(Continued)
11C16 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
I. Special Facilities and Maintenance (Continued)
1. (Continued)
d. Financing Options:
At its sole option, the Utility may require the applicant to pay for all costs associated
with the special facility through a one-time payment. The applicant will, if acceptable
to the Utility, make monthly payments using the amounts determined in subsection
c.3 and c.4 above against the factors set forth below.
Transmission
One-
Time
1
Year
2
Year
3
Year
5
Year
10
Year
20
Year
Substation
Capital
O&M
1.539
.2216
.1394
.0195
.0732
.0103
.0513
.0072
.0338
.0047
.0211
.0030
.0155
.0022
Overhead
Capital
O&M
1.516
.2580
.1379
.0227
.0724
.0119
.0507
.0084
.0335
.0055
.0209
.0034
.0154
.0025
Underground
Capital
O&M
1.552
.1343
.1361
.0118
.0715
.0062
.0501
.0043
.0330
.0029
.0206
.0018
.0152
.0013
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Revised Cal. P.U.C. Sheet No. 15602-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 9104-E
RULE 2 Sheet 12
DESCRIPTION OF SERVICE
(Continued)
12C16 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
I. Special Facilities and Maintenance (Continued)
1. d. Financing Options: (Continued)
Distribution
One-
Time
1
Year
2
Year
3
Year
5
Year
10
Year
20
Year
Substation
Capital
O&M
1.474
.5605
.1331
.0493
.0699
.0259
.0489
.0182
.0323
.0120
.0202
.0075
.0148
.0055
Overhead
Capital
O&M
1.523
.6314
.1375
.0556
.0722
.0292
.0506
.0204
.0334
.0135
.0209
.0084
.0153
.0062
Underground
Capital O&M
1.581 .1611
.1434 .0142
.0754 .0074
.0528 .0052
.0348 .0034
.0218 .0021
.0160 .0016
Transformers
Capital
O&M
1.616
.1326
.1451
.0117
.0763
.0061
.0534
.0043
.0352
.0028
.0220
.0018
.0162
.0013
Service-Over
Capital
O&M
1.721
.5391
.1694
.0475
.0890
.0249
.0623
.0175
.0411
.0115
.0257
.0072
.0189
.0053
Service-Under Capital O&M
1.516 .1691
.1363 .0149
.0716 .0078
.0502 .0055
.0331 .0036
.0207 .0023
.0152 .0017
Meters
Capital
O&M
1.541
.9281
.1377
.0817
.0724
.0429
.0507
.0301
.0334
.0198
.0209
.0124
.0154
.0091
Street Light
Capital
O&M
1.868
.3323
.1774
.0293
.0932
.0154
.0653
.0108
.0431
.0071
.0269
.0044
.0198
.0033
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Revised Cal. P.U.C. Sheet No. 15603-E
San Diego Gas & Electric Company Original 9105-ESan Diego, California Canceling Revised Cal. P.U.C. Sheet No. 9106-E
RULE 2 Sheet 13
DESCRIPTION OF SERVICE
(Continued)
13C20 Issued by Date Filed Aug 28, 2002
Advice Ltr. No. 1436-E Lee Schavrien Effective Oct 7, 2002
Vice President
Decision No. Regulatory Affairs Resolution No.
I. Special Facilities and Maintenance (Continued)
1. (Continued)
e. Contracts for special facilities executed by applicants prior to the Commission
approval of this replacement for Rule 2, shall remain in effect until terminated under
the terms of said contracts, or by order of the California Public Utilities Commission,
or as mutually agreed between the applicant and the Utility.
f. Where the annual consumption estimated for purposes of deriving the extension
allowance to be provided new applicants is in dispute by the applicant and the Utility,
the new applicant may pay 100% of the cost of the facilities to connect to the Utility's
system. For up to a 10-year term, but not to exceed the amount paid by the
applicant, refunds will be equal to 20% of the base rate revenues or such other
amount deemed appropriate by the Utility.
g. If the applicant terminates the contract prior to the end of the contract term or if
mutually agreed between the Utility and the applicant at anytime during the contract
term, applicant shall execute a Buyout Agreement with Utility and make a one-time
payment toward the applicant's outstanding balance remaining under the original
contract between Utility and applicant for the requested special facility. To
determine applicant's outstanding balance, the Utility will calculate a present value of
the applicant's total remaining payments for the balance of the term of the original
contract.
h. If it becomes necessary for the Utility to alter or rearrange the special facilities
including but not limited to the conversion of overhead facilities to underground,
applicant shall be notified of such necessity and shall be responsible for all costs the
Utility incurs in converting this service or shall terminate service under this
agreement. In order to terminate service under this agreement, applicant shall
provide written notice of its intent to the Utility at least thirty (30) days in advance.
applicant shall also execute a Buyout Agreement with Utility as set forth in
subsection g. above.
i. Applicant understands that Utility does not guarantee electric service to be free from
outages, interruptions, or curtailments and that the charges represent the additional
cost associated with providing the special facilities rather than a guaranteed level of
service or reliability. The applicant also understands that the installation of a special
facility, unless the facility is expressly for the purpose of enhancing power quality,
does not provide any enhanced power quality over the service the applicant would
otherwise receive from the Utility.
j. Installation and/or maintenance of a Utility-owned special facility shall at all times be
and remain the property of Utility.
k. In the event that Utility is prevented from completing the installation of the special
facilities for reasons beyond its control of within twelve (12) months following the
date of this Agreement, Utility shall have the right to terminate this Agreement upon
thirty (30) days written notice to applicant.
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Revised Cal. P.U.C. Sheet No. 20415-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 19206-E
RULE 2 Sheet 14
DESCRIPTION OF SERVICE
14C5 Issued by Date Filed Jan 18, 2008
Advice Ltr. No. 1940-E-A Lee Schavrien Effective Feb 17, 2008
Senior Vice President
Decision No. Regulatory Affairs Resolution No.
I. Special Facilities and Maintenance (Continued)
1. (Continued)
l. A monthly perpetuity charge shall be paid by applicant for Utility financed special facilities:
Type of Facility Monthly Charge
Transmission 1.45 percent
Distribution 1.61 percent
General Lighting 1.86 percent
J. Streetlight Energizing Charge for Customer-Owned Lights
1. Energizing Charge
Customers receiving service under Schedule LS-2 will be charged $30 per underground
connection and $60 per overhead connection for energizing the facilities.
2. Periodic Update
The amount of the energizing charge will be updated based on the Wholesale Price Index.
The Utility will prepare a contemplated rule revision for the above charge when the
Wholesale Price Index has changed by more than 10% since the last revision of the charge.
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Revised Cal. P.U.C. Sheet No. 28143-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27716-E
RULE 21 Sheet 1
GENERATING FACILITY INTERCONNECTIONS
(Continued)
1C10 Issued by Date Filed Oct 21, 2016
Advice Ltr. No. 2987-E Dan Skopec Effective Mar 30, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
A. Table of Contents
B. Applicability............................................................................................................................................. 6
1. Applicability ....................................................................................................................................... 6
2. Definitions ......................................................................................................................................... 6
3. Applicable Codes and Standards....................................................................................................... 6
4. Interaction with Other Tariffs for Storage Charging Load Treatment………………………………….. 6 C. Definitions ................................................................................................................................................ 7
D. General, Rules, Rights and Obligations................................................................................................... 19
1. Authorization Required to Operate ................................................................................................... 19
2. Separate Agreements Required for Other Services.......................................................................... 19
3. Services Under This Tariff Limited To Interconnection...................................................................... 19
4. Compliance with Laws, Rules, and Tariffs ........................................................................................ 19
5. Design Reviews and Inspections....................................................................................................... 20
6. Right to Access ................................................................................................................................. 20
7. Confidentiality.................................................................................................................................... 21
a. Scope ......................................................................................................................................... 21
b. Limitations on Scope................................................................................................................... 21
c. Disclosure to Commission, FERC, or their respective Staff........................................................ 22
d. Required Disclosure.................................................................................................................... 23
8. Prudent Operation and Maintenance Required................................................................................. 23
9. Curtailment and Disconnection.......................................................................................................... 23
10. Local Furnishing Bonds .................................................................................................................... 24
11. Coordination with Affected Systems…………………………………………………………………...….. 24
12. Transferability of Interconnection Request ....................................................................................... 24
13. Special Provisions Applicable to Certain Net Energy Metered Applicants......................................... 25
14. Special Provisions Applicable to Non-Export Battery Storage Generating Facilities………………… 27
15. Compliance with Established Timelines ............................................................................................ 27
16. Modification of Timelines................................................................................................................... 28
E. Interconnection Request Submission Process ....................................................................................... 28
1. Optional Standard and Enhanced Pre-Application Report ................................................................ 28
a. Standard Pre-Application Report……………………………………………………………………… 28
b. Enhanced Pre-Application Report……………………………………………………………………..29
c. Limitation and Scope of Optional Standard and Enhanced Pre-Application Report……………. 32
2. Interconnection Request Process...................................................................................................... 32
a. Applicant Initiates Contact with Distribution Provider.................................................................. 32
b. Applicant Selects a Study Process.............................................................................................. 32
c. Applicant Completes an Interconnection Request...................................................................... 33
d. Site Exclusivity.............................................................................................................................36
3. Interconnection Request Fee and Study Deposit.............................................................................. 36
a. Detailed Study Deposit ............................................................................................................... 36
4. Interconnection Cost Responsibility................................................................................................... 39
a. Costs of Interconnection and Parallel Operation ........................................................................ 39
b. Methodology and Timing of Cost Identification........................................................................... 39
c. Timing of Cost Identification........................................................................................................ 40
d. Producer Costs During Parallel Operation ................................................................................. 40
e. Cost Allocation.............................................................................................................................40
f. Summary Tables......................................................................................................................... 41
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Revised Cal. P.U.C. Sheet No. 28005-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27717-E
RULE 21 Sheet 2
GENERATING FACILITY INTERCONNECTIONS
(Continued)
2C10 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
5. Interconnection Request Validation and Assignment of Queue Position…………….…................... 42
a. Acknowledgement of Interconnection Request ........................................................................ 42
b. Deficiencies in Interconnection Request .................................................................................. 42
c. Assignment of Queue Position.................................................................................................. 43
d. Publication of the Interconnection Queue.................................................................................. 43
F. Review Process For Interconnection Requests...................................................................................... 44
1. Overview of the Interconnection Review Process ........................................................................... 44
a. Valid Interconnection Request .................................................................................................. 44
b. Fast Track Review .................................................................................................................... 44
c. Detailed Studies......................................................................................................................... 45
d. Compliance with Timelines ....................................................................................................... 45
2. Fast Track Interconnection Review Process.................................................................................... 46
a. Initial Review.............................................................................................................................. 46
b. Optional Initial Review Results Meeting ................................................................................... 47
c. Supplemental Review ............................................................................................................... 48
d. Optional Supplemental Review Results Meeting....................................................................... 50
e. Execution of the Generator Interconnection Agreement............................................................ 51
3. Detailed Study Interconnection Review Process............................................................................. 52
a. Detailed Study Track Selection Process .................................................................................. 52
b. Independent Study Process...................................................................................................... 54
c. Distribution Group Study Process............................................................................................. 60
d. Transmission Cluster Study Process......................................................................................... 70
e. Generator Interconnection Agreement for Detailed Study......................................................... 71
f. Engineering & Procurement (E&P) Agreement ........................................................................ 73
4. Interconnection Financial Security .................................................................................................. 74
a. Types of Interconnection Financial Security. ............................................................................ 74
b. Initial Posting of Interconnection Financial Security.................................................................. 75
c. Second Posting of Interconnection Financial Security............................................................... 76
d. Third Posting of Interconnection Financial Security................................................................... 77
e. General Effect of Withdrawal of Interconnection Request or Termination of the
Generator Interconnection Agreement on Interconnection Financial Security for
Interconnection Requests Studied Under the Independent Study Process.............................. 78
5. Commissioning Testing and Parallel Operation .............................................................................. 83
a. Commissioning Testing............................................................................................................. 83
b. Parallel Operation or Momentary Parallel Operation ................................................................ 84
6. Withdrawal ....................................................................................................................................... 84
7. Cost Envelope Option……………………………………………………………………………………… 84
a. Eligibility for Cost Envelope Option………………………………………………………………….. 85
b. Cost Responsibility Under the Cost Envelope Option…………………………………………….. 86
c. Timing of Applicant’s Selection of Cost Envelope Option and Payment of Deposit…………… 86
d. Distribution Provider’s Preparation of the Cost Envelope Estimate……………………………… 87
e. Cost Elements Not Subject to Cost Envelope……………………………………………………… 88
f. Modifications…………………………………………………………………………………………… 89
g. Tender of the Generator Interconnection Agreement Under the Cost Envelope Option……… 89
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Revised Cal. P.U.C. Sheet No. 28006-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25990-E
RULE 21 Sheet 3
GENERATING FACILITY INTERCONNECTIONS
(Continued)
3C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details..................................................................................................................... 90
1. Initial Review Screens ....................................................................................................................... 92
a. Screen A: Is the PCC on a Networked Secondary System?....................................................... 92
b. Screen B: Is Certified Equipment used?..................................................................................... 92
c. Screen C: Is the Starting Voltage Drop within acceptable limits? .............................................. 93
d. Screen D: Is the transformer or secondary conductor rating exceeded? ................................... 93
e. Screen E: Does the Single-Phase Generator cause unacceptable imbalance?......................... 94
f. Screen F: Is the Short Circuit Current Contribution Ratio within acceptable limits? ................... 94
g. Screen G: Is the Short Circuit Interrupting Capability Exceeded?............................................... 95
h. Screen H: Is the line configuration compatible with the Interconnection type?........................... 95
i. Screen I: Will power be exported across the PCC?.................................................................... 96
j. Screen J: Is the Gross Rating of the Generating Facility 11 kVA or less? ................................. 97
k. Screen K: Is the Generating Facility a Net Energy Metering (NEM) Generating Facility with
nameplate capacity less than or equal to 500k........................................................................... 97
l. Screen L: Transmission Dependency and Transmission Stability Test...................................... 98
m. Screen M: Is the aggregate Generating Facility capacity on the Line Section less than 15% of
Line Section peak load for all line sections bounded by automatic sectionalizing devices?....... 98
2. Supplemental Review Screens.......................................................................................................... 98
a. Screen N: Penetration Test......................................................................................................... 99
b. Screen O: Power Quality and Voltage Tests .............................................................................. 99
c. Screen P: Safety and Reliability Tests ....................................................................................... 100
3. Detailed Study Screens .................................................................................................................... 101
a. Screen Q: Is the Interconnection Request electrically Independent of the Transmission
System?.......................................................................................................................................101
b. Screen R: Is the Interconnection Request independent of other earlier-queued and yet to be
studied interconnection requests interconnecting to the Distribution System?........................... 102
c. Independent Study Process and Distribution Group Study Process Interconnection Studies... 103
H. Generating Facility Design and Operating Requirements ....................................................................... 105
1. General Interconnection and Protective Function Requirements ..................................................... 105
a. Protective Functions Required ................................................................................................... 105
b. Momentary Paralleling Generating Facilities .............................................................................. 106
c. Suitable Equipment Required ..................................................................................................... 106
d. Visible Disconnect Required ...................................................................................................... 106
e. Drawings Required ..................................................................................................................... 107
f. Generating Facility Conditions Not Identified.............................................................................. 107
2. Prevention of Interference ................................................................................................................. 108
a. Voltage Regulation...................................................................................................................... 108
b. Voltage Trip Setting .................................................................................................................... 108
c. Paralleling.................................................................................................................................... 111
d. Flicker ......................................................................................................................................... 111
e. Integration with Distribution Provider’s Distribution System Grounding ..................................... 111
f. Frequency....................................................................................................................................111
g. Harmonics .................................................................................................................................. 113
h. Direct Current Injection ............................................................................................................... 113
i. Power Factor .............................................................................................................................. 114
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Revised Cal. P.U.C. Sheet No. 29025-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28397-E
RULE 21 Sheet 4
GENERATING FACILITY INTERCONNECTIONS
(Continued)
4C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
3. Technology Specific Requirements ................................................................................................ 114
a. Technology Specific Requirements........................................................................................... 114
b. Induction Generators ................................................................................................................ 114
c. Inverters..................................................................................................................................... 115
d. Limitations on inverters not classified as Smart Inverters………………………………………… 115
4. Supplemental Generating Facility Requirements ............................................................................ 115
a. Fault Detection........................................................................................................................... 115
b. Transfer Trip ............................................................................................................................. 115
c. Reclose Blocking ...................................................................................................................... 115
Hh. Smart Inverter Generating Facility Design and Operating Requirements………………………………….116
1. General Interconnection and Protective Function Requirements…………………………………..… 116
a. Protective Functions Required………………………………………………………………………. 117
b. Momentary Paralleling Generating Facilities……………………………………………………….. 117
c. Suitable Equipment Required…………………………………………………………………...…… 118
d. Visible Disconnect Required………………………………………………………………………..... 118
e. Drawings Required…………………………………………………………………………...……….. 119
f. Generating Facility Conditions Not Identified………………………………………………………. 119
2. Prevention of Interference………………………………………………………………………………… 119
a. Voltage Regulation………………………………………………..………………………………….. 120
b. Voltage Trip and Ride Through Setting…………………………………………………………….. 120
c. Paralleling……………………………………………………………………………………………….122
d. Flicker…………………………………………………………………………………….…………….. 123
e. Integration with Distribution Provider’s Distribution System Grounding………………..……….. 123
f. Frequency……………………………………………………………………………………..……….. 123
g. Harmonics…………………………………………………………………………..………………….. 124
h. Direct Current Injection………………………………………………………………………..……… 125
i. Power Factor………………………………………………………………………………………….. 125
j. Dynamic Volt/VAr Operations………………………………………………………………..……… 126
k. Ramp Rate Requirements……………………………………………………………………………. 127
l. Recommended Frequency-Watt Settings…………………………………………………………... 127
m. Voltage-Watt Default Settings………………………………………………………………………...128 n. Default Activation States for Phase 1 Functions……………………………………………….….. 128
3. Technology Specific Requirements……….……………………………………………………………… 129
4. Supplemental Smart Inverter Requirements……………………………………………………………. 129
a. Fault Detection…………………………………………………………...……………………………. 129
b. Transfer Trip……………………………………………………………………………………..…….. 130
c. Reclose Blocking………………………………………………………………………….……………130
5. Communication Requirements……………………………………………………………………………. 130
a. Protocol Requirements……………………………………………………………………………….. 130
b. Additional Protocol Requirements…………………………………………………………………… 130
I. Third-Party Installations, Reservation of Unused Facilities, and Refund of Salvage Value ……..…….. 131
1. Interconnection Facilities and Distribution Upgrades ...................................................................... 131
2. Third-Party Installations.................................................................................................................... 131
3. Reservation of Unused Facilities .....................................................................................................132
4. Refund of Salvage Value................................................................................................................. 132
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Revised Cal. P.U.C. Sheet No. 29026-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28398-E
RULE 21 Sheet 5
GENERATING FACILITY INTERCONNECTIONS
(Continued)
5C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
J. Metering, Monitoring and Telemetering.................................................................................................. 132
1. General Requirements ....................................................................................................................... 132
2. Metering by Non-Distribution Provider Parties ................................................................................... 132
3. Net Generation Output Metering......................................................................................................... 132
4. Point of Common Coupling (PCC) Metering ...................................................................................... 133
5. Telemetering ...................................................................................................................................... 134
6. Location.............................................................................................................................................. 134
7. Costs of Metering ............................................................................................................................... 134
8. Multiple Tariff Metering ...................................................................................................................... 134
K. Dispute Resolution Process ................................................................................................................... 134
1. Scope............................................................................................................................................... 135
2. Procedures....................................................................................................................................... 135
3. Performance During Dispute ........................................................................................................... 136
L. Certification and Testing Criteria ........................................................................................................... 136
1. Introduction ...................................................................................................................................... 136
2. Certified and Non-Certified Interconnection Equipment .................................................................. 136
a. Certified Equipment .................................................................................................................. 136
b. Non-Certified Equipment........................................................................................................... 137
3. Type Testing .................................................................................................................................... 138
a. Type Tests and Criteria for Interconnection Equipment Certification ....................................... 138
b. Anti-Islanding Test .................................................................................................................... 139
c. Non-Export Test........................................................................................................................ 139
d. In-rush Current Test.................................................................................................................. 140
e. Surge Withstand Capability Test .............................................................................................. 140
f. Synchronization Test ................................................................................................................ 140
g. Paralleling Device Withstand Test…………………………………………………………………... 141
4. Production Testing .......................................................................................................................... 141
5. Commissioning Testing ................................................................................................................... 142
a. Commissioning Testing............................................................................................................. 142
b. Review, Study, and Additional Commissioning Test Verification Costs ................................... 143
c. Other Checks and Tests ........................................................................................................... 143
d. Certified Equipment .................................................................................................................. 144
e. Non-Certified Equipment........................................................................................................... 144
f. Verification of Settings .............................................................................................................. 145
g. Trip Tests................................................................................................................................... 145
h. In-service Tests ........................................................................................................................ 145
6. Periodic Testing............................................................................................................................... 146
7. Type Testing Procedures Not Defined in Other Standards ............................................................. 146
a. Non-Exporting Test Procedures................................................................................................ 146
b. In-rush Current Test Procedures............................................................................................... 154 M. Inadvertent Export.................................................................................................................................. 155
Mm. Inadvertent Export Utilizing UL-1741 or UL-1741 SA-Listed Grid Support (Non-Islanding) Inverters…155
N. Expedited Interconnection Process for Non-Export Battery Storage Generating Facilities ……………. 157
Appendix A….…………………………………………………………………………………………………… 160 Appendix B………………………………………………………………………………………………………. 162
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Revised Cal. P.U.C. Sheet No. 29027-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27719-E
RULE 21 Sheet 6
GENERATING FACILITY INTERCONNECTIONS
(Continued)
6C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
B. Applicability
1. Applicability
This Rule describes the Interconnection, operating and Metering requirements for those Generating
Facilities to be connected to Distribution Provider’s Distribution System and Transmission System
over which the California Public Utilities Commission (Commission) has jurisdiction. All Generating
Facilities seeking Interconnection with Distribution Provider’s Transmission System shall apply to the
California Independent System Operator (CAISO) for Interconnection and be subject to CAISO Tariff
except for 1) Net Energy Metering Generating Facilities and 2) Generating Facilities that do not
export to the grid or sell any exports sent to the grid (Non-Export Generating Facilities). NEM
Generating Facilities and Non-Export Generating Facilities subject to Commission jurisdiction shall
interconnect under this Rule regardless of whether they interconnect to Distribution Provider’s
Distribution or Transmission System. Subject to the requirements of this Rule, Distribution Provider
will allow the Interconnection of Generating Facilities with its Distribution or Transmission System.
Generating Facility interconnections to Distribution Provider’s Distribution System that are subject to
Federal Energy Regulatory Commission (FERC) jurisdiction shall apply under Distribution Provider’s
WDAT.
SDG&E rates and rate design, including the rates and rate design reflected in this Tariff, are subject
to change from time to time. Customers should take this into consideration when making any long
term decisions based on rate structures that are currently in place.
2. Definitions
Capitalized terms used in this Rule, and not defined in Distribution Provider’s other tariffs shall have
the meaning ascribed to such terms in Section C of this Rule. The definitions set forth in Section C
of this Rule shall only apply to this Rule, the Interconnection Request, study agreements and
Generator Interconnection Agreements, and may not apply to Distribution Provider’s other tariffs.
3. Applicable Codes and Standards
This Rule has been harmonized with the requirements of American National Standards
Institute/Institute of Electrical and Electronic Engineers (ANSI/IEEE) 1547-2003 Standards for
Interconnecting Distributed Resources with Electric Power Systems. In some sections, IEEE 1547
language has been adopted directly, in others, IEEE 1547 requirements were interpreted and this
Rule’s language was changed to maintain the spirit of both documents. The language from IEEE
1547 that has been adopted directly (as opposed to paraphrased language or previous language
that was determined to be consistent with IEEE 1547) is followed by a citation that lists the Clause
from which the language derived. For example, IEEE 1547-4.1.1 is a reference to Clause 4.1.1. In
the event of any conflict between this Rule, any of the standards listed herein, or any other
applicable standards or codes, the requirements of this Rule shall take precedence.
UL1741 – Supplement SA has been utilized for certification of Smart Inverters (Phase I Smart
Inverter Functions) as outlined in Section Hh of this Rule.
4. Interaction with Other Tariffs for Storage Charging Load Treatment
For retail customers interconnecting energy storage devices pursuant to this Rule, the load aspects
of the storage devices will be treated pursuant to Electric Rules 2, 3, 15 and 16 just like other load,
using the incremental net load for non-residential customers, if any, of the storage devices.
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Revised Cal. P.U.C. Sheet No. 24948-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 23116-E
RULE 21 Sheet 7
GENERATING FACILITY INTERCONNECTIONS T
(Continued)
7C10 Issued by Date Filed Jun 9, 2014
Advice Ltr. No. 2610-E Lee Schavrien Effective Jul 9, 2014
Senior Vice President
Decision No. 14-04-003 Resolution No.
C. Definitions
The definitions in this Section C are applicable only to this Rule, the Interconnection Request, Study
Agreements and Generator Interconnection Agreements.
Added Facilities: See Special Facilities.
Affected System: An electric system other than Distribution Provider's Distribution or Transmission
System that may be affected by the proposed Interconnection.
Affected System Operator: The entity that operates an Affected System.
Affiliate: With respect to a corporation, partnership or other entity, each such other corporation,
partnership or other entity that directly or indirectly, through one or more intermediaries’ controls, is
controlled by, or is under common control with, such corporation, partnership or other entity.
Allocated Capacity: Existing aggregate generation capacity in megawatts (MW) interconnected to a
substation/area bus, bank or circuit (i.e., amount of generation online).
Anti-Islanding: A control scheme installed as part of the Generating or Interconnection Facility that
senses and prevents the formation of an Unintended Island.
Applicant: The entity submitting an Interconnection Request pursuant to this Rule.
Application: See Interconnection Request.
Available Capacity: Total Capacity less the sum of Allocated Capacity and Queued Capacity.
Base Case: Data including, but not limited to, base power flow, short circuit and dynamic/stability data
bases, underlying load, generation, and transmission facility assumptions, contingency lists, including
relevant special protection systems, and transmission diagrams used to perform the Interconnection
Studies. The Base Case may include Critical Energy Infrastructure Information (as that term is defined
by FERC). The Base Case shall include (a) transmission facilities a approved by Distribution Provider or
CAISO, as applicable, (b) planned Distribution Upgrades that may have an impact on the
Interconnection Request, (c) Distribution Upgrades an Network Upgrades associated with generating
facilities in (iv) below, and (d) generating facilities that (i) are directly interconnected to the Distribution
System or CAISO Controlled Grid; (ii) are interconnected to Affected Systems and may have an impact
on the Interconnection Request; (iii) have a pending request to interconnect to the Distribution System
or an Affected System; or (iv) are not interconnected to the Distribution System or CAISO Controlled
Grid, but are subject to a fully executed Generator Interconnection Agreement (or its equivalent
predecessor agreement) or for which an unexecuted Generator Interconnection Agreement (or its
equivalent predecessor agreement) has been requested to be filed with FERC.
Business Day: Monday through Friday, excluding Federal and State Holidays.
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Revised Cal. P.U.C. Sheet No. 28007-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25993-E
RULE 21 Sheet 8
GENERATING FACILITY INTERCONNECTIONS
(Continued)
8C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
C. Definitions (Continued)
CAISO Controlled Grid: The system of transmission lines and associated facilities that have been
placed under the CAISO’s Operational Control.
CAISO Tariff: The California Independent System Operator FERC Electric Tariff.
Calendar Day: Any day including Saturday, Sunday or a Federal and State Holiday.
Certification Test: A test pursuant to this Rule that verifies conformance of certain equipment with
Commission-approved performance standards in order to be classified as Certified Equipment.
Certification Tests are performed by Nationally Recognized Test Laboratories (NRTLs).
Certification; Certified; Certificate: The documented results of a successful Certification Testing.
Certified Equipment: Equipment that has passed all required Certification Tests.
Commercial Operation: The status of a Generating Facility that has commenced generating electricity,
excluding electricity generated during the period which Producer is engaged in on-site test operations
and commissioning of the Generating Facility prior to Commercial Operation.
Commercial Operation Date: The date on which a Generator at a Generating Facility commences
Commercial Operation as agreed to by the Parties.
Commission: The Public Utilities Commission of the State of California.
Commissioning Test: A test performed during the commissioning of all or part of a Generating Facility
to achieve one or more of the following: Verify specific aspects of its performance; Calibrate its
instrumentation; Establish instrument or Protective Function set-points.
Confidential Information: See Section D.7.
Conservation Voltage Regulation (CVR): The CVR program that the Commission directed Distribution
Provider to implement as applicable to the operation and design of distribution circuits and related
service voltages.
Construction Activities: Actions by Distribution Provider that result in irrevocable financial
commitments for the purchase of major electrical equipment or land for Distribution Provider’s
Interconnection Facilities, Distribution Upgrades, or Network Upgrades assigned to the Interconnection
Customer that occur after receipt of all Facilities, Distribution Upgrades, or Network Upgrades.
Continuous Operation: The Smart Inverter operates indefinitely without tripping. Any functions that
protect the SMART INVERTER from damage may operate as needed.
Control Area: As defined in the CAISO Tariff.
Cost Envelope: A cost-certainty framework defined as plus or minus twenty-five (25) percent of the estimated cost of certain Interconnection Facilities and/or Distribution Upgrades identified in the Cost
Envelope Estimate that is offered to an Applicant based on actual costs within such twenty-five (25) percent envelope. Applicant’s cost responsibility for Interconnection Facilities and/or Distribution
Upgrades subject to the Cost Envelope is set forth in Section F.7.b.
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Revised Cal. P.U.C. Sheet No. 28008-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 24950-E
RULE 21 Sheet 9
GENERATING FACILITY INTERCONNECTIONS
(Continued)
9C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Cost Envelope Estimate: An estimate prepared by the Distribution Provider and delivered to Applicant
pursuant to the Cost Envelope Option that contains the estimated cost of Distribution Provider’s required
Interconnection Facilities, Distribution Upgrades and/or Network Upgrades that are offered to Applicant
based on the Cost Envelope, and the estimated costs of related activities and facilities excluded from the
Cost Envelope and offered on an actual cost basis pursuant to Section F.7. Cost Envelope Option: An estimate prepared by the Distribution Provider and delivered to Applicant pursuant to the Cost Envelope Option that contains (i) the estimated cost of Distribution Provider’s required Interconnection Facilities and/or Distribution Upgrades that are offered to Applicant that are subject to the Cost Envelope, and (ii) the estimated costs of related activities and facilities that are excluded from the Cost Envelope and offered on an actual cost basis, both pursuant to Section F.7. Customer: The entity that receives or is entitled to receive Distribution Service through Distribution
Provider’s Distribution System or is a retail Customer of Distribution Provider connected to the
Transmission System. Dedicated Transformer; Dedicated Distribution Transformer: A transformer that provides electricity
service to a single Customer. The Customer may or may not have a Generating Facility. Delivery Network Upgrades: The transmission facilities at or beyond the point where Distribution
Provider’s Distribution System interconnects to the CAISO Controlled Grid, other than Reliability Network
Upgrades, as defined in the CAISO Tariff. Detailed Study: An Independent Study, a Distribution Group Study or a Transmission Cluster Study. Detailed Study Agreement: The agreement entered into by the Interconnection Customer and
Distribution Provider which sets forth the Parties’ agreement to perform Interconnection Studies under
the Independent Study Process or the Distribution Group Study Process. Device: A mechanism or piece of equipment designed to serve a purpose or perform a function. The
term may be used interchangeably with the terms “equipment” and function without intentional difference
in meaning. See also Function and Protective Function.
DGS Phase I Interconnection Study: Distribution Group Study (DGS) Phase I Interconnection Study
performed by the Distribution Provider under the Distribution Group Study Process per Section G.3.c.i. DGS Phase II Interconnection Study: Distribution Group Study (DGS) Phase II Interconnection Study
performed by the Distribution provider under the Distribution Group Study Process per Section G.3.c.ii.
Dispute Resolution: See Section K. Distribution Group Study: An interconnection engineering study of a group comprised of
Interconnection Requests that pass Screen Q as a group and fail Screen R demonstrating they are
electrically interdependent in accordance with Section F.3.c. Distribution Group Study Process: The interconnection study process set forth in Section F.3.c. Distribution Provider: San Diego Gas & Electric Company. Distribution Service: The service of delivering energy over the Distribution System pursuant to the
approved tariffs of Distribution Provider other than services directly related to the Interconnection of a
Generating Facility under this Rule.
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Revised Cal. P.U.C. Sheet No. 28009-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 24951-E
RULE 21 Sheet 10
GENERATING FACILITY INTERCONNECTIONS
(Continued)
10C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
C. Definitions (Continued) Distribution Study Group: A group comprised of Interconnection Requests that fail Screen R that will
be studied pursuant to Section F.3.c because the Screen R results demonstrate they are electrically
interdependent.
Distribution System: All electrical wires, equipment, and other facilities owned or provided by
Distribution Provider, other than Interconnection Facilities or the Transmission System, by which
Distribution Provider provides Distribution Service to its Customers.
Distribution Upgrades: The additions, modifications, and upgrades to Distribution Provider's
Distribution System at or beyond the Point of Interconnection to facilitate interconnection of the
Generating Facility and render the Distribution Service. Distribution Upgrades do not include
Interconnection Facilities.
Electrical Independence Test: The tests set forth in Section G.3 used to determine eligibility for the
Independent Study Process.
Emergency: Whenever in Distribution Provider’s discretion an Unsafe Operating Condition or other
hazardous condition exists or whenever access is necessary for emergency service restoration, and
such immediate action is necessary to protect persons, Distribution Provider’s facilities or property of
others from damage or interference caused by Interconnection Customer’s Generating Facility, or the
failure of protective device to operate properly, or a malfunction of any electrical system equipment or a
component part thereof.
Energy-Only Deliverability Status: A condition elected by an Interconnection Customer for a
Generating Facility interconnected to Distribution System, the result of which is that the Interconnection
Customer is responsible only for the costs of Reliability Network Upgrades and is not responsible for the
costs of Delivery Network Upgrades, but the Generating Facility will be deemed to have a Net Qualifying
Capacity as defined in the CAISO Tariff of zero.
Engineering and Procurement Agreement: An agreement that authorizes Distribution Provider to
begin engineering and procurement of long lead-time items necessary for the establishment of the
Interconnection in order to advance the implementation of the Interconnection Request.
Exporting Generating Facility: Any Generating Facility other than a Non-Export Generating Facility,
NEM Generating Facility, or uncompensated Generating Facility.
Fast Track Process: The interconnection study process set forth in Section F.2.
Federal Energy Regulatory Commission: Referred to herein as FERC.
Field Testing: Testing performed in the field to determine whether equipment meets Distribution
Provider’s requirements for safe and reliable Interconnection.
Function: Some combination of hardware and software designed to provide specific features or
capabilities. Its use, as in Protective Function, is intended to encompass a range of implementations
from a single-purpose device to a section of software and specific pieces of hardware within a larger
piece of equipment to a collection of devices and software.
Generating Facility: All Generators, electrical wires, equipment, and other facilities, excluding
Interconnection Facilities, owned or provided by Producer for the purpose of producing electric power,
including storage.
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Revised Cal. P.U.C. Sheet No. 28106-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28010-E
RULE 21 Sheet 11
GENERATING FACILITY INTERCONNECTIONS
(Continued)
11C6 Issued by Date Filed Sep 21, 2016
Advice Ltr. No. 2959-E Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Generating Facility Capacity: The net capacity of the Generating Facility and the aggregate net
capacity of the Generating Facility where it includes multiple Generators.
Generator: A device converting mechanical, chemical, or solar energy into electrical energy, including
all of its protective and control functions and structural appurtenances. One or more Generators
comprise a Generating Facility.
Generator Interconnection Agreement: An agreement between Distribution Provider and Producer
providing for the Interconnection of a Generating Facility that gives certain rights and obligations to
effect or end Interconnection. For the purpose of Commission are also defined as Generator
Interconnection Agreements.
Good Utility Practice: Any of the practices, methods and acts engaged in or approved by a significant
portion of the electric utility industry during the relevant time period, or any of the practices, methods
and acts which, in the exercise of reasonable judgment in light of the facts known at the time the
decision was made, could have been expected to accomplish the desired result at a reasonable cost
consistent with good business practices, reliability, safety and expedition. Good Utility Practice is not
intended to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to
be acceptable practices, methods, or acts generally accepted in the region.
Governmental Authority: Any federal, state, local or other governmental regulatory or administrative
agency, court, commission, department, board, or other governmental subdivision, legislature,
rulemaking board, tribunal, or other governmental authority having jurisdiction over the Parties, their
respective facilities, or the respective services they provide, and exercising or entitled to exercise any
administrative, executive, police, or taxing authority or power; provided, however, that such term does
not include Interconnection Customer, Distribution Provider, or any Affiliate thereof.
Gross Rating; Gross Nameplate Rating; Gross Capacity or Gross Nameplate Capacity: The total
gross generating capacity of a Generator or Generating Facility as designated by the manufacturer(s) of
the Generator(s).
Host Load: The electrical power, less the Generator auxiliary load, consumed by the Customer, to
which the Generating Facility is connected.
Inadvertent Export: The unscheduled and uncompensated export of real power from a Generating
Facility (GF) for a limited duration as specified in Sections M and Mm.
Independent Study Process: The interconnection study process set forth in Section F.3.d.
Initial Review: See Section F.2.a.
In-rush Current: The current determined by the In-rush Current Test.
In-Service Date: The estimated date upon which Applicant reasonably expects it will be ready to begin
use of Distribution Provider’s Interconnection Facilities.
Interconnection; Interconnected: The physical connection of a Generating Facility in accordance with
the requirements of this Rule so that Parallel Operation with Distribution Provider’s Distribution or
Transmission System can occur (has occurred).
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Revised Cal. P.U.C. Sheet No. 24953-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 23121-E
RULE 21 Sheet 12
GENERATING FACILITY INTERCONNECTIONS T
(Continued)
12C10 Issued by Date Filed Jun 9, 2014
Advice Ltr. No. 2610-E Lee Schavrien Effective Jul 9, 2014
Senior Vice President
Decision No. 14-04-003 Resolution No.
C. Definitions (Continued)
Interconnection Agreement: See Generator Interconnection Agreement.
Interconnection Customer: See Applicant.
Interconnection Facilities: The electrical wires, switches and related equipment that are required in
addition to the facilities required to provide electric Distribution Service to a Customer to allow
Interconnection. Interconnection Facilities may be located on either side of the Point of Common
Coupling as appropriate to their purpose and design. Interconnection Facilities may be integral to a
Generating Facility or provided separately. Interconnection Facilities may be owned by either Producer
or Distribution Provider.
Interconnection Facilities Study: A study conducted by Distribution Provider for an Interconnection
Customer under the Independent Study Process to determine a list of facilities (including Distribution
Provider's Interconnection Facilities, Distribution Upgrades, and Network Upgrades as identified in the
Interconnection System Impact Study), the cost of those facilities, and the time required to interconnect
the Generating Facility with Distribution Provider's Distribution or Transmission System. The scope of
the study is defined in Section G.3.c.
Interconnection Financial Security: Any of the financial instruments listed in Section F.4.a.
Interconnection Request: An Applicant’s request to interconnect a new Generating Facility, or t
increase the capacity of, or make a Material Modification to the operating characteristics of, an existing
Generating Facility that is interconnected with Distribution Provider's Distribution or Transmission
System.
Interconnection Study: A study to establish the requirements for Interconnection of a Generation
Facility with Distribution Provider’s Distribution System or Transmission System, pursuant to this Rule.
Interconnection System Impact Study: An engineering study conducted by Distribution Provider for
an Interconnection Customer under the Independent Study Process that evaluates the impact of the
proposed interconnection on the safety and reliability of Distribution Provider's Distribution and/or
Transmission System and, if applicable, an Affected System. The scope of the study is defined in
Section G.3.c.i.
Island; Islanding: A condition on Distribution Provider’s Distribution System in which one or more
Generating Facilities deliver power to Customers using a portion of Distribution Provider’s Distribution
System that is electrically isolated from the remainder of Distribution Provider’s Distribution System.
Large Generating Facility: A Generating Facility having a Generating Facility Capacity of more than
20 MW.
Line Section: That portion of Distribution Provider’s Distribution or Transmission System connected to
a Customer bounded by automatic sectionalizing devices or the end of the distribution line.
Local Furnishing Bond: Tax-exempt bonds utilized to finance facilities for the local furnishing of
electric energy, as described in Internal Revenue Code, 26 U.S.C. §142(f).
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Revised Cal. P.U.C. Sheet No. 27218-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25994-E
RULE 21 Sheet 13
GENERATING FACILITY INTERCONNECTIONS
(Continued)
13C11 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Local Furnishing Distribution Provider: Any Distribution Provider that owns facilities financed by
Local Furnishing Bonds.
Mandatory Operation: The Smart Inverter operates at maximum available current without tripping
during Distribution Provider’s Transmission or Distribution System excursions outside the region of
continuous operation. Any functions that protect the Smart Inverter from damage may operate as
needed.
Material Modification: Those modifications that have a material impact on cost or timing of any
Interconnection Request with the same or a later queue priority date or a change in Point of
Interconnection. A Material Modification does not include a change in ownership of a Generating
Facility.
Metering: The measurement of electrical power in kilowatts (kW) and/or energy in kilowatt-hours (kWh),
and if necessary, reactive power in kVAR at a point, and its display to Distribution Provider, as required
by this Rule.
Metering Equipment: All equipment, hardware, software including meter cabinets, conduit, etc., that
are necessary for Metering.
Momentary Cessation: The Smart Inverter momentarily reduces current output to the Distribution
Provider’s Transmission or Distribution System to below 10% of the maximum continuous output current
rating. The Smart Inverter is allowed to increase current output to the Distribution Provider’s
Transmission or Distribution System without any intentional reconnection delay once voltage exits the
momentary cessation region and enters a permissive operation region or continuous operation region.
Momentary Parallel Operation: The Interconnection of a Generating Facility to the Distribution and
Transmission System for one second (60 cycles) or less.
Nationally Recognized Testing Laboratory (NRTL): A laboratory accredited to perform the
Certification Testing requirements under this Rule.
Net Energy Metering (NEM): Metering for the receipt and delivery of electricity between Producer and
Distribution Provider pursuant to California Public Utilities Code (PUC) Sections 2827, 2827.1 (as
implemented by Commission Decision 16-01-044), 2827.8, or 2827.10.
NEM-1: Refers to Interconnection Requests for service pursuant to Schedules NEM, VNM-A and NEM-
V.
NEM-2: Refers to Interconnection Requests for service pursuant to Schedule NEM-ST, VNM-A-ST and
NEM-V-ST.
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Revised Cal. P.U.C. Sheet No. 29028-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28107-E
RULE 21 Sheet 14
GENERATING FACILITY INTERCONNECTIONS
(Continued)
14C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Net Generation Output Metering: Metering of the net electrical power output in kW or energy in kWh,
from a given Generating Facility. This may also be the measurement of the difference between the total
electrical energy produced by a Generator and the electrical energy consumed by the auxiliary
equipment necessary to operate the Generator. For a Generator with no Host Load and/or Section 218
Load, Metering that is located at the Point of Common Coupling. For a Generator with Host Load and/or
Section 218 Load, Metering that is located at the Generator but after the point of auxiliary load(s) and
prior to serving Host Load and/or Section 218 Load.
Net Rating or Net Nameplate Rating: The Gross Rating minus the consumption of electrical power of
the auxiliary load.
Network Upgrades: Delivery Network Upgrades and Reliability Network Upgrades.
Networked Secondary System: An AC distribution system where the secondaries of the distribution
transformers are connected to a common bus for supplying electricity directly to consumers. There are
two types of secondary networks: grid networks (also referred to as area networks or street networks)
and Spot Networks. Synonyms: Secondary Network. Refer to IEEE 1547.6 for additional detail.
Nominal: Standard frequency and voltage.
Non-Emergency: Conditions or situations that are not Emergencies, including but not limited to meter
reading, inspection, testing, routine repairs, replacement, and maintenance.
Non-Export; Non-Exporting: When the Generating Facility is sized and designed such that the
Generator output is used for Host Load only and is designed to prevent the transfer of electrical energy
from the Generating Facility to Distribution Provider’s Distribution or Transmission.
Non-Islanding: Designed to detect and disconnect from a stable Unintended Island with matched load
and generation. Reliance solely on under/over voltage and frequency trip is not considered sufficient to
qualify as Non-Islanding.
Open Loop Response Time: The duration from a step change in control signal input (reference value or
system 26 quantity) until the output changes by 90 percent of its final change, before any overshoot.
Parallel Operation: The simultaneous operation of a Generator with power delivered or received by
Distribution Provider while Interconnected. For the purpose of this Rule, Parallel Operation includes only
those Generating Facilities that are Interconnected with Distribution Provider’s Distribution or
Transmission System for more than 60 cycles (one second).
Paralleling Device: An electrical device, typically a circuit breaker, operating under the control of a
synchronization relay or by a qualified operator to connect an energized generator to an energized
electric power system or two energized power systems to each other.
Party, Parties: Applicant or Distribution Provider.
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Revised Cal. P.U.C. Sheet No. 27220-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25996-E
RULE 21 Sheet 15
GENERATING FACILITY INTERCONNECTIONS
(Continued)
15C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Periodic Test: A test performed on part or all of a Generating Facility/Interconnection Facilities at pre-
determined time or operational intervals to achieve one or more of the following: 1) verify specific
aspects of its performance; 2) calibrate instrumentation; and 3) verify and re-establish instrument or
Protective Function set-points.
Permissive Operation: The Smart Inverter is allowed, but not required, to operate at any current level.
Point of Common Coupling (PCC): The transfer point for electricity between the electrical conductors
of Distribution Provider and the electrical conductors of Producer.
Point of Interconnection: The point where the Interconnection Facilities connect with Distribution
Provider’s Distribution or Transmission System. This may or may not be coincident with the Point of
Common Coupling.
Pre-Construction Activities: The actions by Distribution Provider, other than those required by an
Engineering and Procurement Agreement under Section F.3.f, undertaken prior to Construction Activities
in order to prepare for the construction of Distribution Provider’s Interconnection Facilities, Distribution
Upgrades, or Network Upgrades assigned to the Interconnection Customer, including, but not limited to,
preliminary engineering, permitting activities, environmental analysis, or other activities specifically
needed to obtain governmental approvals for Distribution Provider’s Interconnection Facilities,
Distribution Upgrades, or Network Upgrades.
Producer: The entity that executes a Generator Interconnection Agreement with Distribution Provider.
Producer may or may not own or operate the Generating Facility, but is responsible for the rights and
obligations related to the Generator Interconnection Agreement.
Production Test: A test performed on each device coming off the production line to verify certain
aspects of its performance.
Protective Function(s): The equipment, hardware and/or software in a Generating Facility (whether
discrete or integrated with other functions) whose purpose is to protect against Unsafe Operating
Conditions.
Prudent Electrical Practices: Those practices, methods, and equipment, as changed from time to time,
that are commonly used in prudent electrical engineering and operations to design and operate electric
equipment lawfully and with safety, dependability, efficiency, and economy.
Queue Position: See Section E.5.C.
Queued Capacity: Aggregate queued generation capacity (in MW) for a substation/area bus, bank or
circuit (i.e., amount of generation in the queue).
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Revised Cal. P.U.C. Sheet No. 27221-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25997-E
RULE 21 Sheet 16
GENERATING FACILITY INTERCONNECTIONS
(Continued)
16C10 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Reasonable Efforts: With respect to an action required to be attempted or taken by a Party under this
Rule, efforts that are timely and consistent with Good Utility Practice and are otherwise substantially
equivalent to those a Party would use to protect its own interests.
Reliability Network Upgrades: The transmission facilities at or beyond the point where Distribution
Provider’s Distribution System interconnects to the CAISO Controlled Grid, necessary to interconnect
one or more Generating Facility(ies) safely and reliably to the CAISO Controlled Grid, as defined in the
CAISO Tariff.
Section 218 Load: Electrical power that is supplied in compliance with California PUC section 218.
PUC section 218 defines an “Electric Corporation” and provides conditions under which a transaction
involving a Generating Facility would not classify a Producer as an Electric Corporation. These
conditions relate to “over-the-fence” sale of electricity from a Generating Facility without using
Distribution Provider’s Distribution or Transmission System.
Short Circuit Contribution Ratio (SCCR): The ratio of the Generating Facility’s short circuit
contribution to the short circuit contribution provided through Distribution Provider’s Distribution System
for a three-phase fault at the high voltage side of the distribution transformer connecting the Generating
Facility to Distribution Provider’s Distribution System.
Single Line Diagram; Single Line Drawing: A schematic drawing, showing the major electric
switchgear, Protective Function devices (including relays, current transformer and potential transformer
configurations/wiring in addition to circuit breakers/fuses), wires, Generators, transformers, meters and
other devices, providing relevant details to communicate to a qualified engineer the essential design
and safety of the system being considered.
Site Exclusivity: Documentation reasonably demonstrating: (1) For private land: (a) Ownership of, a
leasehold interest in, or a right to develop property upon which the Generating Facility will be located
consisting of a minimum of 50% of the acreage reasonably necessary to accommodate the Generating
Facility; or (b) an option to purchase or acquire a leasehold interest in property upon which the
Generating Facility will be located consisting of a minimum of 50% of the acreage reasonably necessary
to accommodate the Generating Facility. (2) For public land, including that controlled or managed by
any federal, state or local agency, a final, non-appealable permit, license, or other right to use the
property for the purpose of generating electric power and in acreage reasonably necessary to
accommodate the Generating Facility, which exclusive right to use public land under the management
of the federal Bureau of Land Management shall be in a form specified by the Bureau of Land
Management. The demonstration of Site Exclusivity, at a minimum, must be through the Commercial
Operation Date of the new Generating Facility or increase in capacity of the existing Generating Facility.
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Revised Cal. P.U.C. Sheet No. 27222-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25998-E
RULE 21 Sheet 17
GENERATING FACILITY INTERCONNECTIONS
(Continued)
17C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Small Generating Facility: A Generating Facility that has a Generating Facility Capacity of no more
than 20 MW.
Smart Inverter: A Generating Facility’s Inverter that performs functions that, when activated, can
autonomously contribute to grid support during excursions from normal operating voltage and frequency
system conditions by providing: dynamic reactive/real power support, voltage and frequency ride-
though, ramp rate controls, communication systems with ability to accept external commands, and other
functions.
Special Facilities: For SCE See Added Facilities. For PG&E and SDG&E as defined in Distribution
Provider’s Rule 2.
Spot Network: For purposes of this Rule, a Spot Network is a type of distribution system found within
modern commercial buildings to provide high reliability of service to a single customer.
Starting Voltage Drop: The percentage voltage drop at a specified point resulting from In-rush Current.
The Starting Voltage Drop can also be expressed in volts on a particular base voltage, (e.g. 6 volts on a
120-volt base, yielding a 5% drop).
Supplemental Review: See Section F.2.c.
System Integrity: The condition under which Distribution Provider’s Distribution and Transmission
System is deemed safe and can reliably perform its intended functions in accordance with the safety and
reliability rules of Distribution Provider.
Telemetering: The electrical or electronic transmittal of Metering data on a real time basis to Distribution
Provider.
Total Capacity: Capacity (in MW) of substation/area bus, bank or circuit based on normal or operating
ratings.
Transfer Trip: A Protective Function that trips a Generating Facility remotely by means of an automated
communications link controlled by Distribution Provider.
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Revised Cal. P.U.C. Sheet No. 27720-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27223-E
RULE 21 Sheet 18
GENERATING FACILITY INTERCONNECTIONS
(Continued)
18C9 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
C. Definitions (Continued)
Transient/Dynamic Stability: The ability of an electrical system to withstand disturbances.
Transient/Dynamic Stability studies are performed to ensure power system stability and are time-based
simulations that assess the performance of the power system during and shortly following system
disturbances.
Transmission Cluster Study Process: The cluster study process as defined in Distribution Provider’s
Wholesale Open Access Distribution Tariff.
Transmission System: Transmission facilities owned by Distribution Provider that have been placed
under the CAISO’s operational control and are part of the CAISO Controlled Grid, as defined in the
CAISO Tariff.
Trip: Cease to energize or disconnect from the Distribution Provider’s Transmission or Distribution
System due to a Distribution Provider’s Transmission or Distribution System disturbance. Following a
trip, the Smart Inverter must delay re-energization or reconnection for a preset period of time once the
voltage and frequency of the Distribution Provider’s Transmission or Distribution System are within
normal ranges.
Type Test: A test performed on a sample of a particular model of a device to verify specific aspects of its
design, construction and performance.
Unintended Island: The creation of an Island, usually following a loss of a portion of Distribution
Provider’s Distribution System, without the approval of Distribution Provider.
Unit Cost Guide: A published guide that is not binding for actual facility costs and is provided only for
additional cost transparency, developer reference, and Distribution Provider’s reference when preparing
the study estimate.
Unsafe Operating Conditions: Conditions that, if left uncorrected, could result in harm to personnel,
damage to equipment, loss of System Integrity or operation outside pre-established parameters required
by the Generator Interconnection Agreement.
Voltage Excursion: Beginning when Distribution Provider’s Transmission or Distribution System
voltage at the PCC exits the Near Nominal magnitude range and ending when voltage re-enters the Near
Nominal magnitude range.
VRef: The reference voltage or nominal voltage.
VRefOfs: The offset from the reference voltage due to the location of the Smart Inverter system on a
distribution feeder. This may be a setting or may be calculated dynamically from local voltage
measurements.
Wholesale Distribution Access Tariff: SDG&E’s Wholesale Open Access Distribution Tariff (WADT).
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Revised Cal. P.U.C. Sheet No. 27224-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26000-E
RULE 21 Sheet 19
GENERATING FACILITY INTERCONNECTIONS
(Continued)
19C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations
1. Authorization Required to Operate:
A Producer must comply with this Rule, execute a Generator Interconnection Agreement with Distribution
Provider, and receive Distribution Provider’s express written permission before Parallel Operation of its
Generating Facility with Distribution Provider’s Distribution or Transmission System. Distribution Provider
shall apply this Rule in a non-discriminatory manner and shall not unreasonably withhold its permission
for Parallel Operation of Producer’s Generating Facility with Distribution Provider’s Distribution or
Transmission System.
2. Separate Agreements Required for Other Services:
A Producer requiring other electric services from Distribution Provider including, but not limited to,
Distribution Service during periods of curtailment or interruption of Producer’s Generating Facility,
must enter into agreements with Distribution Provider for such services in accordance with
Distribution Provider’s Commission-approved tariffs.
3. Services Under This Tariff Limited To Interconnection:
Interconnection with Distribution Provider's Distribution or Transmission System under this Rule does
not provide a Producer any rights to utilize Distribution Provider's Distribution or Transmission
System for the transmission, distribution, or wheeling of electric power, nor does it limit those rights.
4. Compliance with Laws, Rules, and Tariffs
A Producer shall ascertain and comply with applicable Commission-approved tariffs of Distribution
Provider; applicable FERC-approved rules, tariffs, and regulations; and any local, state or federal
law, statute or regulation which applies to the design, siting, construction, installation, operation, or
any other aspect of Producer’s Generating Facility and Interconnection Facilities.
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Revised Cal. P.U.C. Sheet No. 27225-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26001-E
RULE 21 Sheet 20
GENERATING FACILITY INTERCONNECTIONS
(Continued)
20C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
5. Design Reviews and Inspections:
Distribution Provider shall have the right to review the design of a Producer's Generating and
Interconnection Facilities and to inspect a Producer's Generating and/or Interconnection Facilities
prior to the commencement of Parallel Operation with Distribution Provider’s Distribution or
Transmission System. Distribution Provider may require a Producer to make modifications as
necessary to comply with the requirements of this Rule. Distribution Provider's review and
authorization for Parallel Operation shall not be construed as confirming or endorsing Producer's
design or as warranting the Generating Facilities’ and/or Interconnection Facilities’ safety, durability
or reliability. Distribution Provider shall not, by reason of such review or lack of review, be
responsible for the strength, adequacy, or capacity of such equipment.
6. Right to Access:
A Producer’s Generating Facility and/or Interconnection Facilities shall be reasonably accessible to
Distribution Provider personnel as necessary for Distribution Provider to perform its duties and
exercise its rights under its tariffs approved by the Commission, and under any Generator
Interconnection Agreement between Distribution Provider and Producer.
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Revised Cal. P.U.C. Sheet No. 27226-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26002-E
RULE 21 Sheet 21
GENERATING FACILITY INTERCONNECTIONS
(Continued)
21C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
7. Confidentiality:
a. Scope
Confidential Information shall include, without limitation, confidential, proprietary or trade secret
information relating to the present or planned business of Applicant, Customer, Producer, or
Distribution Provider (individually referred to in Section D.7 as Party or collectively as Parties),
including all information relating to a Party's technology, research and development, business
affairs, and pricing. Distribution Provider shall not use the information contained in the
Interconnection Request to propose discounted tariffs to the Customer unless authorized to do
so by the Customer or the information is provided to Distribution Provider by the Customer
through other means.
Information is Confidential Information only if it is clearly designated or marked in writing as
confidential on the face of the document (including electronic materials), or, if the information is
conveyed orally or by inspection, if the Party providing the information orally informs the Party
receiving the information that the information is confidential. For purposes of this Rule all design,
operating specifications, and metering data provided by Applicant shall be deemed Confidential
Information regardless of whether it is clearly marked or otherwise designated as such, except
as provided in section D.7.b. below.
If requested by either Party, the other Party shall provide in writing, the basis for asserting that
the information referred to in this Article warrants confidential treatment, and the requesting
Party may disclose such writing to the appropriate Governmental Authority. Each Party shall be
responsible for the costs associated with affording confidential treatment to its information.
b. Limitations on Scope
Confidential Information shall not include information pertaining to each Interconnection Request
that may be provided in a publicly-posted queue pursuant to Section E.5.d of this Rule.
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Revised Cal. P.U.C. Sheet No. 27227-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26811-E
RULE 21 Sheet 22
GENERATING FACILITY INTERCONNECTIONS
(Continued)
22C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
b. Limitations on Scope (Continued)
Confidential Information shall not include information that: (1) is generally available to the public
other than as a result of a disclosure by the receiving Party; (2) was in the lawful possession of
the receiving Party on a non-confidential basis before receiving it from the disclosing Party; (3)
was supplied to the receiving Party without restriction by a third party, who, to the knowledge of
the receiving Party after due inquiry, was under no obligation to the disclosing Party to keep
such information confidential; (4) was independently developed by the receiving Party without
reference to Confidential Information of the disclosing Party; (5) is, or becomes, publicly known,
through no wrongful act or omission of the receiving Party; or (6) is required, in accordance with
Section D.7.d, Required Disclosure, to be disclosed by any Governmental Authority or is
otherwise required to be disclosed by law or subpoena.
Information designated as Confidential Information will no longer be deemed confidential if the
Party that designated the information as confidential notifies the other Party that it no longer is
confidential.
c. Disclosure to Commission, FERC, or their respective Staff
Notwithstanding anything in this Section D.7 to the contrary, and pursuant to 18 CFR section
1b.20 in the case of disclosure to FERC, if the Commission, FERC, or their respective staff,
during the course of an investigation or otherwise, requests information from one of the Parties
that is otherwise required to be maintained in confidence pursuant to this Rule, the Party shall
provide the requested information to the Commission, FERC, or their respective staff, within the
time provided for in the request for information. In providing the information to the Commission,
FERC, or their respective staff, the Party shall, pursuant to PUC section 583 and General Order
66-C in the case of disclosure to the Commission, and consistent with 18 CFR section 388.112
in the case of disclosure to FERC, request that the information be treated as confidential and
non-public by the Commission, FERC, and their respective staff and that the information be
withheld from public disclosure. Requests from another state regulatory body with jurisdiction
conducting a confidential investigation shall be treated in a similar manner, consistent with
applicable state rules and regulations.
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Revised Cal. P.U.C. Sheet No. 27228-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26812-E
RULE 21 Sheet 23
GENERATING FACILITY INTERCONNECTIONS
(Continued)
23C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
d. Required Disclosure
Subject to the exception in Section D.7.c, any information that a Party claims is Confidential
Information shall not be disclosed by the other Party to any person not employed or retained by
the other Party, except to the extent disclosure is (i) required by law or pursuant to an order of the
Commission or FERC; (ii) reasonably deemed by the disclosing Party to be required to be
disclosed in connection with a dispute between or among the Parties, or the defense of litigation
or dispute; (iii) otherwise permitted by consent of the other Party, such consent not to be
unreasonably withheld; (iv) necessary to fulfill its obligations under this Rule; or (v) as a
transmission or distribution service provider or a Control Area operator, including disclosing the
Confidential Information to a Regional Transmission Organization or CAISO, or to sub regional,
regional or national reliability organization or planning group under the applicable confidentiality
provisions in the relevant tariffs. Prior to any disclosures of the other Party's Confidential
Information under this subparagraph, or if any third party or Governmental Authority makes any
request or demand for any of the information described in this subparagraph, the disclosing Party
agrees to assert confidentiality and cooperate with the other Party in seeking to protect the
Confidential Information from public disclosure by confidentiality agreement, protective order or
other reasonable measures.
8. Prudent Operation and Maintenance Required
A Producer shall operate and maintain its Generating Facility and Interconnection Facilities in
accordance with Prudent Electrical Practices and shall maintain compliance with this Rule.
9. Curtailment and Disconnection
Distribution Provider may limit the operation or disconnect or require the disconnection of a
Producer’s Generating Facility from Distribution Provider’s Distribution or Transmission System at
any time, with or without notice, in the event of an Emergency, or to correct Unsafe Operating
Conditions. Distribution Provider may also limit the operation or disconnect or require the
disconnection of a Producer’s Generating Facility from Distribution Provider’s Distribution or
Transmission System upon the provision of reasonable written notice: 1) to allow for routine
maintenance, repairs or modifications to Distribution Provider’s Distribution or Transmission System;
2) upon Distribution Provider’s determination that a Producer’s Generating Facility is not in
compliance with this Rule; or 3) upon termination of the Generator Interconnection Agreement. Upon
Producer’s written request, Distribution Provider shall provide a written explanation of the reason for
such curtailment or disconnection.
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Revised Cal. P.U.C. Sheet No. 27229-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26813-E
RULE 21 Sheet 24
GENERATING FACILITY INTERCONNECTIONS
(Continued)
24C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
10. Local Furnishing Bonds
If a proposed Interconnection of a Generating Facility would impair the tax exempt status of interest
on the Local Furnishing Bonds or the deductibility of interest expense on the Local Furnishing Bonds
to the Local Furnishing Distribution Provider under the Internal Revenue Code, Treasury Regulations
and/or applicable IRS rulings, the Interconnection Customer will be required to pay the costs properly
attributable to the proposed Interconnection of such Generating Facility. The Interconnection Study
shall specify and estimate the cost of all remedial measures that address the financial impacts, if
any, on Local Furnishing Bonds that would result from an Interconnection.
11. Coordination with Affected Systems
Distribution Provider will notify the Affected System Operators that are potentially affected by an
Applicant’s Interconnection Request or group of Interconnection Requests. Distribution Provider will
coordinate the conduct of any studies required to determine the impact of the Interconnection
Request on Affected Systems with Affected System Operators and, if possible, include those results
(if available) in its applicable Interconnection Study within the time frame specified in this Rule.
Distribution Provider will include such Affected System Operators in all meetings held with Applicant
as required by this Rule. Applicant will cooperate with Distribution Provider in all matters related to
the conduct of studies and the determination of modifications to Affected Systems. A transmission
provider which may be an Affected System shall cooperate with Distribution Provider with whom
interconnection has been requested in all matters related to the conduct of studies and the
determination of modifications to Affected Systems. Applicant shall enter into an agreement with the
owner of the Affected System, as applicable. The agreement shall specify the terms governing
payments to be made by Applicant to the owner of the Affected System as well as the repayment, if
applicable, by the owner of the Affected System.
12. Transferability of Interconnection Request
An Applicant may transfer its Interconnection Request to another entity only if such entity acquires
the proposed Generating Facility identified in the Interconnection Request and the Point of
Interconnection does not change.
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Revised Cal. P.U.C. Sheet No. 28011-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27230-E
RULE 21 Sheet 25
GENERATING FACILITY INTERCONNECTIONS
(Continued)
25C9 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
13. Special Provisions Applicable to Certain Net Energy Metered Applicants
Notwithstanding any other provision in this Rule:
a. For NEM Generating Facilities with a capacity of 1 MW or smaller, Distribution Provider may
proceed from Initial to Supplemental Review to Independent Study Process or Distribution Group
Study Process to further study without waiting for Applicant concurrence, since Applicant is not
responsible for payment of study costs. Except as provided in Section D.13.e below, for NEM-2
Generating Facilities with a capacity greater than 1 MW, the special provisions contained within
Section D.13 and other exemptions applicable to NEM Applicants contained within this Rule do
not apply. Instead, all provisions applicable to non-NEM Interconnection Requests shall apply,
including but not limited to the requirement to pay all Interconnection Request fees, study costs
and upgrade costs, and the adherence to all non-NEM timeline and interconnection provisions
contained within Rule 21. However, if Applicant selects the Cost Envelope Option, Applicant is
responsible for the deposit and cost associated with the Cost Envelope Option in accordance
with Section F.7.
b. For NEM-1 and NEM-2 Generating Facilities with a capacity equal to or less than 1 MW , Distribution
Provider approval for Interconnection (i.e., Permission to Operate) shall normally be processed not
later than thirty (30) Business Days following Distribution Provider’s receipt of 1) a completed
Net Energy Metering Interconnection Request including all supporting documents and required
payments; 2) a completed signed Net Energy Metering Generator Interconnection Agreement;
and 3) evidence of Applicant’s final electric inspection clearance from the Governmental
Authority having jurisdiction over the Generating Facility. If the 30-day period cannot be met,
Distribution Provider shall notify Applicant and the Commission of the reason for the inability to
process the Interconnection Request and the expected completion date. However, Applicants
that include non-inverter based Generators. Generators with non-Certified Equipment and/or
Interconnection Requests that are anticipated to require new services (i.e., NEM-A) and/or the
design and construction of Interconnection Facilities or Distribution Upgrades should plan to
submit a completed Net Energy Metering Interconnection Request including all supporting
documents sufficient for Distribution Provider to start the review process in Section F.2.a without
waiting for the final inspection clearance. Applicants with such Generating Facilities are advised
to submit their Interconnection Request at least six (6) months in advance of their planned
Commercial Operation Date. Depending on the size and location of these Generating Facilities,
additional time for review may be required and could include Supplemental Review, an
Interconnection Impact System Impact Study and an Interconnection Facilities as set out in
Section F. The advance submission of the Interconnection Request will better accommodate
Distribution Provider’s review and studies in a manner consistent with the timelines established
in this Rule that may be required to complete the processing for these types of Interconnection
Requests.
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Revised Cal. P.U.C. Sheet No. 28145-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27231-E
RULE 21 Sheet 26
GENERATING FACILITY INTERCONNECTIONS
(Continued)
26C7 Issued by Date Filed Oct 21, 2016
Advice Ltr. No. 2987-E Dan Skopec Effective Mar 30, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
13. Special Provisions Applicable to Net Energy Metered Applicants (continued)
c. Unless Net Generator Output Metering is required, Metering Equipment necessary to obtain
service under NEM-1 or NEM-2 shall be installed and operational within the timeframe required
to complete Interconnection.
d. An Applicant with a Fast Track Interconnection Request for a NEM-1 or NEM-2 Generating
Facility with a capacity that is equal to or less than 1MW that 1) goes for more than one year from
the date of Distribution Provider's written notification that the Interconnection Request is valid
without a signed Generator Interconnection Agreement, or 2) has a Generating Facility that has
not been approved for Parallel Operation within one year of completion of all applicable review
and/or studies, is subject to withdrawal by Distribution Provider; however, Distribution Provider
may not deem the Interconnection Request to be withdrawn if i) Applicant provides reasonable
evidence that the Interconnection Request is still active or ii) the delay is at no fault of Applicant.
e. For the purposes of establishing the interconnection requirements for NEM Generating Facilities
qualifying for service under PUC Section 2827(b)(4)(B) (i.e. the California Department of
Corrections and Rehabilitation) with a capacity greater than one megawatt (1 MW), Distribution
Provider shall be afforded a prudent but necessary time as mutually agreed to in writing by the
Distribution Provider and the CDCR to study the impacts of the Interconnection Request. In the
event that Distribution Provider and the CDCR are unable to mutually agree upon this prudent
but necessary study time, the study time shall then be determined by the executive director of
the Commission. If the study reveals the need for upgrades to the Transmission and/or
Distribution System arising solely from the Interconnection Request, Distribution Provider shall
be afforded the time necessary to complete those upgrades before the Generating Facility is
interconnected. The costs of the Network and/or Distribution Upgrades shall be borne by the
Interconnection Customer, but the exemption from application fees and study costs applicable
to Generating Facilities eligible for Net Energy Metering under PUC Section 2827 shall apply.
Distribution Provider shall consider the submission date of the completed Interconnection
Request Application when completing the study allowed for herein and for purposes of
determining the appropriate cost responsibility for the necessary Network and/or Distribution
Upgrades, if any, triggered solely by the Interconnection Request. All Generating Facilities
interconnected pursuant to this section shall comply with applicable state and federal
requirements, including requirements of the FERC. These same provisions also apply to the
Interconnection Requests of the CDCR for NEM Generating Facilities with a capacity greater
than 1 MW that are eligible and applying for service under NEM-2 , except that the CDCR shall
be additionally responsible for any application fees and study costs applicable under the NEM-
2Interconnection Request.
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Revised Cal. P.U.C. Sheet No. 28146-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28012-E
RULE 21 Sheet 27
GENERATING FACILITY INTERCONNECTIONS
(Continued)
27C11 Issued by Date Filed Oct 21, 2016
Advice Ltr. No. 2987-E Dan Skopec Effective Mar 30, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
13. Special Provisions Applicable to Net Energy Metered Applicants (continued)
f. For the purposes of establishing the interconnection requirements for United States Armed
Forces (USAF) bases or facilities with Generating Facilities qualifying for service under PUC
Section 2827(b)(4)(C), Distribution Provider shall be afforded a prudent but necessary time as,
mutually agreed to in writing by the Distribution Provider and the USAF, but not less than 60
Business Days, to study the impacts of the Interconnection Request. In the event Distribution
Provider and USAF are unable to mutually agree upon this prudent but necessary study time, the
study time shall then be determined by the executive director of the Commission. If the study
reveals the need for upgrades to the Transmission and/or Distribution System arising solely from
the interconnection, Distribution Provider shall be afforded the time necessary to complete those
upgrades before the Generating Facility is interconnected. The costs of the Network and/or
Distribution Upgrades shall be borne by the Interconnection Customer, but the exemption from
application fees and study costs applicable to Generating Facilities eligible for Net Energy
Metering under PUC Section 2827 shall apply. Distribution Provider shall consider the
submission date of the completed Interconnection Request Application when completing the
study allowed for herein and for purposes of determining the appropriate cost responsibility for
the necessary Network and/or Distribution Upgrades, if any, triggered solely by the
interconnection. All Generating Facilities that interconnect pursuant to this section shall comply
with applicable state and federal requirements, including requirements of the FERC. These same
provisions also apply to the Interconnection Requests of the USAF for NEM Generating Facilities
with a capacity greater than 1 MW that are eligible and applying for service under NEM-2, except
that the USAF shall be additionally responsible for any application fees and study costs
applicable under the NEM-2 Interconnection Request.
Additionally, for any renewable generation facility that interconnects directly to the transmission
grid or that requires transmission upgrades, the USAF base or facility shall comply with all FERC
interconnection procedures and requirements g. Applicants with an Interconnection Request for a Net Energy Metering Generating Facility, or a
Non-Export Generating Facility, shall have the opportunity to select the Cost Envelope Option in
accordance with Section F.7. Applicants who are determined to not have responsibility for any applicable upgrade costs will be automatically withdrawn from the Cost Envelope Option.
14. Special Provisions Applicable to Non-Export Battery Storage Generating Facilities Applicants with Non-Export Energy Storage Generating Facilities that meet the criteria listed in
Section N shall be eligible to elect to have their Interconnection Requests processed in an expedited timeframe, subject to the terms and conditions of Section N.
15. Compliance with Established Timelines
Distribution Provider shall use Reasonable Efforts in meeting all the timelines provided for under this
Rule. In the event Distribution Provider is not able to meet a particular timeline set forth in this Rule,
Distribution Provider shall notify Applicant as soon as practicable and provide an estimated
completion date with an explanation of the reasons why additional time is needed. Any Applicant
dissatisfied with the Reasonable Efforts of Distribution Provider may use the informal procedures set
out in Section F.1.d and/or the Dispute Resolution process in Section K.
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Revised Cal. P.U.C. Sheet No. 28147-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27721-E
RULE 21 Sheet 28
GENERATING FACILITY INTERCONNECTIONS
(Continued)
28C8 Issued by Date Filed Oct 21, 2016
Advice Ltr. No. 2987-E Dan Skopec Effective Mar 30, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
D. General, Rules, Rights and Obligations (Continued)
16. Modification of Timelines
Distribution Provider and Applicant, for good cause, may agree to modify any of the timelines in this
Rule. The modified timeline shall be mutually agreed upon, in writing, between Distribution Provider
and Applicant.
E. Interconnection Request Submission Process
1. Optional Standard and Enhanced Pre-Application Report
a. Standard Pre-Application Report
Upon receipt of a completed Pre-Application Report Request and a non-refundable processing
fee of $300, Distribution Provider shall provide pre-application data described in this section
within ten (10) Business Days of receipt. The Pre-Application Report Request shall include a
proposed Point of Interconnection, generation technology and fuel source. The proposed Point
of Interconnection shall be defined by latitude and longitude, site map, street address, utility
equipment number (e.g. pole number), meter number, account number or some combination of
the above sufficient to clearly identify the location of the point of interconnection.
The Pre-Application Report will include the following information if available:
1. Total Capacity (MW) of substation/area bus or bank and circuit likely to serve proposed site 2. Allocated Capacity (MW) of substation/area bus or bank and circuit likely to serve proposed site. 3. Queued Capacity (MW) of substation/area bus or bank and circuit likely to serve proposed site. 4. Available Capacity (MW) of substation/area bus or bank and circuit most likely to serve proposed site. 5. Substation nominal distribution voltage or transmission nominal voltage if applicable. 6. Nominal distribution circuit voltage at the proposed site. 7. Approximate circuit distance between the proposed site and the substation. 8. Relevant Line Section(s) peak load estimate, and minimum load data, when available. 9. Number of protective devices and number of voltage regulating devices between the proposed site and the substation/area. 10. Whether or not three-phase power is available at the site. 11. Limiting conductor rating from proposed Point of Interconnection to distribution substation. 12. Based on proposed Point of Interconnection, existing or known constraints such as, but not limited to, electrical dependencies at that location, short circuit interrupting capacity issues, power quality or stability issues on the circuit, capacity constraints, or secondary networks. 13. Nominal distribution circuit voltage and wiring configuration.
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Revised Cal. P.U.C. Sheet No. 27722-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27234-E
RULE 21 Sheet 29
GENERATING FACILITY INTERCONNECTIONS
(Continued)
29C9 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
1. Optional Standard and Enhanced Pre-Application Report (Continued)
b. Enhanced Pre-Application Report
The Enhanced Pre-Application Report Request shall be submitted in parallel with the Standard
Pre-Application Report. Requests that exclude the Standard Pre-Application Report and select
only one or both of the Enhanced Pre-Application Report packages shall be assessed an
additional non-refundable fee of $100.
The Enhanced Pre-Application Report shall include a proposed Point of Interconnection,
generation technology and fuel source. The proposed Point of Interconnection shall be defined
by latitude and longitude, site map, street address, utility equipment number (e.g. pole number),
meter number, account number or some combination of the above sufficient to clearly identify the
location of the point of interconnection.
The information included in the Enhanced Pre-Application Report is dependent upon the data
package selected by Applicant
1. Primary Service Package
Upon receipt of a completed Enhanced Pre-Application Report Request for Primary Service
Package and a non-refundable fee of $225, and additional $100 fee if applicable, Distribution
Provider shall provide the enhanced pre-application data described in this section within ten
(10) Business Days of receipt.
The Primary Service Package will include the following information if available:
i) Relevant line section(s) absolute minimum load and minimum load during the 10 AM – 4
PM period (provided when SCADA data is available).
ii) Existing upstream protection including:
(a) Device type (Fuse Breaker, Recloser)
(b) Device controller (device make/model ex: 50E/50T)
(c) Phase settings [IEEE Curve, Lever, Min Trip (A), Inst Trip(A)]
(d) Ground settings [IEEE Curve, Lever, Min Trip (A), Inst Trip(A)]
(e) Rated continuous current
(f) Short Circuit interrupting capability
(g) Confirm if the device is capable of bi-directional operation
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Revised Cal. P.U.C. Sheet No. 27723-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27235-E
RULE 21 Sheet 30
GENERATING FACILITY INTERCONNECTIONS
(Continued)
30C10 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
1. Optional Standard and Enhanced Pre-Application Report (Continued)
b. Enhanced Pre-Application Report (Continued)
1. Primary Service Package (Continued)
iii) Provide the Available Fault Current at the proposed Point of Interconnection including
existing distributed generation fault contribution.
2. Behind the Meter Interconnection Package
Upon receipt of a completed Enhanced Pre-Application Report Request for Behind the Meter
Interconnection Package and a non-refundable fee of $800, and additional $100 fee if
applicable, Distribution Provider shall provide the enhanced pre-application data described
in this section within thirty (30) Business Days of receipt. Distribution Provider shall conduct
a physical verification based on field confirmation.
If a third party is submitting an Enhanced Pre-Application Report Request for Behind the
Meter Interconnection Package on behalf of the Applicant, an Authorization to Receive
Customer Information or Act on a Customer’s Behalf [Form 185-1000] shall be required to
be submitted as part of the Pre-Application Report Request. Distribution Provider shall
notify the Applicant if additional processing time will be required.
The Behind the Meter Interconnection Package will include the following information if
available:
i) Relevant line section(s) absolute minimum load, and minimum load during the 10 AM –
4 PM period (provided when SCADA data is available)
(a) Existing service transformer kVA rating
(b) Primary Voltage and secondary Voltage rating
(c) Configuration on both Primary and Secondary Side (i.e., Delta, Wye,
Grounded Wye, etc.)
(d) Characteristic impedance (%Z)
(e) Confirm if the transformer is serving only one customer or multiple
customers
(f) Provide the Available Fault Current on both the Primary and Secondary Side
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Revised Cal. P.U.C. Sheet No. 27724-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27236-E
RULE 21 Sheet 31
GENERATING FACILITY INTERCONNECTIONS
(Continued)
31C10 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
1. Optional Standard and Enhanced Pre-Application Report (Continued)
b. Enhanced Pre-Application Report (Continued)
2. Behind the Meter Interconnection Package (Continued)
ii) Secondary Service Characteristics
(a) Conductor type (AL or CU) and size (AWG)
(b) Conductor insulation type
(c) Number of parallel runs
(d) Confirm if the existing secondary service is 3-wire or 4-wire
iii) Primary Service Characteristics
(a) Conductor type (AL or CU and size (AWG)
(b) Conductor insulation type
(c) Number of parallel runs
(d) Confirm if the existing primary service is 3-wire or 4-wire
3. Combined Primary Service and Behind the Meter Interconnection Packages
Applicant may choose to request a combination of the Combined Primary Service Package
and Behind the Meter Interconnection Package. Upon receipt of the applicable non-
refundable fee of $1,025, and additional $100 fee if applicable, Distribution Provider shall
provide the enhanced pre-application data described in this section within thirty (30)
Business Days of receipt.
If a third party is submitting an Enhanced Pre-Application Report Request for Behind the
Meter Interconnection Package on behalf of the Applicant, an Authorization to Receive
Customer Information or Act on a Customer’s Behalf [Form 185-1000] shall be processed in
accordance with the instructions therein, and shall be required to be submitted at the same
time as part of the Pre-Application Report Request. Distribution Provider shall notify the
Applicant if additional processing time will be required.
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Revised Cal. P.U.C. Sheet No. 27725-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27237-E
RULE 21 Sheet 32
GENERATING FACILITY INTERCONNECTIONS
(Continued)
32C9 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
1. Optional Standard and Enhanced Pre-Application Report (Continued)
c. Limitation and Scope of Optional Standard and Enhanced Pre-Application Report
Except as provided specifically in this Section E. 1, the Optional Standard and Enhanced Pre-
Application Reports (Pre-Application Report(s)) need only include pre-existing data and does not
obligate Distribution Provider to conduct a study or other analysis of the proposed project. For
all Pre-Application Reports, if Distribution Provider cannot complete all or some of the Pre-
Application Report responses due to lack of available data, Distribution Provider will provide
Applicant with a Pre-Application Report that includes the information that is available.
In requesting a Pre-Application Report, Applicant understands that 1) the existence of “Available
Capacity” in no way implies that an interconnection up to this level may be completed without
impacts since there are many variables studied as part of the interconnection review process, 2)
the distribution system is dynamic and subject to change and 3) data provided in the Pre-
Application Report may become outdated and not useful at the time of submission of the
complete Interconnection Request. Notwithstanding any of the provisions of this Section,
Distribution Provider shall, in good faith, provide Pre- Application Report data that represents the
best available information at the time of reporting.
2. Interconnection Request Process
a. Applicant Initiates Contact with Distribution Provider:
Upon request, Distribution Provider will provide information and documents (such as sample
agreements, Interconnection Request, technical information, listing of Certified Equipment, Initial
and Supplemental Review fee information, applicable tariff schedules and Metering
requirements) to a potential Applicant. Unless otherwise agreed upon, all such information shall
normally be sent to an Applicant within three (3) Business Days following the initial request from
Applicant. Distribution Provider will establish an individual representative as the single point of
contact for Applicant, but may allocate responsibilities among its staff to best coordinate the
Interconnection of an Applicant’s Generating Facility.
b. Applicant Selects a Study Process
An Applicant may select one of two interconnection evaluation processes in accordance with the
following eligibility requirements:
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Revised Cal. P.U.C. Sheet No. 27726-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27238-E
RULE 21 Sheet 33
GENERATING FACILITY INTERCONNECTIONS
(Continued)
33C8 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
2. Interconnection Request Process (Continued)
b. Applicant Selects a Study Process (Continued)
i) Fast Track Eligibility
Non-Exporting Generating Facilities and NEM-1 Generating Facilities are eligible for Fast Track
evaluation regardless of the Gross Nameplate Rating of the proposed Generating Facility.
NEM-2 Generating Facilities and Exporting Generating Facilities with a Gross Nameplate
Rating no larger than 1.5 MW on a 12 kV interconnection are also eligible for Fast Track
evaluation. For an Exporting Generating Facility that agrees to the installation of Distribution
Provider-approved protective devices at Applicant’s cost such that the Exporting Generating
Facility’s net export will never exceed the Fast Track eligibility limits, the Generating Facility’s
net export will be considered for purposes of Fast Track eligibility. However, these
Interconnection Requests will be required to complete Supplemental Review and Applicants
should pre-pay for Supplemental Review at the time the Interconnection Request is
submitted.
ii) Detailed Study Eligibility
Applicants with Interconnection Requests that are not eligible for Fast Track evaluation must
apply for Detailed Study. An Applicant may also choose to apply directly for Detailed Studies.
Detailed Study shall require either (i) an Independent Study Process, (ii) a Distribution Group
Study Process, or (iii) a Transmission Cluster Study Process. The specific study process
used will depend on the results of the Electrical Independence Tests for the Transmission
and Distribution Systems.
iii) Request for Deliverability Assessment.
Unless specified otherwise in the Interconnection Request, Generating Facilities eligible to
be studied under the Fast Track Process, Independent Study Process or Distribution Group
Study Process will be assumed to have selected Energy-Only Deliverability Status. Nothing
herein will prohibit an Applicant from seeking a deliverability assessment in accordance with
the WDAT. Applicants studied under the Transmission Cluster Study Process may seek a
deliverability assessment in accordance with the applicable provisions of the WDAT.
c. Applicant Completes an Interconnection Request
All Applicants shall submit a complete and valid Interconnection Request. When applicable per
Table E.1, a nonrefundable $800 Interconnection Request fee, and for Applicants that elect
Detailed Study in the Interconnection Request, a study deposit shall be required per instructions
in the Interconnection Request. Applicants who proceed to Detailed Study after Fast Track will
provide a Detailed Study deposit as specified in Section E.3.a.
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Revised Cal. P.U.C. Sheet No. 27727-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27239-E
RULE 21 Sheet 34
GENERATING FACILITY INTERCONNECTIONS
(Continued)
34C8 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
2. Interconnection Request Process (Continued)
c. Applicant Completes an Interconnection Request (Continued)
Applicant shall submit a separate Interconnection Request for each Point of Interconnection. An
Interconnection Request for the expansion of capacity of an existing operating Generating
Facility shall be treated the same as an Interconnection Request for a new Generating Facility
pursuant to this Rule.
i) Interconnection Requests for the Independent Study Process will be accepted throughout the
year, except during the Distribution Group Study windows. All Detailed Study Interconnection
Requests (except those applying directly to the Transmission Cluster Study Process)
submitted during the Distribution Group Study windows will be processed as Distribution
Group Study Process Applicants.
ii) Interconnection Requests to be studied under the Distribution Group Study Process shall
either be (a) an Independent Study Process Interconnection Request that passed screen Q
and failed Screen R for which the Applicant elects to continue to the next available
Distribution Group Study, or (b) an Interconnection Request submitted during a Distribution
Group Study Application window that passes Screen Q.
There will normally be two (2) Distribution Group Study Application windows annually. The first
Distribution Group Study Application window will usually open on March 1 and close on March
31. The second Distribution Group Study Application window will usually open on September 1
and close on September 30. In the event that any date set in this Section is not a Business Day,
then the applicable date shall be the next Business Day thereafter.
The Distribution Provider may change the Distribution Group Study Application window interval
and opening or closing dates. Any changes will be posted on the Distribution Provider’s website.
If there is a conflict between the Distribution Group Study Application window interval and
opening or closing dates posted on the Distribution Provider’s website and the dates identified in
the paragraph above, the dates posted on the Distribution Provider’s website shall apply.
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Revised Cal. P.U.C. Sheet No. 28013-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27728-E
RULE 21 Sheet 35
GENERATING FACILITY INTERCONNECTIONS
(Continued)
35C10 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued) 2. Interconnection Request Process (Continued) c. Applicant Completes an Interconnection Request (Continued) Table E.1 - Summary of Interconnection Request Fees, Deposits and Exemptions
Generating
Facility Type
Interconnection
Request Fee
Supplemental
Review Fee
Detailed Study Deposit Additional
Commissioning
Test Verification
Cost
Envelope
Option
Deposit***
Non-Net Energy
Metering and
NEM-2 facilities
with a capacity
greater than 1
MW
$800 $2,500**
For a Generating Facility with a
Gross Nameplate Rating of 5 MW
or less and applying to the
Independent Study Process,
$10,000 for a System Impact
Study or the DGS Phase I
Interconnection Study in the case
of the Distribution Group Study
Process; and $15,000 for an
Interconnection Facilities Study or
DGS Phase II Interconnection
Study in the case of the
Distribution Group Study
Process. For a Generating Facility with a
Gross Nameplate Rating above 5
MW, $50,000 plus $1,000 per
MW of electrical output of the
Generating Facility, or the
increase in electrical output of the
existing Generation Facility, as
applicable, rounded up to the
nearest whole MW, up to a
maximum of $250,000.
$150/Person
Hour * $2,500
NEM-2 with a
Capacity of 1 MW
or Smaller (per
PUC Section
2827.1 and D.16-
01-044)***
$132 $0 $0 N/A $2,500
Net Energy
Metering (per
PUC Sections
2827 2827.8, or
2827.10 (per
D.02-03-057)
$0 $0 $0 N/A $2,500
Solar 1MW or less
that does not sell
power to
Distribution
Provider (per
D.01-07-027)
First $5,000 of study fees waived $150/Person
Hour * $2,500
* Plus additional costs for travel, lodging and meals.
** Optional $1,000 additional fault current study fee pursuant to Section F.2.c.ii *** Interconnection Requests that have selected the Cost Envelope Option and that subsequently qualify for and pass the Fast Track
Process evaluation, as well as NEM Generating Facilities and Solar ≤ 1 MW Generating Facilities evaluated under the Independent
Study Process, must provide the Cost Envelope Option deposit in accordance with Section F.7 to remain eligible for the Cost Envelope
Option.
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Revised Cal. P.U.C. Sheet No. 27729-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27241-E
RULE 21 Sheet 36
GENERATING FACILITY INTERCONNECTIONS
(Continued)
36C9 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
2. Interconnection Request Process (Continued)
d. Site Exclusivity
Documentation of Site Exclusivity must be submitted with the Interconnection Request. This
requirement does not apply to Applicants with NEM-1 Generating Facilities, NEM-2 Generating
Facilities 1 MW or less, or Non-Export Generating Facilities.
3. Interconnection Request Fee and Study Deposit
The Interconnection Request fee shall be waived for NEM-1 Interconnection and for non-NEM solar-
powered Generating Facilities that do not sell power per Commission Decision 01-07-027. NEM-1
Generating Facilities are also exempt from any costs associated with Interconnection Studies.
NEM-2 Applicants are required to pay any applicable Interconnection Request fees and costs
associated with Interconnection Studies pursuant to Table E.1. As noted in the table, SASH
participants are exempt from the NEM-2 Interconnection Request Fee and NEM-2 ≤1 MW Applicants
are exempt from costs associated with Interconnection Studies.
Interconnection Study fees for non-NEM solar ≤1 MW Generating Facilities interconnecting to the
Distribution System that do not sell power will be waived up to the amount of $5,000.
a. Detailed Study Deposit
i) Detailed Study Deposit
To proceed with Detailed Study, Applicant must submit a Detailed Study deposit.
For a Generating Facility with a Gross Nameplate Rating of 5 MW or less, Applicant must
submit a Detailed Study deposit of $10,000 for the Interconnection System Impact Study or
the DGS Phase I Interconnection Study, and where an Interconnection Facilities Study or
DGS Phase II Interconnection Study in the case of the Distribution Group Study Process is
required, an additional $15,000 deposit must be submitted as required in Section F.3.b.vi or
F.3.c.viii.
For a Generating Facility with a Gross Nameplate Rating above 5 MW, Applicant must
submit a Detailed Study deposit equal to $50,000 plus $1,000 per MW of electrical output of
the Generating Facility, or the increase in electrical output of the existing Generating Facility,
as applicable, rounded up to the nearest whole MW, up to a maximum of $250,000.
ii) Use of Detailed Study Deposit
The Detailed Study deposit shall be applied to pay for prudent costs incurred by Distribution
Provider, the CAISO, or third parties at the direction of Distribution Provider or CAISO, as
applicable, to perform and administer the Interconnection Studies. Deposit amounts that
exceed the prudent costs incurred by Distribution Provider shall be refunded to Applicant
within sixty (60) Calendar Days following either the execution of the Generator
Interconnection Agreement or project withdrawal as described in more detail below.
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Revised Cal. P.U.C. Sheet No. 27730-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27242-E
RULE 21 Sheet 37
GENERATING FACILITY INTERCONNECTIONS
(Continued)
37C9 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
3. Interconnection Request Fee and Study Deposit (Continued)
ii) Use of Detailed Study Deposit (Continued)
The interconnection study costs for a Distribution Study Group shall be allocated equally
among the Interconnection Requests within the Distribution Study Group, except as provided
in (3) below.
The Detailed Study deposits shall be refundable as follows:
(1) Should an Interconnection Request be withdrawn by Applicant or be deemed withdrawn
by Distribution Provider by written notice under Section F.6 on or before thirty (30)
Calendar Days following the scoping meeting, Distribution Provider shall refund to
Applicant any portion of Applicant’s Detailed Study deposit that exceeds the costs
Distribution Provider, CAISO, and third parties have incurred on Applicant’s behalf,
including interest from the date of receipt by Distribution Provider to the date of payment
to Applicant. The applicable interest shall be one-twelfth of the Federal Reserve three-
month Commercial Paper Rate – Non-Financial, from the Federal Reserve Statistical
Release H.15 (expressed as an annual rate).
(2) Should an Interconnection Request that has been moved into the Detailed Study
Process be withdrawn by Applicant or be deemed withdrawn by Distribution Provider by
written notice under Section F.6 more than thirty (30) Calendar Days after the scoping
meeting, but on or before thirty (30) Calendar Days following the results meeting for the
Interconnection System Impact Study or DGS Phase I Interconnection Study, Distribution
Provider shall refund to Applicant the difference between (i) Applicant’s Detailed Study
deposit and (ii) the greater of (a) the costs Distribution Provider, CAISO, and third parties
have incurred on Applicant’s behalf or (b) one-half of the original Detailed Study deposit
up to a maximum of $100,000, including interest from the date of receipt by Distribution
Provider to the date of payment to Applicant. The applicable interest shall be one-twelfth
of the Federal Reserve three-month Commercial Paper Rate – Non-Financial, from the
Federal Reserve Statistical Release H.15 (expressed as an annual rate).
(3) Should an Interconnection Request be withdrawn by Applicant or be deemed withdrawn
by Distribution Provider by written notice under Section F.6 at any time more than thirty
(30) Calendar Days after the results meeting for the Interconnection System Impact
Study or DGS Phase I Interconnection Study, or thirty (30) Calendar Days after issuance
of the final Interconnection System Impact Study report or DGS Phase I Interconnection
Study report if a results meeting is not held, the Detailed Study deposit shall be non-
refundable.
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Revised Cal. P.U.C. Sheet No. 27731-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27243-E
RULE 21 Sheet 38
GENERATING FACILITY INTERCONNECTIONS
(Continued)
38C7 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
3. Interconnection Request Fee and Study Deposit (Continued)
ii) Use of Detailed Study Deposit (Continued)
(4) Upon execution of a Generator Interconnection Agreement by an Applicant and
Distribution Provider Distribution Provider shall refund to Applicant any portion of
Applicant’s Detailed Study deposit that exceeds the costs Distribution Provider, CAISO,
and third parties have incurred on Applicant’s behalf, including interest from the date of
receipt by Distribution Provider to the date of payment to Applicant. The applicable
interest shall be one-twelfth of the Federal Reserve three-month Commercial Paper Rate
– Non-Financial, from the Federal Reserve Statistical Release H.15 (expressed as an
annual rate).
iii) Impact of Withdrawal
(1) Notwithstanding the foregoing, an Applicant that withdraws or is deemed to have
withdrawn its Interconnection Request shall be obligated to pay to Distribution Provider
all costs in excess of the Detailed Study deposit that have been prudently incurred or
irrevocably have been committed to be incurred with respect to that Interconnection
Request prior to withdrawal. Distribution Provider will reimburse the CAISO or third
parties, as applicable, for all work performed on behalf of the withdrawn Interconnection
Request at Distribution Provider’s direction. Applicant must pay all monies due before it
is allowed to obtain any Interconnection Study data or results. Any proceeds of the
Detailed Study deposit not otherwise reimbursed to Applicant or applied to costs incurred
or irrevocably committed to be incurred for the interconnection studies shall be applied
as directed by the Commission. Where an Applicant with remaining proceeds from a
Detailed Study deposit cannot be located, such remaining proceeds shall escheat to the
State pursuant to the Unclaimed Property Law commencing with the California Code of
Civil Procedure §1500.
(2) Forfeited Study Deposit for Distribution Group Study Process
Non-refundable Detailed Study deposits, as pursuant to Section E.3.a.ii, for a Distribution
Group Study Process Interconnection Request, shall be applied to the costs associated
with any following Interconnection Study or restudy work performed by Distribution
Provider, CAISO, or third party for the withdrawn Interconnection Request’s Distribution
Study Group. Any remaining proceeds of the Detailed Study deposit, after the withdrawn
Interconnection Request’s Distribution Study Group has completed all relevant
Interconnection Studies or restudies, or all Interconnection Requests associated with the
specific Distribution Study Group have withdrawn, not otherwise applied to costs
incurred, or irrevocably committed to be incurred for the Interconnection Studies or
restudies, shall be allocated to individual Applicants on a kVA basis who have remained
in the Distribution Study Group by executing a Generator Interconnection Agreement.
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Revised Cal. P.U.C. Sheet No. 27732-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27244-E
RULE 21 Sheet 39
GENERATING FACILITY INTERCONNECTIONS
(Continued)
39C7 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
3. Interconnection Request Fee and Study Deposit (Continued)
(2) Forfeited Study Deposit for Distribution Group Study Process (Continued)
Such funds shall be allocated to Applicants sixty (60) Calendar Days following the conclusion of
the Generator Interconnection Agreement negotiation pursuant to Section F.3.e.ii. If no
Applicants remain in the Distribution Study Group, such funds shall escheat to the State
pursuant to the Unclaimed Property Law commencing with the California Code of Civil
Procedure § 1500.
iv) Special Circumstances
Applicant may propose, and Distribution Provider may agree, to reduced costs for reviewing
atypical Interconnection Requests, such as Interconnection Requests submitted for multiple
Generating Facilities, multiple sites, or otherwise as conditions warrant.
4. Interconnection Cost Responsibility
An Applicant, or a Producer where those are different entities, is responsible for all fees and/or costs,
including Commissioning Testing, required to complete the interconnection process. A Producer that
interconnects to Distribution Provider’s Distribution or Transmission System is responsible for all
costs associated with Parallel Operation to support the safe and reliable operation of the Distribution
and Transmission System. NEM- 1 Generating Facilities and NEM-2 Generating Facilities with a
capacity that is equal to or less than 1 MW are exempt from any costs associated with Distribution or
Network Upgrades.
a. Costs of Interconnection and Parallel Operation
The Interconnection and Parallel Operation of a Producer may trigger the need for
Interconnection Facilities, Special Facilities or Added Facilities, Upgrades, Delivery Network
Upgrades, and/or Reliability Network Upgrades. Interconnection Facilities installed on Producer’s
side of the PCC may be owned, operated and maintained by Producer or Distribution Provider.
Interconnection Facilities installed on Distribution Provider’s side of the PCC and Distribution
System modifications shall be owned, operated, and maintained only by Distribution Provider.
b. Methodology and Timing of Cost Identification
Any costs triggered by a Producer are based on Producer’s unique Interconnection
requirements, Producer’s impact on the Distribution System and/or Transmission System
following allocation of capacity to earlier-queued interconnection requests, and Producer’s
electrical interdependence with any earlier-queued interconnection requests. Earlier-queued
interconnection requests include interconnection requests under any applicable tariff.
L
L
Revised Cal. P.U.C. Sheet No. 27733-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27245-E
RULE 21 Sheet 40
GENERATING FACILITY INTERCONNECTIONS
(Continued)
40C8 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
4. Interconnection Cost Responsibility (Continued)
c. Timing of Cost Identification
For Applicants to Fast Track, Independent Study Process, or Distribution Group Study Process,
costs may be identified during the study process, or after the study process is complete and a
Generator Interconnection Agreement is executed. The purpose of later identification of costs is
to facilitate Applicant’s Interconnection while accommodating incomplete interconnection studies
for earlier-queued interconnection requests to the same Line Section and/or distribution circuit,
and/or substation, incomplete interconnection studies for earlier-queued interconnection requests
with which Applicant is electrically interdependent with respect to short circuit duty, withdrawal of
earlier-queued interconnection requests for Interconnection to the Distribution or Transmission
System, and delay or cancellation of planned Distribution System Upgrades.
d. Producer Costs During Parallel Operation
All Producers are required to provide and maintain Interconnection Facilities, for the duration of
the Generator Interconnection Agreement, that meet Distribution Provider’s technical design and
operating standards for Parallel Operation as set out in Section H or Hh, including any updates to
those standards. This includes Producer responsibility for costs associated with changes to the
operating characteristics at the Point of Interconnection necessitated by Distribution Provider’s
upgrades to the Transmission or Distribution System from time to time.
e. Cost Allocation
For cost allocation under the Fast Track Process or the Independent Study Process: Except
where exempt by law or Commission decision, costs triggered by an Interconnection Request
are the responsibility of the triggering Interconnection Request.
For cost allocation under the Distribution Group Study Process: The costs of Interconnection
Facilities will be assigned to the triggering Interconnection Request. The costs of Distribution
Upgrades or Network Upgrades identified through a Distribution Group Study shall be allocated
among the Interconnection Requests in a Distribution Study Group based on nameplate kilovolt
amperes (kVA) and, in some instances, as determined by Distribution Provider, also based on an
Applicant’s specific contributions to the upgrade costs. Costs for upgrades will be allocated
based upon an Applicant’s specific contributions to a particular upgrade only if the Distribution
Provider determines that; based on overall fairness to the Distribution Study Group, the individual
applicant, rather than the Distribution Study Group, should be responsible for the costs. Cost
allocation within the Distribution Study Group will not always align with cost contribution under a
per kVA plus specific contribution allocation method. The DGS Phase I and Phase II study
reports will indicate how cost allocation is determined. Examples of the possible types of shared
costs include but may not be limited to: upgraded transformers, reconductoring, circuit switchers,
and breakers.
Costs triggered by an Interconnection Request under this Rule that transitions to the
Transmission Cluster Study Process are allocated pursuant to the terms of Distribution Provider’s
WDAT or other applicable tariff.
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L
Revised Cal. P.U.C. Sheet No. 27734-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27246-E
RULE 21 Sheet 41
GENERATING FACILITY INTERCONNECTIONS
(Continued)
41C7 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
4. Interconnection Cost Responsibility (Continued)
f. Summary Tables
Table E.2 summarizes cost responsibility for costs and fees that may arise in the course of the
interconnection process for NEM and non-NEM Applicants. Table E.3 summarizes cost
responsibility for costs and fees that may arise in the course of the interconnection process for
NEM Applicants under various sequences of interconnecting NEM and non-NEM Generators on
the same PCC interconnecting to the Distribution or Transmission System.
Table E.2 Summary of Producer Cost Responsibility
Generating
Facility Type
Interconnection
Request Fee
Supplemental
Review Fee
Detailed Study
Cost (ISP,
DGSP, or
TCSP)
Interconnectio
n Facilities
Cost
Distribution
Upgrades
Cost
Transmission
Network
Upgrade Cost
(Ref.CAISO
Tariff Sec. --)
YES NO YES NO YES NO YES NO YES NO YES NO
NEM-2
>1MW and
Non-NEM
x x x x x x
NEM-2
<1MW* x x x** x x x**
NEM x x x x xa xa
Table E.3 Summary of Producer Cost Responsibility for Multiple Tariff Interconnections Existing
Generating
Facility
New
Generating
Facility
Interconnection
Request Fee
Supplemental
Review Fee
Detailed
Study Cost
Interconnection
Facilities Cost
Distribution
Upgrades
Cost
YES NO YES NO YES NO YES NO YES NO
NEM-1 NON-NEM x x x x xb
NEM-1 NEM x x x x xa
NEM-1 NEM-2
≤1MW x x x x x
Non-NEM NEM xc xc xc x xa,b,
c
Non-NEM NEM-2
>1MW x x x x x
Non-NEM NEM-2
≤1MW) x xc xc x x b,c
Simultaneous NEM and
Non-NEM x x x x xb
a Except as provided in Section D.13.e and f. b Proration will be based upon the annual expected energy output (kWh) derived from the nameplate of the
Generator(s) modified by technology-specific capacity/availability factors of all NEM, NEM-2 and non-NEM
Generators for the costs that cannot be clearly assigned to each type of tariff. c. Change of operation of a non-NEM eligible Generator at any time to export is treated as a simultaneous NEM and
non-NEM Interconnection Request, resulting in associated costs being allocated to Producer.
L
L
Revised Cal. P.U.C. Sheet No. 28014-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27735-E
RULE 21 Sheet 42
GENERATING FACILITY INTERCONNECTIONS
(Continued)
42C9 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued) 5. Interconnection Request Validation and Assignment of Queue Position Any Applicant for Interconnection to Distribution Provider’s Distribution or Transmission System must
submit a complete and valid Interconnection Request. An Interconnection Request will be
considered complete and valid when all items required for an Interconnection Request have been
received by Distribution Provider and deemed valid by Distribution Provider.
a. Acknowledgement of Interconnection Request
For Interconnection Requests that have not elected the Cost Envelope Option, Distribution
Provider shall provide a first written notification to the Interconnection Customer within ten (10)
Business Days of receipt of the Interconnection Request, which notice shall state whether the
Interconnection Request is deemed complete and valid.
For Interconnection Requests that have elected the Cost Envelope Option, Distribution Provider
shall provide a first written notification to the Interconnection Customer within fifteen (15)
Business Days of receipt of the Interconnection Request, which notice shall state whether the
Interconnection Request is deemed complete and valid.
b. Deficiencies in Interconnection Request
i) First Notification of Deficiency
If an Interconnection Request fails to meet the requirements, Distribution Provider shall state
in its first written notification the reasons for such failure and that the Interconnection
Request does not constitute a valid request. Applicant shall provide Distribution Provider the
additional requested information needed to constitute a complete and valid request within
ten (10) Business Days from the date of the first written notification that the Interconnection
Request is invalid.
ii) Second Notification of Deficiency
Distribution Provider shall provide a second written notification to Applicant within ten (10)
Business Days of receipt of the additional requested information, stating whether the
Interconnection Request is valid or the reasons for any failure. Applicant shall provide
Distribution Provider the additional requested information needed to constitute a complete
and valid request within five (5) Business Days from the date of the second written
notification that the Interconnection Request is invalid.
iii) Extension Request
Upon request, Applicant can receive one extension of up to twenty (20) Business Days to
resolve deficiencies in the Interconnection Request.
iv) Failure to Resolve Deficiencies
If Applicant does not resolve deficiencies in the Interconnection Request within the time
frames set out above, Distribution Provider will deem the Interconnection Request
withdrawn. Applicant may submit a new Interconnection Request. Applicants with invalid
Interconnection Requests under this Section may seek relief under the dispute resolution
provisions in Section K by so notifying Distribution Provider within two (2) Business Days of
receipt of the first or second written notification that the Interconnection Request is
incomplete and/or invalid.
N
N
N
N
N
Revised Cal. P.U.C. Sheet No. 27736-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27248-E
RULE 21 Sheet 43
GENERATING FACILITY INTERCONNECTIONS
(Continued)
43C7 Issued by Date Filed Jul 8, 2016
Advice Ltr. No. 2916-E Dan Skopec Effective Jul 8, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
5. Interconnection Request Validation and Assignment of Queue Position (Continued)
c. Assignment of Queue Position
Distribution Provider shall assign a queue position to all non-Net Energy Metering Applicants. If
there were no deficiencies in the Interconnection Request, the queue position will be based on
the date Distribution Provider received the Interconnection Request. If there were deficiencies in
the Interconnection Request, the queue position will be based on the date Distribution Provider
determines an Interconnection Request to be complete and valid. Should Distribution Provider
not meet any deadline for providing the first (Section E.5.b.i) or second written notification
(Section E.5.b.ii) to Applicant regarding the Interconnection Request, Applicant’s queue position
shall be set on the final day of the period in which Distribution Provider was obligated to provide
such written notification, provided, however, that Applicant meets deadlines as set out above to
submit any additional information required for a valid Interconnection Request following such
written notification under Section E.5.b.i or E.5.b.ii, and that Distribution Provider determines
that the Interconnection Request is valid.
Distribution Provider shall maintain a single queue for all non-Net Energy Metering
Interconnection Requests governed by this Rule with a Point of Interconnection on Distribution
Provider’s Distribution System. For Interconnection Requests that are studied under the
Distribution Group Study Process, the effective queue position for all Interconnection Requests
in a Distribution Study Group will be derived on the last day of the Distribution Group Study
window for that Distribution Study Group. For Interconnection Requests that are studied under
the Transmission Cluster Study Process, the queue position will be the applicable cluster’s
queue position.
d. Publication of the Interconnection Queue
Distribution Provider shall publish and update monthly on its website the interconnection queue
for all Interconnection Requests governed by this Rule with a Point of Interconnection on
Distribution Provider’s Distribution System that have been assigned a queue position. Nothing
here prohibits Distribution Provider from publishing this queue combined with other
interconnection requests to Distribution Provider’s Distribution System. The published
interconnection queue may include the following information for each Interconnection Request
governed by this Rule, subject to Energy Division approval:
i) Interconnection Request and Queue Position Data
(1) The assigned number, if any;
(2) the queue position;
(3) the date the Interconnection Request was received by Distribution Provider;
(4) the date the Interconnection Request was determined to be complete and valid;
(5) the review process to which Applicant originally applied, and is currently assigned;
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Revised Cal. P.U.C. Sheet No. 28148-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27737-E
RULE 21 Sheet 44
GENERATING FACILITY INTERCONNECTIONS
(Continued)
44C9 Issued by Date Filed Oct 21, 2016
Advice Ltr. No. 2987-E Dan Skopec Effective Mar 30, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
E. Interconnection Request Submission Process (Continued)
5. Interconnection Request Validation and Assignment of Queue Position (Continued)
d. Publication of the Interconnection Queue
i) Interconnection Request and Queue Position Data
(6) the original requested In-Service Date;
(7) the currently requested In-Service Date;
(8) the agreed-upon Commercial Operation Date or actual Commercial Operation Date.
ii) Applicant Generating Facility/Storage System and Point of Interconnection Data
(1) the maximum summer and winter MW electrical output;
(2) the type of generating or storage facility to be constructed; (3) the fuel source;
(4) the proposed Point of Interconnection location by county;
(5) the proposed Point of Interconnection location by substation/area and, if applicable, circuit;
F. Review Process For Interconnection Requests
1. Overview of the Interconnection Review Process
a. Valid Interconnection Request
After an Interconnection Request is deemed complete and valid, Distribution Provider will
perform Fast Track evaluation unless an Applicant applies for Detailed Study or is not eligible
for Fast Track evaluation. The eligibility requirements for Fast Track evaluation are set forth in
Section E.2.b. See Section D.13 for special provisions related to the timeframe and costs
applicable to NEM Applicants. See Section D.14 and Section N for special provisions
applicable to Non-Export Energy Storage Generating Facilities, as provided therein.
b. Fast Track Review
Fast Track evaluation allows for rapid review of the Interconnection of those Generating
Facilities that do not require Detailed Study. Regardless of study process, all Generating
Facilities shall be designed to meet the applicable requirements of Section H which identifies
Generating Facility Design and Operation Requirements.
Fast Track review consists of an Initial Review and, if required, a Supplemental Review. The
need for Supplemental Review will be determined based on the results of Initial Review
Screens A through M in Section G. Applicants that successfully pass Initial Review Screens A
through M will be allowed to interconnect without Supplemental Review.
N
N
Revised Cal. P.U.C. Sheet No. 28149-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27738-E
RULE 21 Sheet 45
GENERATING FACILITY INTERCONNECTIONS
(Continued)
45C8 Issued by Date Filed Oct 21, 2016
Advice Ltr. No. 2987-E Dan Skopec Effective Mar 30, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
1. Overview of the Interconnection Review Process (Continued)
b. Fast Track Review (Continued)
If Supplemental Review is required, Distribution Provider will notify Applicant and Applicant
must pay a nonrefundable Supplemental Review fee or withdraw its Interconnection Request.
Supplemental Review shall consist of the application of Screens N through P in Section G.2.
Applicants that pass Screens N through P will be allowed to interconnect without additional
review.
If Supplemental Review reveals that a proposed Generating Facility cannot be interconnected
to Distribution Provider’s Distribution System by means of Fast Track evaluation, Distribution
Provider will notify Applicant that Detailed Study will be required.
Failure to pass Fast Track evaluation means only that further review and/or study are required
before the Generating Facility can be interconnected with Distribution Provider’s Distribution
System. It does not mean that the Generating Facility cannot be interconnected.
c. Detailed Studies
Detailed Study will be required for Interconnection Requests that either apply directly for
Detailed Study, are not eligible for Fast Track evaluation, or do not pass Fast Track evaluation.
Detailed Study shall consist of one of three study processes: (i) Independent Study Process; (ii)
Distribution Group Study Process; or (iii) Transmission Cluster Study Process. The specific
study process that is applied will depend on the results of Screens Q and R in Section G.3.
Interconnection Requests that are found to be electrically interdependent with earlier-queued
interconnection requests with impacts on the Transmission System, and thereby fail screen Q,
will proceed to the Transmission Cluster Study Process. Interconnection Requests that are not
electrically interdependent with earlier-queued interconnection requests with impacts on the
Transmission System, and thereby pass screen Q, will be studied under either the Independent
Study Process or the Distribution Group Study Process, depending on the results of Screen R.
d. Compliance with Timelines
Distribution Provider shall use Reasonable Efforts in meeting all the timelines set out in this
Rule, or mutually modified by Distribution Provider and Applicant pursuant to Section D.16.
Each Distribution Provider shall designate an ombudsman with authority to resolve disputes
over missed timelines. The identity, role, and contact information of the ombudsman shall be
available on Distribution Provider’s website. If at any time an Applicant is dissatisfied with the
Reasonable Efforts of Distribution Provider to meet the timelines in this Section, Applicant may
use the following procedures:
(i) Contact the ombudsman designated by Distribution Provider;
T
Revised Cal. P.U.C. Sheet No. 28015-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27739-E
RULE 21 Sheet 46
GENERATING FACILITY INTERCONNECTIONS
(Continued)
46C11 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
1. Overview of the Interconnection Review Process (Continued)
d. Compliance with Timelines (Compliance)
(ii) If the Distribution Provider ombudsman is unable to resolve the dispute within ten (10)
Business Days, Applicant may either:
a) Contact the Consumer Affairs Branch (CAB) at the Commission.
b) Upon mutual agreement with Distribution Provider, make a written request for mediation
to the Alternative Dispute Resolution (ADR) Coordinator in the Commission’s
Administrative Law Judge (ALJ) Division. The request may be made by electronic mail to
adr_program@cpuc.ca.gov, and shall state “Rule 21” in the subject line. The request
shall contain the relevant facts of the timeline dispute. A copy of the request shall be
sent to the Distribution Provider ombudsman. Provided that resources are available, the
mediator assigned shall schedule mediation with Applicant and Distribution Provider
within ten (10) Business Days of receiving the request.
At any time, Applicant may file a formal complaint before the Commission pursuant to
California PUC Section 1702 and Article 4 of the Commission’s Rules of Practice and
Procedure.
2. Fast Track Interconnection Review Process
a. Initial Review
Upon receipt of a complete and valid Interconnection Request, Distribution Provider shall
perform Initial Review using the process in Section G.1. The Initial Review determines if (i) the
Generating Facility qualifies for Fast Track Interconnection through Initial Review, or (ii) the
Generating Facility requires a Supplemental Review. Absent extraordinary circumstances,
Distribution Provider shall notify Applicant in writing of the results of Initial Review within fifteen
(15) Business Days following validation of an Interconnection Request.
For all Interconnection Requests that pass Initial Review and do not require Interconnection
Facilities or Distribution Upgrades, Distribution Provider shall provide Applicant with a Generator
Interconnection Agreement within fifteen (15) Business Days of providing notice of Initial Review
results. For Interconnection Requests that pass Initial Review but do require Interconnection
Facilities or Distribution Upgrades, within fifteen (15) Business Days of providing notice of Initial
Review results, Distribution Provider shall provide Applicant with a non-binding cost estimate of
the Interconnection Facilities or Distribution Upgrades. For those Interconnection Requests
where Applicant has selected the Cost Envelope Option, within ten (10) Business Days of
providing Applicant the non-binding cost estimate for the required Interconnection Facilities
and/or Distribution Upgrades, Applicant shall provide the Distribution Provider the Cost Envelope
Option deposit, in accordance with Section F.7.a.i.3. If Applicant fails to provide the Cost
Envelope Option deposit in accordance with Section F.7.a.i.3, Applicant’s request for the Cost
Envelope Option shall be deemed withdrawn and the Interconnection Request shall not be
eligible for the Cost Envelope Option.
For all Interconnection Requests that pass Initial Review, refer to Section F.2.e for cost
responsibility and time frames for completing the Generator Interconnection Agreement.
T
T
N
N
N
N
N
N
N
Revised Cal. P.U.C. Sheet No. 28016-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27740-E
RULE 21 Sheet 47
GENERATING FACILITY INTERCONNECTIONS
(Continued)
47C11 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
2. Fast Track Interconnection Review Process (Continued)
a. Initial Review (Continued)
For Interconnection Requests that fail Initial Review, Distribution Provider shall provide the
technical reason, data and analysis supporting the Initial Review results in writing and provide
Applicant the option to either attend an Initial Review results meeting or proceed directly t
Supplemental Review. Net Energy Metering Applicants covered under Section D.13.1 shall
proceed directly to Supplemental Review without an Initial Review results meeting. Applicant
shall notify Distribution Provider within ten (10) Business Days following such notification
whether to (i) proceed to an Initial Review results meeting, (ii) proceed to Supplemental Review,
or (iii) withdraw the Interconnection Request. Applicant may request one extension of no more
than ten (10) Business Days to respond. If Applicant fails to notify Distribution Provider within ten
(10) Business Days of such notification, or at the end of the extension, if one was requested, the
Interconnection Request shall be deemed withdrawn. No changes may be made to the planned
Point of Interconnection or Generating Facility size included in the Interconnection Request
during the Fast Track Process, unless such change are agreed to by Distribution Provider.
Where agreement has not been reached, Applicants choosing to change the Point of
Interconnection or Generating Facility size must reapply and submit a new Interconnection
Request.
Applicants that elect to proceed to Supplemental Review shall provide a nonrefundable
Supplemental Review fee set forth in Section E.2.c with their response. The Supplemental
Review fee shall be waived for Interconnection Requests requesting Interconnection pursuant to
PUC Sections 2827, 2827.8, or 2827.10, per Commission Decision 02-03-057 and for solar-
powered Generating Facilities that do not sell power to Distribution Provider, per Commission
Decision 01-07-027.
b. Optional Initial Review Results Meeting
Within five (5) Business Days of Applicant’s request for an Initial Review results meeting,
Distribution Provider shall contact Applicant and offer to convene a meeting at a mutually
acceptable time to review the Initial Review screen analysis and related results to determine
what modifications, if any, may permit the Generating Facility to be connected safely and reliably
without Supplemental Review.
If modifications that obviate the need for Supplemental Review are identified, and Applicant and
Distribution Provider agree to such modifications, Distribution Provider shall provide Applicant
with a Generator Interconnection Agreement within fifteen (15) Business Days of the Initial
Review results meeting if no Interconnection Facilities or Distribution Upgrades are required. If
Interconnection Facilities or Distribution Upgrades are required, Distribution Provider shall
provide Applicant with a non-binding cost estimate of any Interconnection Facilities or
Distribution Upgrades within fifteen (15) Business Days of the Initial Review results meeting. For
those Interconnection Requests where Applicant has selected the Cost Envelope Option, within
ten (10) Business Days of providing Applicant the non-binding cost estimate for the required
Interconnection Facilities and/or Distribution Upgrades, Applicant shall provide the Distribution
Provider the Cost Envelope Option deposit, in accordance with Section F.7.a.i.3. If Applicant
fails to provide the Cost Envelope Option deposit in accordance with Section F.7.a.i.3,
Applicant’s request for the Cost Envelope Option shall be deemed withdrawn and the
Interconnection Request shall not be eligible for the Cost Envelope Option.
T
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N
N
N
N
N
N L
Revised Cal. P.U.C. Sheet No. 28017-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27741-E
RULE 21 Sheet 48
GENERATING FACILITY INTERCONNECTIONS
(Continued)
48C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
2. Fast Track Interconnection Review Process (Continued)
b. Optional Initial Review Results Meeting (Continued)
For all Interconnection Requests that pass Initial Review, refer to Section F.2.e for cost
responsibility and time frames for completing the Generator Interconnection Agreement.
If Applicant and Distribution Provider are unable to identify or agree to modifications that enable
Applicant to pass Initial Review, Applicant shall notify Distribution Provider within ten (10)
Business Days of the Initial Review results meeting whether it would like to proceed with
Supplemental Review or withdraw its Interconnection Request. Applicant may request one
extension of no more than ten (10) Business Days to respond. If Applicant fails to notify
Distribution Provider within ten (10) Business Days of the Initial Review results meeting, or at the
end of the extension, if one was requested, the Interconnection Request shall be deemed
withdrawn.
c. Supplemental Review
i) If Applicant requests Supplemental Review and submits a nonrefundable Supplemental
Review fee, if required, Distribution Provider shall complete Supplemental Review within
twenty (20) Business Days, absent extraordinary circumstances, following authorization and
receipt of the fee. Supplemental Review determines if (i) the Generating Facility qualifies for
Fast Track Interconnection, or (ii) the Generating Facility requires Detailed Study.
ii) If the Applicant chooses to move to Supplemental Review, they have the option to elect that
the Distribution Provider provide a fault current study as part of the Supplemental Review.
This fault current study would extend the Supplemental Review time by up to ten (10)
Business Days, and would require an additional nonrefundable fee of $1,000.
iii) This fault current study will determine if the Generating Facility can detect phase and ground
faults on the Distribution Provider’s Distribution System or the distribution feeder breaker
where the Applicant proposes to connect the Generating Facility. The result of the fault
current study will determine if direct transfer trip (DTT) will be required from the Distribution
System to the Generating Facility site. Note that for Applicants proposing to interconnect to
the Distribution System where there is expected to be power backfeed to the Transmission
System, DTT from the transmission may still be required and a Detailed Interconnection
Study will be required to make this determination. Should the Applicant request a
Supplemental Review results meeting, as described in Section F.2d, the optional fault
current study analysis and related results shall, at the Applicant’s request, be reviewed to
determine what modifications, if any, may permit the Generating Facility to be connected
safely and reliably.
The Applicant must provide the following data to Distribution Provider when requesting
Supplemental Review in order to select this option:
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L
Revised Cal. P.U.C. Sheet No. 28018-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27742-E
RULE 21 Sheet 49
GENERATING FACILITY INTERCONNECTIONS
(Continued)
49C10 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
2. Fast Track Interconnection Review Process (Continued)
c. Supplemental Review (Continued)
iii. (Continued)
Generator:
MVA Rating
kV Rating
Base MVA
Base kV
Xd” (direct axis subtransient reactance)
Xd’ (direct axis transient reactance
Xd (Synchronous reactance)
X2 (Negative Sequence reactance)
X0 (Zero Sequence reactance)
XFMR Data:
Winding configuration (delta-Wye grd or Wye grd-Delta)
MVA Rating
KV Rating
Base MVA
Base KV
Z1 HV -LV
Z0 HV-LV
Line Data:
Impedance data for line from XFMR to POI (if applicable).
Z1
Z0
POI Location:
iv) For Interconnection Requests that pass Supplemental Review and do not require
Interconnection Facilities or Distribution Upgrades, Distribution Provider shall provide
Applicant with a Generator Interconnection Agreement within fifteen (15) Business
Days of providing notice of Supplemental Review results. For Interconnection
Requests that pass Supplemental Review and do require Interconnection Facilities or
Distribution Upgrades, within fifteen (15) Business Days of providing notice of
Supplemental Review results, Distribution Provider shall provide Applicant with a non-
binding cost estimate of any Interconnection Facilities or Distribution Upgrades. For
those Interconnection Requests where Applicant has selected the Cost Envelope
Option, within ten (10) Business Days of providing Applicant the non-binding cost
estimate for the required Interconnection Facilities and/or Distribution Upgrades,
Applicant shall provide the Distribution Provider the Cost Envelope Option deposit, in
accordance with Section F.7.a.i.3. If Applicant fails to provide the Cost Envelope
Option deposit in accordance with Section F.7.a.i.3, Applicant’s request for the Cost
Envelope Option shall be deemed withdrawn and the Interconnection Request shall
not be eligible for the Cost Envelope Option.
T
N
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Revised Cal. P.U.C. Sheet No. 28019-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27255-E
RULE 21 Sheet 50
GENERATING FACILITY INTERCONNECTIONS
(Continued)
50C11 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued) 2. Fast Track Interconnection Review Process (Continued) c. Supplemental Review (Continued) iv) (Continued)
For all Interconnection Requests that pass Supplemental Review, refer to Section F.2.d for
cost responsibility and time frames for completing the Generator Interconnection
Agreement.
v) For Interconnection Requests that fail Supplemental Review, Distribution Provider shall
provide the technical reason, data and analysis supporting the Supplemental Review results
in writing, including, if Distribution Provider can make the determination, which Detailed
Study track Applicant qualifies for, and provide Applicant the option to attend a
Supplemental Review results meeting or proceed directly to Detailed Study. Applicant shall
notify Distribution Provider within fifteen (15) Business Days following such notification
whether to (i) proceed to a Supplemental Review results meeting, (ii) proceed to Detailed
Study, or (iii) withdraw the Interconnection Request. Applicant may request one extension of
no more than fifteen (15) Business Days to respond. If Applicant fails to notify Distribution
Provider within fifteen (15) Business Days of such notification, or at the end of the
extension, if one was requested, the Interconnection Request shall be deemed withdrawn. Applicants that elect to proceed to Detailed Study shall provide the applicable study deposit
set forth in Section E.3.a. Detailed Study fees for solar Generating Facilities up to 1 MW
interconnecting to the Distribution System that do not sell power to Distribution Provider will
be waived up to the amount of $5,000. Generating Facilities eligible for Net Energy Metering
under PUC Sections 2827, 2827.8, or 2827.10 are exempt from any costs associated with
Detailed Studies.
d. Optional Supplemental Review Results Meeting
Within five (5) Business Days of Applicant’s request for a Supplemental Review results meeting,
Distribution Provider shall contact Applicant and offer to convene a meeting at a mutually
acceptable time to review the Supplemental Review screen analysis and related results to
determine what modifications, if any, may permit the Generating Facility to be connected safely
and reliably without Detailed Study. If modifications that obviate the need for Detailed Study are identified and Applicant and
Distribution Provider agree to such modifications, Distribution Provider shall provide Applicant
with a Generator Interconnection Agreement within fifteen (15) Business Days of the
Supplemental Review results meeting if no Interconnection Facilities or Distribution Upgrades
are required. If Interconnection Facilities or Distribution Upgrades are required, Distribution
Provider shall provide Applicant with a non-binding cost estimate of any Interconnection
Facilities or Distribution Upgrades within fifteen (15) Business Days of the Supplemental Review
results meeting. For those Interconnection Requests where Applicant has selected the Cost
Envelope Option, within ten (10) Business Days of providing Applicant the non-binding cost
estimate for the required Interconnection Facilities and/or Distribution Upgrades, Applicant shall
provide the Distribution Provider the Cost Envelope Option deposit, in accordance with Section
F.7.a.i.3. If Applicant fails to provide the Cost Envelope Option deposit in accordance with
Section F.7.a.i.3, Applicant’s request for the Cost Envelope Option shall be deemed withdrawn
and the Interconnection Request shall not be eligible for the Cost Envelope Option.
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Revised Cal. P.U.C. Sheet No. 28388-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27256-E
RULE 21 Sheet 51
GENERATING FACILITY INTERCONNECTIONS
(Continued)
51C5 Issued by Date Filed Dec 16, 2016
Advice Ltr. No. 2945-E-A Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
2. Fast Track Interconnection Review Process (Continued)
d. Optional Supplemental Review Results Meeting (Continued)
For all Interconnection Requests that pass Supplemental Review, refer to Section F.2.e for cost
responsibility and time frames for completing the Generator Interconnection Agreement.
If Applicant and Distribution Provider are unable to identify or agree to modifications, Applicant
shall notify Distribution Provider within twenty (20) Business Days of the Supplemental Review
Results Meeting whether it would like to proceed with Detailed Study or withdraw its
Interconnection Request. Applicant may request one extension of no more than twenty (20)
Business Days to respond. If Applicant fails to notify Distribution Provider within twenty (20)
Business Days of the Supplemental Review results meeting, or at the end of the extension, if
one was requested, the Interconnection Request shall be deemed withdrawn. Applicants that
elect to proceed to Detailed Study shall provide the applicable study deposit set forth in Section
E.3.a.
e. Execution of the Generator Interconnection Agreement
For Interconnection Requests where Applicant has not selected the Cost Envelope Option,
following the receipt of a cost estimate for any Distribution Upgrades and/or Interconnection
Facilities that have been identified (Applicants that did not require a cost estimate may proceed
directly to the 3rd paragraph below), Applicant shall notify Distribution Provider within fifteen (15)
Business Days whether Applicant: (i) requests a Generator Interconnection Agreement, or (ii)
withdraws its Interconnection Request. Applicant may request one extension of no more than
fifteen (15) Business Days to respond. If Applicant fails to notify Distribution Provider within
fifteen (15) Business Days, or at the end of the extension, if one was requested, the
Interconnection Request shall be deemed withdrawn. If Applicant elects to proceed to a
Generator Interconnection Agreement, Distribution Provider shall provide Applicant with a
Generator Interconnection Agreement for Applicant’s signature within fifteen (15) Business Days
of Applicant’s request.
For those Interconnection Requests where Applicant has selected the Cost Envelope Option and
has provided the Cost Envelope Option deposit in accordance with Section F.7.a.i.3, Distribution
Provider shall complete and issue to Applicant the Cost Envelope Estimate within twenty (20)
Business Days following Distribution Provider’s receipt of the Cost Envelope Option deposit in
accordance with F.7.d. Once the Cost Envelope Estimate is issued, Applicant shall notify
Distribution Provider within fifteen (15) Business Days of notification whether Applicant: (i)
requests a Generator Interconnection Agreement, or (ii) withdraws its Interconnection Request.
Applicant may request one extension of no more than fifteen (15) Business Days to respond. If
Applicant fails to notify Distribution Provider within fifteen (15) Business Days, or at the end of
the extension if one was requested, the Interconnection Request shall be deemed withdrawn. If
Applicant elects to proceed to a Generator Interconnection Agreement, Distribution Provider
shall provide Applicant with a Generator Interconnection Agreement for Applicant’s signature
within fifteen (15) Business Days of Applicant’s request.
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Revised Cal. P.U.C. Sheet No. 28021-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27257-E
RULE 21 Sheet 52
GENERATING FACILITY INTERCONNECTIONS
(Continued)
52C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
2. Fast Track Interconnection Review Process (Continued)
e. Execution of the Generator Interconnection Agreement (Continued)
Upon receipt of a draft Generator Interconnection Agreement, Applicant has ninety (90)
Calendar Days to sign and return the Generator Interconnection Agreement. Applicant shall
provide written comments, or notification of no comments, to the draft Generator Interconnection
Agreement and appendices within thirty (30) Calendar Days. At the request of Applicant,
Distribution Provider shall begin negotiations with Applicant at any time after Distribution
Provider provides Applicant with the draft Generator Interconnection Agreement, which contains
in its appendices the cost estimate for any Distribution Upgrades and/or Interconnection
Facilities that have been identified by Distribution Provider. Distribution Provider and Applicant
shall negotiate concerning the cost estimate, or any disputed provisions of the appendices to a
draft Generator Interconnection Agreement, for not more than ninety (90) Calendar Days after
Distribution Provider provides Applicant with the Generator Interconnection Agreement. If
Applicant determines that negotiations are at an impasse, it may request termination of the
negotiations and initiate Dispute Resolution procedures pursuant to Section K. If Applicant fails
to sign the Generator Interconnection Agreement or initiate Dispute Resolution within ninety (90)
Calendar Days, the Interconnection Request shall be deemed withdrawn.
After Applicant, or a Producer where those are different entities, has executed the Generator
Interconnection Agreement, Distribution Provider will commence design, procurement,
construction and installation of Distribution Provider’s Distribution Upgrades and/or
Interconnection Facilities that have been identified in the Generator Interconnection Agreement.
Distribution Provider and Producer will use good faith efforts to meet schedules in accordance
with the requirements of the Generator Interconnection Agreement and estimated costs as
appropriate. Producer is responsible for all costs associated with Parallel Operation to support
the safe and reliable operation of the Distribution System and Transmission System as set forth
in Section E.4.
Distribution Provider and Producer shall negotiate in good faith concerning a schedule for the
construction of Distribution Provider’s Interconnection Facilities and Distribution Upgrades.
3. Detailed Study Interconnection Review Process
a. Detailed Study Track Selection Process
For all Detailed Study Applicants, as well as Applicants that have failed Fast Track initial review
and/or supplemental, the specific Detailed Study track for which Applicant is eligible will be
determined by the application of Screens Q and R. For Applicants that require application of
Screens Q and R, absent extraordinary circumstances, within twenty (20) Business Days
following validation of an Interconnection Request and receipt of the appropriate study deposit
set forth in Section E.3.a, Distribution Provider will apply Screen Q, and if applicable, Screen R
and provide Applicant with the screen results as set forth below.
If Applicant fails Screen Q, Distribution Provider shall provide the data and analysis supporting
Screen Q results in writing. The Interconnection Request will be processed in accordance with
Section F.3.d below.
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Revised Cal. P.U.C. Sheet No. 28022-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27258-E
RULE 21 Sheet 53
GENERATING FACILITY INTERCONNECTIONS
(Continued)
53C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
a. Detailed Study Track Selection Process (Continued)
If Applicant passes Screen Q, but fails Screen R, Distribution Provider shall provide data and
analysis supporting the Screen R results in writing.
Applicant shall notify Distribution Provider within twenty (20) Business days following such
notification whether it would like to (i) proceed to the Distribution Group Study Process or (ii)
withdraw the Interconnection Request. Applicant may request one extension of no more than
twenty (20) Business Days to respond. However, Applicant’s decision must be received prior to
the close of a given Distribution Group Study window, to participate in that Distribution Study
Group. If the decision is received after the close of a particular Distribution Group Study window,
then Applicant’s Interconnection Request will be included in the next available Distribution Group
Study window. If Applicant fails to notify Distribution Provider within twenty (20) Business Days
of receiving Screen R results, or at the end of the extension, if one was requested, the
Interconnection Request shall be deemed withdrawn
If Applicant elects to proceed to the Distribution Group Study Process, the Interconnection
Request will be processed in accordance with Section F.3.c below.
A Distribution Study Group will be comprised of all Interconnection Requests that are determined
to be electrically interdependent based on results of Screen R. A Distribution Study Group may
contain only one Interconnection Request.
Applicant(s) that opt to proceed to the Distribution Group Study Process will be re-evaluated
under Screen Q. If the Distribution Study Group fails Screen Q, the Applicants will be required to
withdraw and move to the Transmission Cluster Process.
If Applicant passes Screens Q and R, the Interconnection Request will be processed in
accordance with Section F.3.b below.
If Applicant elects to proceed to the Transmission Cluster Study Process, Interconnection
Request will be processed in accordance with Section F.3.d.
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Revised Cal. P.U.C. Sheet No. 27259-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 24995-E
RULE 21 Sheet 54
GENERATING FACILITY INTERCONNECTIONS
(Continued)
54C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
b. Independent Study Process
i) Scoping Meeting
Within five (5) Business Days after Distribution Provider notifies Applicant that the
Interconnection Request has passed Screens Q and R and is thus eligible for the
Independent Study Process, Distribution Provider shall contact Applicant to establish a date
agreeable to Applicant and Distribution Provider for a scoping meeting.
The purpose of the scoping meeting shall be: (i) to discuss reasonable Commercial
Operation Dates and alternative interconnection options; (ii) to exchange information,
including any transmission data that would reasonably be expected to impact Applicant’s
interconnection options; (iii) to analyze such information; and (iv) to determine feasible
Points of Interconnection and eliminate alternatives given resources and available
information.
Distribution Provider will bring to the scoping meeting, as reasonably necessary to
accomplish its purpose, such already available technical data, including, but not limited to; (i)
general facility loadings, (ii) general instability issues, (iii) general short circuit issues, (iv)
general voltage issues, and (v) general reliability issues.
Applicant will bring to the scoping meeting, in addition to the technical data in Attachment A
of the Rule 21 Exporting Generating Facility Interconnection Request form, any system
studies previously performed. Distribution Provider, the CAISO, if applicable, and Applicant
will also bring to the meeting personnel and other resources as may be reasonably required
to accomplish the purpose of the meeting in the time allocated for the meeting. On the basis
of the meeting, Applicant shall designate its Point of Interconnection. The duration of the
meeting shall be only what is sufficient to accomplish its purpose.
Within fifteen (15) Business Days after the scoping meeting, Distribution Provider shall
provide Applicant with a Detailed Study Agreement, which shall contain an outline of the
scope of the Interconnection System Impact Study and Interconnection Facilities Study,
contain a non-binding good faith estimate of the cost to perform such studies, and shall
specify that Applicant is responsible for the actual cost of the Interconnection Studies,
including reasonable administrative costs.
Applicant shall execute and deliver to Distribution Provider the Detailed Study Agreement no
later than thirty (30) Business Days after the scoping meeting, or the Interconnection
Request shall be deemed withdrawn.
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Revised Cal. P.U.C. Sheet No. 27260-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 24996-E
RULE 21 Sheet 55
GENERATING FACILITY INTERCONNECTIONS
(Continued)
55C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
b. Independent Study Process (Continued)
ii) Timing of the Interconnection System Impact Study Results.
Absent extraordinary circumstances, Distribution Provider shall complete and issue a final
Interconnection System Impact Study report within sixty (60) Business Days after the
execution of a Detailed Study Agreement. If the System Impact Study indicates a need for
Network Upgrades, Distribution Provider will share applicable study results with the CAISO
for review and comment and will incorporate comments into the final Interconnection System
Impact Study report.
At any time Distribution Provider determines that it will not meet the required time frame for
completing the Interconnection System Impact Study, Distribution Provider shall notify
Applicant in writing as to the status of the Interconnection System Impact Study and provide
an estimated completion date with an explanation of the reasons why additional time is
required.
Upon request, Distribution Provider shall provide Applicant all relevant supporting
documentation, workpapers and pre-Interconnection Request and post-Interconnection
Request power flow, short circuit and stability databases, and currently planned Distribution
Upgrades relevant to the Interconnection Request for the Interconnection System Impact
Study. Applicant may be required to sign a non-disclosure agreement with terms consistent
with Section D.7 regarding Confidentiality.
iii) Interconnection System Impact Study Results Meeting.
Applicant shall request a results meeting within ten (10) Business Days of the issuance of
the final Interconnection System Impact Study report. This results meeting, if requested,
shall be held among Distribution Provider, the CAISO, if applicable, and Applicant to discuss
the results of the Interconnection System Impact Study, including assigned cost
responsibility. Within five (5) Business Days of the request, Distribution Provider shall
contact Applicant to establish a date agreeable to Applicant, Distribution Provider and the
CAISO, if applicable, for the results meeting.
If Applicant does not request a results meeting within the specified time above, the results
meeting will be deemed waived.
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Revised Cal. P.U.C. Sheet No. 28023-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27261-E
RULE 21 Sheet 56
GENERATING FACILITY INTERCONNECTIONS
(Continued)
56C6 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
b. Independent Study Process (Continued)
iv) Initial Posting of Interconnection Financial Security.
Applicant shall make its initial posting of Interconnection Financial Security in accordance
with the requirements of Section F.4.b, within sixty (60) Calendar Days after issuance of the
final Interconnection System Impact Study report, or its Interconnection Request shall be
deemed withdrawn. The initial posting of Interconnection Financial Security will be based on
the cost responsibility for Network Upgrades, Distribution Upgrades, and Distribution
Provider’s Interconnection Facilities set forth in the final Interconnection System Impact
Study report.
v) Modifications
At any time during the course of the Interconnection Studies, Applicant, Distribution Provider,
or the CAISO, as applicable, may identify changes to the planned Interconnection that may
improve the costs and benefits (including reliability) of the Interconnection, and the ability of
the proposed change to accommodate the Interconnection Request. To the extent the
identified changes are acceptable to Distribution Provider, the CAISO, as applicable, and
Applicant, such acceptance not to be unreasonably withheld, Distribution Provider shall
modify the Point of Interconnection and/or configuration in accordance with such changes
without altering the Interconnection Request’s eligibility for participating in Interconnection
Studies.
At the Interconnection System Impact Study results meeting, Applicant should be prepared
to discuss any desired modifications to the Interconnection Request. After the issuance of
the final Interconnection System Impact Study report, but no later than five (5) Business
Days following the Interconnection System Impact Study results meeting, Applicant shall
submit to Distribution Provider, in writing, (i) modifications to any information provided in the
Interconnection Request, including that information required for the Cost Envelope Option, if
applicable, or (ii) confirmation of no modifications. Distribution Provider will forward
Applicant’s request for modification to the CAISO, if applicable, within two (2) Business Days
of receipt. If no Interconnection System Impact Study results meeting is held, Applicant shall
submit to Distribution Provider any requested modifications within twenty-five (25) Business
Days of the receipt of the final Interconnection System Impact Study report.
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Revised Cal. P.U.C. Sheet No. 28024-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27262-E
RULE 21 Sheet 57
GENERATING FACILITY INTERCONNECTIONS
(Continued)
57C10 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
b. Independent Study Process (Continued)
v) Modifications (Continued)
Modifications permitted under this Section F.3.b.v shall include specifically: (a) a decrease in
the electrical output (MW) of the proposed Generating Facility; (b) modifying the technical
parameters associated with the Generating Facility technology or the Generating Facility
step-up transformer impedance characteristics; and (c) modifying the interconnection
configuration. For any modifications other than those permitted above, Distribution Provider,
in coordination with CAISO, if applicable, will evaluate whether the proposed modification to
the interconnection request constitutes a Material Modification. Distribution Provider will
inform Applicant in writing whether the modifications would constitute a Material Modification
within (i) for Interconnection Requests that have not elected the Cost Envelope Option, ten
(10) Business Days of receipt of the proposed request for modification, and (ii) for
Interconnection Requests that have elected the Cost Envelope Option, twenty (20) Business
Days of receipt of the proposed request for modification. Any change to the Point of
Interconnection, except for that specified by Distribution Provider in an Interconnection Study
or otherwise allowed under this Section F.3.b.v, shall constitute a Material Modification.
If the proposed modification is determined to be a Material Modification, Applicant may either
withdraw the proposed modification or proceed with a new Interconnection Request for such
modification. Applicant shall make such determination within ten (10) Business Days after
being provided the Material Modification determination results.
Proposed modifications determined not to be Material Modifications may still necessitate the
need to re-evaluate the System Impact Study to determine modifications to the
Interconnection Facilities and Distribution Upgrades, or to update the Cost Envelope
Estimate, if applicable, in accordance with Section F.7. Distribution Provider will provide
Applicant an estimate of time to complete the re-evaluation and the associated incremental
cost required to complete the re-evaluation. Applicant may either accept the additional time
and cost to complete the re-evaluation, withdraw the proposed modification request, or
proceed with a new Interconnection Request for such modification. Applicant shall make
such determination within ten (10) Business Days after being provided the Material
Modification results.
vi) Scope and Purpose of the Interconnection Facilities Study and Study Deposit.
Within ten (10) Business Days of Applicant’s confirmation of no modifications or Distribution
Provider’s determination that the Interconnection System Impact Study does not require re-
evaluation, Applicant shall submit to Distribution Provider the data required by Distribution
Provider, including the completed form of Attachment B to the Detailed Study Agreement, if
applicable. For Generating Facilities 5 MW or less, Applicant shall also submit the
Interconnection Facilities Study deposit, as set out in Section E.3.a, unless the
Interconnection Facilities Study will be waived in accordance with Section F.3.b.vii.
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Revised Cal. P.U.C. Sheet No. 28025-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27263-E
RULE 21 Sheet 58
GENERATING FACILITY INTERCONNECTIONS
(Continued)
58C12 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
b. Independent Study Process (Continued)
vi) Scope and Purpose of the Interconnection Facilities Study and Study Deposit. (Continued)
For NEM Generating Facilities and Solar ≤1 MW Generating Facilities that have elected the
Cost Envelope Option, Applicant must (i) submit to Distribution Provider the Cost Envelope
Option deposit within ten (10) Business Days of Applicant’s confirmation of no modifications
or Distribution Provider’s determination that the Interconnection System Impact Study does
not require re-evaluation, or (ii) provide Distribution Provider written notice that it elects to
withdraw its request for the Cost Envelope Option, in accordance with Section F.7. Should
Applicant fail to provide the required Cost Envelope Option deposit or provide written notice
within such timeframe, Applicant’s request for the Cost Envelope Option shall be deemed
withdrawn, and the Interconnection Request shall continue to be processed in accordance
with the Independent Study Process.
vii) Waiver of the Interconnection Facilities Study
The Interconnection Facilities Study may be waived if Distribution Provider and Applicant
mutually agree to such waiver within either (i) five (5) Business Days following the
Interconnection System Impact Study results meeting, or (ii) within twenty-five (25) Business
Days of the issuance of the final Interconnection System Impact Study report if no
Interconnection System Impact Study results meeting is held. If Distribution Provider and
Applicant agree to waive the Interconnection Facilities Study for an Interconnection Request
where Applicant has selected the Cost Envelope Option, the Interconnection Request shall
not be eligible for the Cost Envelope Option and Applicant’s request for the Cost Envelope
Option shall be deemed withdrawn. The Interconnection Facilities Study may not be waived
for Interconnection Requests that have selected the Cost Envelope Option and for which the
Applicant elects to proceed with Distribution Provider’s preparation of the Cost Envelope
Estimate.
Within thirty (30) Calendar Days after Distribution Provider and Applicant mutually agree to
waive the Interconnection Facilities Study, Distribution Provider shall tender a draft
Generator Interconnection Agreement, together with draft appendices, to Applicant. If
Applicant chooses to forgo the Interconnection Facilities Study and move directly to a
Generator Interconnection Agreement, Applicant must agree in writing to be responsible for
all actual costs of all required facilities deemed necessary by Distribution Provider.
Applicant is responsible for all applicable costs associated with Parallel Operation to support
the safe and reliable operation of the Distribution and Transmission System as set forth in
Section E.4. Refer to Section F.3.e for cost responsibility and time frames for completing the
Generator Interconnection Agreement.
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Revised Cal. P.U.C. Sheet No. 28026-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27264-E
RULE 21 Sheet 59
GENERATING FACILITY INTERCONNECTIONS
(Continued)
59C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
b. Independent Study Process (Continued)
viii) Timing of the Interconnection Facilities Study.
The Interconnection Facilities Study shall be completed and provided to Applicant within
sixty (60) Business Days after Applicant posts the initial Interconnection Financial Security in
accordance with Section F.4.b where Distribution Upgrades or Network Upgrades are
identified and, for Generating Facilities with a Gross Nameplate Rating of 5 MW or less,
Applicant submits the Interconnection Facilities Study deposit in accordance with Section
E.3.a and F.3.b.vi. In cases where no Distribution Upgrades and/or Network Upgrades are
identified and the required facilities are limited to Distribution Provider’s Interconnection
Facilities only, the Interconnection Facilities Study shall be completed within forty-five (45)
Business Days after Applicant posts the initial Interconnection Financial Security and, for
Generating Facilities with a Gross Nameplate Rating of 5 MW or less, Applicant submits the
Interconnection Facilities Study deposit.
If applicable, Distribution Provider will share the study results with the CAISO for review and
comment, and will incorporate CAISO comments, if any, into the study report prior to issuing
a final Interconnection Facilities Study report to Applicant.
Within thirty (30) Calendar Days after Distribution Provider issues the final Interconnection
Facilities Study report to Applicant, or within thirty (30) Calendar Days of an Interconnection
Facilities Study results meeting, if requested, Distribution Provider shall tender a draft
Generator Interconnection Agreement, together with draft appendices. Refer to Section F.3.e
for cost responsibility and time frames for completing the Generator Interconnection
Agreement.
At any time Distribution Provider determines that it will not meet the required time frame for
completing the Interconnection Facilities Study, Distribution Provider shall notify Applicant in
writing as to the status of the Interconnection Facilities Study and provide an estimated
completion date with an explanation of the reasons why additional time is required.
ix) Interconnection Facilities Study Results Meeting.
If requested by Applicant, a results meeting shall be held among Distribution Provider, the
CAISO, if applicable, and Applicant to discuss the results of the Interconnection Facilities
Study, including assigned cost responsibility. Within five (5) Business Days of the request,
Distribution Provider shall contact Applicant to establish a date agreeable to Applicant,
Distribution Provider and the CAISO, if applicable, for the results meeting.
Within thirty (30) Calendar Days after the Interconnection Facilities Study results meeting,
Distribution Provider shall tender a draft Generator Interconnection Agreement, together with
draft appendices, to Applicant.
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Revised Cal. P.U.C. Sheet No. 28027-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27265-E
RULE 21 Sheet 60
GENERATING FACILITY INTERCONNECTIONS
(Continued)
60C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
x) Second and Third Postings of Interconnection Financial Security
Applicant will post its second and third postings of Interconnection Financial Security as set
forth in Sections F.4.c and F.4.d based on the cost responsibility for Network Upgrades,
Distribution Upgrades, and Distribution Provider’s Interconnection Facilities set forth in the
final Interconnection Facilities Study, or the final Interconnection System Impact Study if the
Interconnection Facilities Study is waived in accordance with Section F.3.b.vii.
c. Distribution Group Study Process
i) Initiation of Distribution Study Group
Applicants that apply for the Independent Study Process that pass Screen Q but fail Screen
R will be eligible for inclusion in a Distribution Study Group. Applicant must submit all
materials required to complete their Interconnection Request no later than ten (10) Business
Days after the close of the relevant Distribution Group Study window. This includes
notification from Applicant that they want to proceed with the Distribution Group Study
Process, if applicable, in accordance with Section F.3.a.
Distribution Provider shall perform a Screen Q analysis for the Distribution Study Group
within thirty (30) Business Days of the close of the window, using best available information
about projects that have entered the Distribution Group Study Process under Rule 21 and
the WDAT.
If the Distribution Study Group fails Screen Q, the Distribution Provider will deem the
projects withdrawn from Rule 21 and notify Applicants. Applicants may elect to proceed with
the Transmission Cluster Study Process pursuant to Section F.3.d.
In order to be eligible to participate in the DGS Phase I Interconnection Study, the scoping
meeting must be complete and the Applicant must execute the Detailed Study Agreement
prior to the start date of the DGS Phase I Interconnection Study.
ii) Scoping Meeting
Within five (5) Business Days after Distribution Provider performs the Electrical
Independence Test, it will contact the Applicant(s) to notify them that the Interconnection
Request has passed Screen Q and failed Screen R and is thus eligible for the Distribution
Group Study Process, and establish a date agreeable to Applicant and Distribution Provider
for a scoping meeting.
The Distribution Provider, in coordination with the CAISO, if applicable, shall determine
whether the Interconnection Request is at or near the boundary of an Affected System(s) so
as to potentially impact such Affected System(s). If a determination of potential impact is
made, the Distribution Provider shall invite the Affected System Operator(s) to the scoping
meeting by informing them of the time and place of the scheduled scoping meeting as soon
as practicable.
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Revised Cal. P.U.C. Sheet No. 27266-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25002-E
RULE 21 Sheet 61
GENERATING FACILITY INTERCONNECTIONS
(Continued)
61C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
ii) Scoping Meeting (Continued)
The purpose of the scoping meeting shall be: (i) to discuss reasonable Commercial
Operation Dates and alternative interconnection options; (ii) to exchange information,
including any transmission data that would reasonably be expected to impact Applicant’s
interconnection options; (iii) to analyze such information; (iv) to determine feasible Points of
Interconnection and eliminate alternatives given resources and available information; and (v)
to advise Applicant of the expected start date of the DGS Phase I Interconnection Study.
Distribution Provider will bring to the scoping meeting, as reasonably necessary to
accomplish its purpose, such already available technical data, including, but not limited to: (i)
general facility loadings, (ii) general instability issues, (iii) general short circuit issues, (iv)
general voltage issues, and (v) general reliability issues.
Applicant will bring to the scoping meeting, in addition to the technical data in Attachment A
of the Rule 21 Exporting Generating Facility Interconnection Request form, any system
studies previously performed. Distribution Provider, the CAISO, if applicable, and Applicant
will also bring to the meeting personnel and other resources as may be reasonably required
to accomplish the purpose of the meeting in the time allocated for the meeting.
During the meeting, Applicant shall confirm its Point of Interconnection. The duration of the
meeting shall be only what is sufficient to accomplish its purpose.
Within fifteen (15) Business Days after the scoping meeting, Distribution Provider shall
provide Applicant with a Detailed Study Agreement, which shall contain an outline of the
scope of the DGS Phase I Interconnection Study and DGS Phase II Interconnection Study,
contain a non-binding good faith estimate of the cost to perform such studies, and shall
specify that Applicant is responsible for the actual cost of the Interconnection Studies,
including reasonable administrative costs. Applicant shall execute and deliver to Distribution
Provider the Detailed Study Agreement no later than thirty (30) Business Days after the
scoping meeting or the start date of the DGS Phase I Interconnection Study, whichever is
earlier, or the Interconnection Request shall be deemed withdrawn.
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Revised Cal. P.U.C. Sheet No. 27267-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25003-E
RULE 21 Sheet 62
GENERATING FACILITY INTERCONNECTIONS
(Continued)
62C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
iii) Grouping of Interconnection Requests for a Distribution Group Study
The results of Screen R will determine the Interconnection Requests to be grouped together
for each Distribution Group Study. An Interconnection Request that failed Screen R will be
grouped with other projects that are determined to be electrically interdependent through the
application of Screen R. No later than the date a DGS Phase I Interconnection Study
begins, Distribution Provider may send to each Applicant in a Distribution Study Group a list
of the Interconnection Requests in its Distribution Study Group.
At the Distribution Provider's option, an Interconnection Request received during a particular
Distribution Group Study Application window may be studied individually (Independent Study
Process) or in a Distribution Group Study for the purpose of conducting one or more of the
analyses forming the Interconnection Studies. For each Interconnection Study received
within the same Distribution Group Study Application window, the Distribution Provider may
develop one or more Distribution Study Groups.
iv) Timing of the DGS Phase I Interconnection Study.
Absent extraordinary circumstances, Distribution Provider shall complete and issue a final
DGS Phase I Interconnection Study report within sixty (60) Business Days from the start of
the study. If the DGS Phase I Interconnection Study indicates a need for Network Upgrades,
Distribution Provider will share applicable study results with the CAISO for review and
comment and will incorporate comments into the final DGS Phase I Interconnection Study
report.
At any time Distribution Provider determines that it will not meet the required time frame for
completing the DGS Phase I Interconnection Study, Distribution Provider shall notify all
Applicants in the Distribution Study Group as to the status of the DGS Phase I
Interconnection Study and provide an estimated completion date with an explanation of the
reasons why additional time is required.
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Revised Cal. P.U.C. Sheet No. 27268-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25004-E
RULE 21 Sheet 63
GENERATING FACILITY INTERCONNECTIONS
(Continued)
63C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
iv) Timing of the DGS Phase I Interconnection Study.
Upon request, Distribution Provider shall provide any Applicant in the Distribution Study
Group all relevant supporting documentation, workpapers and pre-Interconnection Request
and post-Interconnection Request power flow, short circuit and dynamic/stability databases,
and currently planned Distribution Upgrades relevant to the Interconnection Request for the
DGS Phase I Interconnection Study. Applicant may be required to sign a non-disclosure
agreement with terms consistent with Section D.7 regarding Confidentiality.
If applicable, Distribution Provider will share the applicable study results with the CAISO for
review and comment, and will incorporate CAISO comments, if any, into the study report
prior to issuing a final DGS Phase I Interconnection Study report to Applicants in the
Distribution Study Group.
v) DGS Phase I Interconnection Study Results Meeting
If requested by an Applicant in a Distribution Study Group or Distribution Provider, a results
meeting shall be held among Distribution Provider, the CAISO, if applicable, and the
Applicant to discuss the results of the DGS Phase I Interconnection Study, including
assigned cost responsibility. Within five (5) Business Days of such request, Distribution
Provider shall contact Applicant to establish a date agreeable to Applicant, Distribution
Provider and the CAISO, if applicable, for the results meeting. If the Applicant or Distribution
Provider has requested a results meeting, it must be completed within thirty (30) Calendar
Days after issuance of the final DGS Phase I Interconnection Study report, unless otherwise
agreed upon by the Distribution Provider and Applicant.
At the Phase I Interconnection Study results meeting, the Applicant shall provide a schedule
outlining key milestones including environmental survey start date, expected environmental
permitting submittal date, expected procurement date of project equipment, back-feed date
for project construction, and expected project construction date. This will assist the parties
in determining if proposed Commercial Operation Dates are reasonable. If large-scale
Distribution Provider’s Interconnection Facilities or Distribution Upgrades for the Generating
Facility have been identified in the DGS Phase I Interconnection Study, such as
telecommunications equipment, distribution feeders to support back feed, a new substation,
and/or expanded substation work, permitting and material procurement lead times may
result in the need to alter the proposed Commercial Operation Date, the Applicant and
Distribution Provider may agree to a new Commercial Operation Date. In addition, where an
Applicant intends to establish Commercial Operation separately for different Electric
Generating Units or project phases at its Generating Facility, it may only do so in accordance
with an implementation plan agreed to in advance by the Distribution Provider and the
CAISO, if applicable, which agreement shall not be unreasonably withheld.
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Revised Cal. P.U.C. Sheet No. 27269-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25005-E
RULE 21 Sheet 64
GENERATING FACILITY INTERCONNECTIONS
(Continued)
64C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
v) DGS Phase I Interconnection Study Results Meeting (Continued)
Where the parties cannot agree to a revised Commercial Operation Date, the Commercial
Operation Date determined reasonable by the Distribution Provider will be used for the DGS
Phase II Interconnection Study, or the Generator Interconnection Agreement (in accordance
with Section F.3.e.iii) if the DGS Phase II Interconnection Study is waived in accordance with
Section F.3.c.ix, where the revised Commercial Operation Date is needed to accommodate
the anticipated completion, assuming Reasonable Efforts by the Distribution Provider of
necessary Distribution Upgrades and/or Distribution Provider’s Interconnection Facilities,
pending the outcome of any relief sought by the Applicant under Sections F.1.d or K. The
Applicant must notify the Distribution Provider within five (5) Business Days following the
Results Meeting if it is initiating dispute procedures under Sections F.1.d or K.
Within five (5) Business Days following the DGS Phase I Interconnection Study results
meeting, the Applicant shall submit to the Distribution Provider all requested information. If
no DGS Phase I Interconnection Study results meeting is held, Applicant shall submit to
Distribution Provider any requested information within thirty (30) Calendar Days of the
receipt of the final DGS Phase I Interconnection Study report.
vi) Initial Posting of Interconnection Financial Security
Each Applicant in a Distribution Study Group shall make its initial posting of Interconnection
Financial Security in accordance with the requirements of Section F.4.b, within sixty (60)
Calendar Days after being provided with the final DGS Phase I Interconnection Study report,
or its Interconnection Request shall be deemed withdrawn. The initial posting of
Interconnection Financial Security will be based on the cost responsibility for Network
Upgrades, Distribution Upgrades, and Distribution Provider’s Interconnection Facilities set
forth in the final DGS Phase I Interconnection Study report.
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Revised Cal. P.U.C. Sheet No. 27270-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25006-E
RULE 21 Sheet 65
GENERATING FACILITY INTERCONNECTIONS
(Continued)
65C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
vii) Modifications
At any time during the course of the Interconnection Studies, Applicant, Distribution Provider,
or the CAISO, as applicable, may identify changes to the planned Interconnection that may
improve the costs and benefits (including reliability) of the Interconnection, and the ability of
the proposed change to accommodate the Interconnection Request. To the extent the
identified changes are acceptable to Distribution Provider, the CAISO, as applicable, and
Applicant, such acceptance not to be unreasonably withheld, Distribution Provider shall
modify the Point of Interconnection and/or configuration in accordance with such changes
without altering the Interconnection Request’s eligibility for participating in Interconnection
Studies.
At the DGS Phase I Interconnection Study results meeting, if elected by Applicant or
Distribution Provider, Applicant should be prepared to discuss any desired modifications to
the Interconnection Request. After the publication of the final DGS Phase I Interconnection
Study report, but no later than five (5) Business Days following the DGS Phase I
Interconnection Study results meeting, Applicant shall submit to Distribution Provider, in
writing, modifications to any information provided in the Interconnection Request.
Distribution Provider will forward Applicant’s request for modification to the CAISO, if
applicable, within two (2) Business Days of receipt.
If no DGS Phase I Interconnection Study results meeting is held, Applicant shall submit to
Distribution Provider any requested modifications within thirty (30) Calendar Days of the
receipt of the final Phase I Interconnection Study report.
Modifications permitted under this Section F.3.c.vii shall include specifically: (a) a decrease
in the electrical output (MW) of the proposed Generating Facility; (b) modifying the technical
parameters associated with the Generating Facility technology or the Generating Facility
step-up transformer impedance characteristics; and (c) modifying the interconnection
configuration. For any modifications other than those permitted above, Distribution Provider,
in coordination with CAISO, if applicable, will evaluate whether the proposed modification to
the Interconnection Request constitutes a Material Modification. Distribution Provider will
inform Applicant in writing whether the modifications would constitute a Material Modification
within ten (10) Business Days of receipt of the proposed request for modification. Any
change to the Point of Interconnection, except for that specified by Distribution Provider in an
Interconnection Study or otherwise allowed under this Section F.3.c.vii, shall constitute a
Material Modification.
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Revised Cal. P.U.C. Sheet No. 27271-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25007-E
RULE 21 Sheet 66
GENERATING FACILITY INTERCONNECTIONS
(Continued)
66C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
vii) Modifications (Continued)
If the proposed modification is determined to be a Material Modification, Applicant may either
withdraw the proposed modification or proceed with a new Interconnection Request for such
modification. Applicant shall make such determination within ten (10) Business Days after
being provided the Material Modification determination results.
Proposed modifications determined not to be Material Modifications may still necessitate the
need to re-evaluate the DGS Phase I Interconnection Study to determine modifications to
the Interconnection Facilities and Distribution Upgrades. Such re-evaluation will occur
during the DGS Phase II Interconnection Study.
viii) Scope and Purpose of the DGS Phase II Interconnection Study and Study Deposit.
Within either (i) five (5) Business Days following the DGS Phase I Interconnection Study
results meeting, or (ii) within thirty (30) Calendar Days of the receipt of the final DGS Phase I
Interconnection Study report if no DGS Phase I Interconnection Study results meeting is
held, Applicant shall submit to Distribution Provider the data required by Distribution
Provider. Within thirty (30) Business Days of the issuance of the final DGS Phase I
Interconnection Study report, for Generating Facilities 5 MW or less, Applicant shall submit
the DGS Phase II Interconnection Study deposit, as set out in Section E.3.a, unless the DGS
Phase II Interconnection Study is waived in accordance with Section F.3.c.ix.
ix) Waiver of the DGS Phase II Interconnection Study
The DGS Phase II Interconnection Study may be waived if Distribution Provider and all
Applicants included in the DGS Phase I Interconnection Study mutually agree to such waiver
within thirty (30) Calendar Days of the issuance of the DGS Phase I Interconnection Study
report. Within thirty (30) Calendar Days after Distribution Provider and Applicants agree to
waive the DGS Phase II Interconnection Study, Distribution Provider shall tender a draft
Generator Interconnection Agreement, together with draft appendices, to Applicant.
Applicant is responsible for all costs associated with Parallel Operation to support the safe
and reliable operation of the Distribution and Transmission System as set forth in Section
E.4. Refer to Section F.3.e for cost responsibility and time frames for completing the
Generator Interconnection Agreement.
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Revised Cal. P.U.C. Sheet No. 27272-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25008-E
RULE 21 Sheet 67
GENERATING FACILITY INTERCONNECTIONS
(Continued)
67C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
x) DGS Phase II Interconnection Study Procedures
Distribution Provider shall utilize existing studies to the extent practicable in conducting the
DGS Phase II Interconnection Study. The Distribution Provider shall commence the DGS
Phase II Interconnection Study within sixty (60) Calendar Days of the issuance of the final
DGS Phase I Interconnection Study report.
Distribution Provider shall complete and distribute to Applicants the DGS Phase II
Interconnection Study reports within sixty (60) Business Days after the commencement of
each DGS Phase II Interconnection Study. The Distribution Provider will issue a final DGS
Phase II Interconnection Study report to Applicant.
At the request of Applicant or at any time Distribution Provider determines that it will not
meet the required time frame for completing the DGS Phase II Interconnection Study,
Distribution Provider shall notify Applicant as to the schedule status of the DGS Phase II
Interconnection Study and provide an estimated completion date. If the Distribution Provider
is unable to complete the DGS Phase II Interconnection Study in the time specified, such
notice shall provide an explanation of the reasons why additional time is required.
Upon request of the Applicant, Distribution Provider shall provide Applicant all supporting
documentation, work papers, and relevant pre-Interconnection Request and post-
Interconnection Request power, short circuit and stability databases for the DGS Phase II
Interconnection Study, subject to confidentiality arrangements consistent with Section D.7.
The Distribution Provider will conduct a DGS Phase II Interconnection Study that will
incorporate eligible Interconnection Requests from the previous DGS Phase I
Interconnection Study. The DGS Phase II Interconnection Study shall (i) update, as
necessary, analyses performed in the DGS Phase I Interconnection Study to account for the
withdrawal of Interconnection Requests or other projects in the Interconnection Study
Process, (ii) identify Distribution Upgrades needed to physically interconnect the Generating
Facility, (iii) assign cost responsibility for the Distribution Upgrades, (iv) identify for each
Interconnection Request a final Point of Interconnection and Distribution Provider’s
Interconnection Facilities, (v) provide an estimate for each Interconnection Request of the
Distribution Provider’s Interconnection Facilities, and (vi) optimize in-service timing
requirements based on operational studies in order to maximize achievement of the
Commercial Operation Dates of the Generating Facilities, as applicable.
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Revised Cal. P.U.C. Sheet No. 27273-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25009-E
RULE 21 Sheet 68
GENERATING FACILITY INTERCONNECTIONS
(Continued)
68C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
xi) DGS Phase II Interconnection Study Results Meeting
If requested by an Applicant in a Distribution Study Group, a results meeting shall be held
among Distribution Provider, the CAISO, if applicable, and the Applicant to discuss the
results of the DGS Phase II Interconnection Study, including selection of the final
Commercial Operation Date and assigned cost responsibility. Within five (5) Business Days
of such request, Distribution Provider shall contact Applicant to establish a date agreeable to
Applicant, Distribution Provider and the CAISO, if applicable, for the results meeting. If
Applicant wants to have a meeting, it must be completed within thirty (30) Calendar Days
after issuance of the final DGS Phase II Interconnection Study report, unless mutually
agreed upon by the Distribution Provider and Applicant.
Distribution Provider shall tender a draft Generator Interconnection Agreement pursuant to
F.3.e.i. Refer to Section F.3.e for cost responsibility and time frames for completing the
Generator Interconnection Agreement.
xii) Timing of the DGS Phase II Interconnection Study
At any time Distribution Provider determines that it will not meet the required time frame for
completing the DGS Phase II Interconnection Study, Distribution Provider shall notify each
Applicant in the Distribution Study Group in writing as to the status of the DGS Phase II
Interconnection Study and provide an estimated completion date with an explanation of the
reasons why additional time is required.
xiii) Second and Third Postings of Interconnection Financial Security
Each Applicant in a Distribution Study Group will post its second and third posting of
Interconnection Financial Security as set forth in Sections F.4.c and F.4.d based on the cost
responsibility for Network Upgrades, Distribution Upgrades, and Distribution Provider’s
Interconnection Facilities set forth in the final DGS Phase II Interconnection Study, or the
final DGS Phase I Interconnection Study if the DGS Phase II Interconnection Study is
waived in accordance with Section F.3.c.ix.
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Revised Cal. P.U.C. Sheet No. 27274-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25010-E
RULE 21 Sheet 69
GENERATING FACILITY INTERCONNECTIONS
(Continued)
69C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
c. Distribution Group Study Process (Continued)
xiv) Withdrawal and Reallocation of Cost to Interconnection Requests in a Distribution Study
Group
If at any time, an Interconnection Request is withdrawn or a Generator Interconnection
Agreement is terminated, the upgrades identified in the Interconnection Studies will be
revaluated to determine if they are still needed. If the Distribution Provider determines that a
restudy is needed, it will be conducted pursuant to Section F.3.c.xv. Any costs, identified in
the Distribution Group Study not already funded by Interconnection Financial Security that
has been posted by the withdrawing Applicant, will be the responsibility of remaining
Applicants in the Distribution Group and will be reallocated in accordance with E.4.e.
xv) Restudy
If a restudy is required following the issuance of the final DGS Phase II Interconnection
Study, or the final DGS Phase I Interconnection Study if the DGS Phase II Interconnection
Study is waived, due to a project withdrawal, Distribution Provider shall notify the remaining
Applicant(s) in writing.
The restudy report shall be completed and provided to each Applicant remaining in the
Distribution Group within sixty (60) Business Days of the withdrawal of the Interconnection
Request that caused the restudy. The Applicants remaining in the Distribution Group will be
responsible for the cost of the restudy.
xvi) Automatic Timing Extension
If during any six month period, the number of Interconnection Requests exceeds by fifty (50)
percent the number of active Interconnection Request in the preceding six month period, the
study timelines for Distribution Group Studies begun during the next twelve (12) months will
automatically increase as follows. The time to complete the DGS Phase I Interconnection
Study pursuant to Section F.3.c.iv will increase from sixty (60) Business Days to one
hundred twenty (120) Business Days. The time to complete the DGS Phase II
Interconnection Study pursuant to Section F.3.c.x will increase from sixty (60) Business
Days to one hundred twenty (120) Business Days. The time to tender a draft Generator
Interconnection Agreement pursuant to F.3.e.i will increase from thirty (30) Calendar Days to
forty-five (45) Calendar Days. Distribution Provider will notify Applicants in the Distribution
Study Group in writing after commencement of DGS Phase I Interconnection Study of the
extension.
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Revised Cal. P.U.C. Sheet No. 27275-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25011-E
RULE 21 Sheet 70
GENERATING FACILITY INTERCONNECTIONS
(Continued)
70C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
d. Transmission Cluster Study Process
If Applicant’s Interconnection Request fails Screen Q or elects to be studied under the
Transmission Cluster Study Process, Applicant shall have the option of applying for
Interconnection under the Transmission Cluster Study Process of the Wholesale Distribution
Access Tariff in accordance with its provisions. If Applicant fails Screen Q, Applicant’s
Interconnection Request shall be deemed withdrawn under this Rule regardless of whether
Applicant applies for Interconnection under the WDAT.
An Applicant that chooses to apply under the Transmission Cluster Study Process of the WDAT
must file a valid Interconnection Request and post the applicable study deposit as set out in
Distribution Provider’s WDAT. If Applicant chooses to apply under the WDAT, then Applicant’s
Interconnection Request will be subject to the terms of Distribution Provider’s WDAT applicable
to the Transmission Cluster Study Process, including those provisions establishing cost
responsibility. Upon completion of the Transmission Cluster Study Process under the WDAT,
Applicants that are eligible for a State-jurisdictional Interconnection can, in accordance with the
WDAT, either execute the applicable Commission-approved Rule 21 Generator Interconnection
Agreement for Exporting Generating Facilities or the WDAT Generator Interconnection
Agreement. Such Commission-approved Generator Interconnection Agreement for Exporting
Generating Facilities will include the cost responsibility established in the Transmission Cluster
Study.
If and when an Applicant submits a new interconnection request under the WDAT, Applicant is
under the jurisdiction of FERC. On the date the applicable Commission-approved Rule 21
Generator Interconnection Agreement for Exporting Generating Facilities is executed by
Applicant, or Producer where those are different entities, and Distribution Provider, jurisdiction
over the Interconnection reverts back to the Commission.
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Revised Cal. P.U.C. Sheet No. 27276-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25012-E
RULE 21 Sheet 71
GENERATING FACILITY INTERCONNECTIONS
(Continued)
71C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
e. Generator Interconnection Agreement for Detailed Study
i) Tender
The Distribution Provider shall tender a draft Generator Interconnection Agreement, together
with draft appendices, within thirty (30) Calendar Days of the following:
1) Agreement by the Distribution Provider and Applicant to waive the Interconnection
Facilities Study in accordance with Section F.3.b.vii,
2) Issuance of the final Interconnection Facilities Study report (or results meeting, if held) to
Applicant,
3) Agreement by the Distribution Provider and all Applicants included in a DGS Phase I
Interconnection Study to waive the DGS Phase II Interconnection Study in accordance
with Section F.3.c.ix,
4) Issuance of the final DGS Phase II Interconnection Study report to each Applicant in the
Distribution Study Group (or results meeting, if held). Applicant(s) shall provide written
comments, or notification of no comments, to the draft appendices within thirty (30)
Calendar Days.
ii) Negotiation
Notwithstanding Section F.3.e.i, at the request of Applicant, Distribution Provider shall begin
negotiations with Applicant concerning the appendices to the Generator Interconnection
Agreement at any time after Distribution Provider provides Applicant with the final
Interconnection Facilities Study report (or final Interconnection System Impact Study report if
the Interconnection Facilities Study is waived) or final DGS Phase II Interconnection Study
report (or the final DGS Phase I Interconnection Study report if the DGS Phase II
Interconnection Study is waived) in the case of the Distribution Group Study Process.
Distribution Provider and Applicant shall negotiate concerning any disputed provisions of the
appendices to the draft Generator Interconnection Agreement for not more than ninety (90)
Calendar Days after Distribution Provider provides Applicant with the final DGS Phase II
Interconnection Study report (or the final DGS Phase I Interconnection Study report if the
DGS Phase II Interconnection Study is waived) in the case of the Distribution Group Study
Process or the final Interconnection Facilities Study report (or final Interconnection System
Impact Study report if the Interconnection Facilities Study is waived) in the case of the
Independent Study Process.
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Revised Cal. P.U.C. Sheet No. 27277-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25013-E
RULE 21 Sheet 72
GENERATING FACILITY INTERCONNECTIONS
(Continued)
72C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
e. Generator Interconnection Agreement for Detailed Study (Continued)
ii) Negotiation (Continued)
Producers whose Interconnection Requests were studied in a Distribution Group Study
Process will be required to fund upgrades triggered by more than one Interconnection
Request in accordance with a payment schedule that allows such upgrades to be completed
in time for the earliest Commercial Operation Date of such Interconnection Requests.
Producer is responsible for all costs associated with Parallel Operation to support the safe
and reliable operation of the Distribution System and Transmission System as set forth in
Section E.4.
If Applicant determines that negotiations are at an impasse, it may request termination of the
negotiations at any time after tender of the draft Generator Interconnection Agreement
pursuant to Section F.3.e.i and initiate Dispute Resolution procedures pursuant to Section K.
Unless otherwise agreed by the Parties, if Applicant or Producer, where those are different
entities, has not executed the Generator Interconnection Agreement, or initiated Dispute
Resolution procedures pursuant to Section K, within ninety (90) Calendar Days after
issuance of the final DGS Phase II Interconnection Study report (or the final DGS Phase I
Interconnection Study report if the DGS Phase II Interconnection Study is waived) in the case
of the Distribution Group Study Process or Interconnection Facilities Study report (or final
Interconnection System Impact Study report if the Interconnection Facilities Study is waived)
in the case of the Independent Study Process, it shall be deemed to have withdrawn its
Interconnection Request.
iii) Extensions of Commercial Operation Date
The Commercial Operation Date will be agreed upon in the executed Generator
Interconnection Agreement. Reasonable Commercial Operation Dates will be discussed at
the DGS Phase II Interconnection Study results meeting, or the DGS Phase I Interconnection
Study results meeting if the DGS Phase II Interconnection Study results meeting is waived, in
the case of the Distribution Group Study Process, the Interconnection Facilities Study results
meeting or the Interconnection System Impact Study results meeting if the Interconnection
Facilities Study is waived in the case of the Independent Study Process. A request for an
extension of the Commercial Operation Date after the Generator Interconnection Agreement
is executed will be agreed to provided that, the Producer is still responsible for funding any
Distribution Upgrades and Network Upgrades as specified in the Generator Interconnection
Agreement and under the same payment schedule agreed upon in the Generator
Interconnection Agreement. This provision has no impact on any power purchase
agreement terms.
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Revised Cal. P.U.C. Sheet No. 27278-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25014-E
RULE 21 Sheet 73
GENERATING FACILITY INTERCONNECTIONS
(Continued)
73C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
3. Detailed Study Interconnection Review Process (Continued)
f. Engineering & Procurement (E&P) Agreement
Prior to executing a Generator Interconnection Agreement, in order to advance the
implementation of its interconnection, an Applicant may request, and Distribution Provider shall
offer, an E&P Agreement that authorizes Distribution Provider to begin engineering and
procurement of long lead-time items necessary for the establishment of the interconnection.
However, Distribution Provider shall not be obligated to offer an E&P Agreement if Applicant is in
Dispute Resolution as a result of an allegation that Applicant has failed to meet any milestones
or comply with any prerequisites specified in other parts of this Rule. The E&P Agreement is an
optional procedure. The E&P Agreement shall provide for Applicant to pay the cost of all
activities authorized by Applicant and to make advance payments or provide other satisfactory
security for such costs.
Applicant shall pay the cost of such authorized activities and any cancellation costs for
equipment that is already ordered for its interconnection, which cannot be mitigated as hereafter
described, whether or not such items or equipment later become unnecessary. If Applicant
withdraws its Interconnection Request, or either Applicant or Distribution Provider terminates the
E&P Agreement, to the extent the equipment ordered can be canceled under reasonable terms,
Applicant shall be obligated to pay the associated cancellation costs. To the extent that the
equipment cannot be reasonably canceled, Distribution Provider may elect: (i) to take title to the
equipment, in which event Distribution Provider shall refund Applicant any amounts paid by
Applicant for such equipment and shall pay the cost of delivery of such equipment, or (ii) to
transfer title to and deliver such equipment to Applicant, in which event Applicant shall pay any
unpaid balance and cost of delivery of such equipment.
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Revised Cal. P.U.C. Sheet No. 27279-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25015-E
RULE 21 Sheet 74
GENERATING FACILITY INTERCONNECTIONS
(Continued)
74C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security
a. Types of Interconnection Financial Security
The Interconnection Financial Security posted by an Applicant may be any combination of the
following types of Interconnection Financial Security provided in favor of Distribution Provider:
(i) an irrevocable and unconditional letter of credit issued by a bank or financial institution that
has a credit rating of A or better by Standard and Poor’s or A2 or better by Moody’s;
(ii) an unconditional and irrevocable guaranty issued by a company has a credit rating of A or
better by Standard and Poor’s or A2 or better by Moody’s;
(iii) a cash deposit standing to the credit of Distribution Provider and in an interest-bearing
escrow account maintained at a bank or financial institution that is reasonably acceptable to
Distribution Provider.
Interconnection Financial Security instruments as listed above shall be in such form as
Distribution Provider may reasonably require from time to time by notice to Applicants, or in such
other form as has been evaluated and approved as reasonably acceptable by Distribution
Provider.
Distribution Provider shall require the use of standardized forms of Interconnection Financial
Security to the greatest extent possible. If at any time the guarantor of the Interconnection
Financial Security fails to maintain the credit rating required by this Section F.4.a, Applicant shall
provide to Distribution Provider replacement Interconnection Financial Security meeting the
requirements of this Section F.4.a within five (5) Business Days of the change in credit rating.
Interest on a cash deposit standing to the credit of Distribution Provider in an interest-bearing
escrow account under subpart (iii) of this Section F.4.a will accrue to Applicant’s benefit.
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Revised Cal. P.U.C. Sheet No. 27280-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25016-E
RULE 21 Sheet 75
GENERATING FACILITY INTERCONNECTIONS
(Continued)
75C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
b. Initial Posting of Interconnection Financial Security
On or before sixty (60) Calendar Days after the publication of either the final Interconnection
System Impact Study report, or the final DGS Phase I Interconnection Study Report, Applicant
must post, with notice to Distribution Provider, two separate Interconnection Financial Security
instruments.
First, Applicant proposing to interconnect a Large Generating Facility shall post an
Interconnection Financial Security instrument in an amount equal to the lesser of (i) fifteen
percent (15%) of the total cost responsibility assigned to Applicant in the final Interconnection
System Impact Study or final DGS Phase I Interconnection Study in the case of the Distribution
Group Study Process for Network Upgrades, (ii) $20,000 per MW of electrical output of the
Large Generating Facility or the amount of megawatt increase in the generating capacity of each
existing Generating Facility as listed by Applicant in its Interconnection Request, including any
requested modifications thereto, or (iii) $7,500,000.
Applicant proposing to interconnect a Small Generating Facility shall post an Interconnection
Financial Security instrument in an amount equal to the lesser of (i) fifteen percent (15%) of the
total cost responsibility assigned to Applicant in the final Interconnection System Impact Study or
final DGS Phase I Interconnection Study in the case of the Distribution Group Study Process for
Network Upgrades, or (ii) $20,000 per megawatt of electrical output of the Small Generating
Facility or the amount of MW increase in the generating capacity of each existing Generating
Facility as listed by Applicant in its Interconnection Request.
Second, Applicant shall also post an Interconnection Financial Security instrument in the amount
of twenty percent (20%) of the total estimated cost responsibility assigned to Applicant in the
final Interconnection System Impact Study or final DGS Phase I Interconnection Study in the
case of the Distribution Group Study Process for Distribution Provider’s Interconnection Facilities
and Distribution Upgrades.
The failure by an Applicant to timely post the Interconnection Financial Security required by this
Section F.4.b shall result in the Interconnection Request being deemed withdrawn subject to
Section F.6.
If required by Distribution Provider Applicant shall provide Distribution Provider with written
notice that it has posted the required Interconnection Financial Security no later than the
applicable final day for posting.
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Revised Cal. P.U.C. Sheet No. 27281-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25017-E
RULE 21 Sheet 76
GENERATING FACILITY INTERCONNECTIONS
(Continued)
76C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
c. Second Posting of Interconnection Financial Security
On or before one hundred twenty (120) Calendar Days after issuance of the final DGS Phase II
Interconnection study report (or final DGS Phase I Interconnection Study report if the DGS
Phase II Interconnection Study is waived) or final Interconnection Facilities Study report (or final
Interconnection System Impact Study report if the Interconnection Facilities Study is waived in
the case of the Independent Study Process), Applicant shall post two separate Interconnection
Financial Security instruments.
First, Applicant proposing to interconnect a Large Generating Facility shall post an
Interconnection Financial Security instrument such that the total Interconnection Financial
Security posted by Applicant for Network Upgrades equals the lesser of (i) $15 million, or (ii)
thirty percent (30%) of the total cost responsibility assigned to Applicant for Network Upgrades in
either the final Interconnection System Impact Study (final DGS Phase I Interconnection Study in
the case of the Distribution Group Study Process) or final Interconnection Facilities Study (final
DGS Phase II Interconnection Study in the case of the Distribution Group Study Process),
whichever is lower.
Applicant proposing to interconnect a Small Generating Facility shall post an Interconnection
Financial Security instrument such that the total Interconnection Financial Security posted by
Applicant for Network Upgrades equals the lesser of (i) $1 million, or (ii) thirty percent (30%) of
the total cost responsibility assigned to Applicant for Network Upgrades in either the final
Interconnection System Impact Study (final DGS Phase I or final DGS Phase II Interconnection
Studies, respectively, for the Distribution Group Study Process) or final Interconnection Facilities
Study, whichever is lower.
Second, Applicant shall also post an Interconnection Financial Security instrument such that the
total Interconnection Financial Security posted by Applicant for Distribution Provider’s
Interconnection Facilities and Distribution Upgrades equals thirty percent (30%) of the total cost
responsibility assigned to Applicant in the final DGS Phase II Interconnection Study (or final DGS
Phase I Interconnection Study if the DGS Phase II Interconnection study is waived) in the case
of the Distribution Group Study Process, or final Interconnection Facilities Study (or final
Interconnection System Impact Study if the Interconnection Facilities Study is waived) in the
case of the Independent Study Process, for Distribution Provider’s Interconnection Facilities and
Distribution Upgrades.
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Revised Cal. P.U.C. Sheet No. 27282-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25018-E
RULE 21 Sheet 77
GENERATING FACILITY INTERCONNECTIONS
(Continued)
77C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
c. Second Posting of Interconnection Financial Security (Continued)
If the start date for Construction Activities of Network Upgrades, Distribution Provider’s
Interconnection Facilities and Distribution Upgrades on behalf of Applicant is prior to one
hundred twenty (120) Calendar Days after issuance of the final DGS Phase II Interconnection
Study report (or final DGS Phase I Interconnection Study report if the DGS Phase II
Interconnection Study is waived) in the case of the Distribution Group Study Process or final
Interconnection Facilities Study report (or final Interconnection System Impact Study report if the
Interconnection Facilities Study is waived) in the case of the Independent Study Process, that
start date must be set forth in Applicant’s Generator Interconnection Agreement and Applicant
shall make its second posting of Interconnection Financial Security pursuant to Section F.4.d
rather than Section F.4.c.
The failure by an Applicant to timely post the Interconnection Financial Security required by this
Section F.4.c shall result in the Interconnection Request being deemed withdrawn and subject to
Section F.6 or, if applicable, shall constitute grounds for termination of the Generator
Interconnection Agreement.
d. Third Posting of Interconnection Financial Security
On or before the start of Construction Activities for Network Upgrades or Distribution Provider’s
Interconnection Facilities or Distribution Upgrades on behalf of Applicant, whichever is earlier,
Applicant shall modify the two separate Interconnection Financial Security instruments posted as
follows.
With respect to the Interconnection Financial Security instrument for Network Upgrades,
Applicant shall modify this instrument so that it equals one hundred percent (100%) of the total
cost responsibility assigned to Applicant for Network Upgrades in the final DGS Phase II
Interconnection Study (or the final DGS Phase I Interconnection Study if the DGS Phase II
Interconnection Study is waived) in the case of the Distribution Group Study Process or final
Interconnection Facilities Study (or the final Interconnection System Impact Study if the
Interconnection Facilities Study is waived) in the case of the Independent Study Process.
With respect to the Interconnection Financial Security instrument for Distribution Provider’s
Interconnection Facilities or Distribution Upgrades, Applicant shall modify this instrument so that
it equals one hundred percent (100%) of the total cost responsibility assigned to Applicant for
Distribution Provider’s Interconnection Facilities and Distribution Upgrades in the final DGS
Phase II Interconnection Study (or the final DGS Phase I Interconnection Study if the DGS
Phase II Interconnection Study is waived) in the case of the Distribution Group Study Process or
final Interconnection Facilities Study (or the final Interconnection System Impact Study if the
Interconnection Facilities Study is waived) in the case of the Independent Study Process.
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Revised Cal. P.U.C. Sheet No. 27283-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25019-E
RULE 21 Sheet 78
GENERATING FACILITY INTERCONNECTIONS
(Continued)
78C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
d. Third Posting of Interconnection Financial Security (Continued)
The failure by an Applicant to timely post the Interconnection Financial Security required by this
Section F.4.d shall constitute grounds for termination of the Generator Interconnection
Agreement.
e. General Effect of Withdrawal of Interconnection Request or Termination of the Generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Independent Study Process.
Except as set forth in Section F.4.e.i, withdrawal of an Interconnection Request or termination of
a Generator Interconnection Agreement shall allow Distribution Provider to liquidate the
Interconnection Financial Security, or balance thereof, posted by Applicant for Network
Upgrades at the time of withdrawal. To the extent the amount of the liquidated Interconnection
Financial Security plus capital, if any, separately provided by Applicant to satisfy its obligation to
finance Network Upgrades in accordance with Section E.4 exceeds the total cost responsibility
for Network Upgrades assigned to Applicant by the final Interconnection Facilities Study, or the
final Interconnection System Impact Study if the Interconnection Facilities Study is waived,
Distribution Provider shall remit to Applicant the excess amount.
Withdrawal of an Interconnection Request or termination of a Generator Interconnection
Agreement shall result in the release to Applicant of any Interconnection Financial Security
posted by Applicant for Distribution Provider’s Interconnection Facilities and Distribution
Upgrades, except with respect to any amounts necessary to pay for costs incurred or irrevocably
committed by Distribution Provider on behalf of Applicant for Distribution Provider’s
Interconnection Facilities and Distribution Upgrades and for which Distribution Provider has not
been reimbursed.
i) Conditions for Partial Recovery of Interconnection Financial Security Upon Withdrawal of
Interconnection Request or Termination of Generator Interconnection Agreement.
A portion of the Interconnection Financial Security shall be released to Applicant, consistent
with Section F.4.e.ii, if the withdrawal of the Interconnection Request or termination of the
Generator Interconnection Agreement occurs for any of the following reasons:
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Revised Cal. P.U.C. Sheet No. 27284-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25020-E
RULE 21 Sheet 79
GENERATING FACILITY INTERCONNECTIONS
(Continued)
79C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
e. General Effect of Withdrawal of Interconnection Request or Termination of the Generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Independent Study Process. (Continued)
i) Conditions for Partial Recovery of Interconnection Financial Security Upon Withdrawal of
Interconnection Request or Termination of Generator Interconnection Agreement.
(Continued)
(1) Failure to Secure a Power Purchase Agreement.
At the time of withdrawal of the Interconnection Request or termination of the Generator
Interconnection Agreement, Applicant demonstrates to Distribution Provider that it has
failed to secure an acceptable power purchase agreement for the energy or capacity of
the Generating Facility after a good faith effort to do so. A good faith effort can be
established by demonstrating participation in a competitive solicitation process or
bilateral negotiations with an entity other than an Affiliate that progressed, at minimum,
to the mutual exchange by all counter-parties of proposed term sheets.
(2) Failure to Secure a Necessary Permit.
At the time of withdrawal of the Interconnection Request or termination of the Generator
Interconnection Agreement, Applicant demonstrates to Distribution Provider that it has
received a final denial from the primary issuing Governmental Authority of any permit or
other authorization necessary for the construction or operation of the Generating Facility.
(3) Increase in the Cost of Distribution Provider’s Interconnection Facilities or Distribution
Upgrades.
Applicant withdraws the Interconnection Request or terminates the Generator
Interconnection Agreement based on an increase of: (i) more than 30% or $300,000,
whichever is greater, in the estimated cost of Distribution Provider’s Interconnection
Facilities; or (ii) more than 30% or $300,000, whichever is greater, in the estimated cost
of Distribution Upgrades allocated to Applicant from the Interconnection System Impact
Study to the Interconnection Facilities Study. This Section F.4.e.i.(3) shall not apply if the
cause of the cost increase under (i) or (ii) above is the result of a change requested by
Applicant pursuant to Section F.3.b.v.
(4) Material Change in Applicant’s Interconnection Facilities Created by Distribution
Provider’s Change in the Point of Interconnection.
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Revised Cal. P.U.C. Sheet No. 27285-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25021-E
RULE 21 Sheet 80
GENERATING FACILITY INTERCONNECTIONS
(Continued)
80C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
e. General Effect of Withdrawal of Interconnection Request or Termination of the Generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Independent Study Process. (Continued)
i) Conditions for Partial Recovery of Interconnection Financial Security Upon Withdrawal of
Interconnection Request or Termination of Generator Interconnection Agreement.
(4) Material Change in Applicant’s Interconnection Facilities Created by Distribution
Provider’s Change in the Point of Interconnection. (Continued)
Applicant withdraws the Interconnection Request or terminates the Generator
Interconnection Agreement based on a material change from the Interconnection
System Impact Study in the Point of Interconnection for the Generating Facility
mandated by Distribution Provider and included in the final Interconnection Facilities
Study. A material change in the Point of Interconnection shall be where the Point of
Interconnection has moved to (i) a different substation, (ii) a different line on a different
right of way, or (iii) a materially different location than previously identified on the same
line.
ii) Schedule for Determining Non-Refundable Portion of the Interconnection Financial Security
for Network Upgrades.
(1) Up to One Hundred Twenty days (120) after the final Interconnection Facilities Study
report (or final Interconnection System Impact Study report if the Interconnection
Facilities Study is waived)
If, at any time after the initial posting of the Interconnection Financial Security for
Network Upgrades under Section F.4.b and on or before one hundred twenty (120)
Calendar Days after the date of issuance of the final Interconnection Facilities Study
report (or final Interconnection System Impact Study report if the Interconnection
Facilities Study is waived), Applicant withdraws the Interconnection Request or
terminates the Generator Interconnection Agreement, as applicable, in accordance with
Section F.4.e.i, Distribution Provider shall liquidate the Interconnection Financial
Security for Network Upgrades under Section F.4.b and reimburse Applicant in an
amount of (i) any posted amount less fifty percent (50%) of the value of the posted
Interconnection Financial Security for Network Upgrades (with a maximum of $10,000
per requested and approved MW value of the Generating Facility Capacity at the time of
withdrawal being retained by Distribution Provider), or (ii) if the Interconnection Financial
Security has been drawn down to finance Pre-Construction Activities for Network
Upgrades on behalf of Applicant, the lesser of the remaining balance of the
Interconnection Financial Security or the amount calculated under (i) above. If Applicant
has separately provided capital apart from the Interconnection Financial Security to
finance Pre-Construction Activities for Network Upgrades, Distribution Provider will credit
the capital provided as if drawn from the Interconnection Financial Security and apply (ii)
above.
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Revised Cal. P.U.C. Sheet No. 27286-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25022-E
RULE 21 Sheet 81
GENERATING FACILITY INTERCONNECTIONS
(Continued)
81C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
e. General Effect of Withdrawal of Interconnection Request or Termination of the Generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Independent Study Process. (Continued)
ii) Schedule for Determining Non-Refundable Portion of the Interconnection Financial Security
for Network Upgrades. (Continued)
(2) Between One Hundred Twenty-One (121) Calendar Days and After Final
Interconnection Facilities Study Report and the Commencement of Construction
Activities
If, at any time between one hundred twenty-one (121) Calendar Days and after the date
of issuance of the final Interconnection Facilities Study report (or final Interconnection
System Impact Study report if the Interconnection Facilities Study is waived), and the
commencement of Construction Activities for either Network Upgrades or Distribution
Provider’s Interconnection Facilities or Distribution Upgrades, Applicant withdraws the
Interconnection Request or terminates the Generator Interconnection Agreement, as
applicable, in accordance with Section F.4.e.i, Distribution Provider shall liquidate the
Interconnection Financial Security for Network Upgrades under Section F.4.c and
reimburse Applicant in an amount of (i) any posted amounts less fifty percent (50%) of
the value of the posted Interconnection Financial Security for Network Upgrades (with a
maximum of $20,000 per requested and approved MW value of the Generating Facility
Capacity at the time of withdrawal being retained by Distribution Provider), or, (ii) if the
Interconnection Financial Security has been drawn down to finance Pre-Construction
Activities for Network Upgrades on behalf of Applicant, the lesser of the remaining
balance of the Interconnection Financial Security or the amount calculated under (i)
above. If Applicant has separately provided capital apart from the Interconnection
Financial Security to finance Pre-Construction Activities for Network Upgrades,
Distribution Provider will credit the capital provided as if drawn from the Interconnection
Financial Security and apply (ii) above.
(3) After Commencement of Construction Activities. Once Construction Activities on
Network Upgrades on behalf of Applicant commence, any withdrawal of the
Interconnection Request or termination of the Generator Interconnection Agreement by
Applicant will be treated in accordance with this Section F.4.e.
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Revised Cal. P.U.C. Sheet No. 27287-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25023-E
RULE 21 Sheet 82
GENERATING FACILITY INTERCONNECTIONS
(Continued)
82C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
e. General Effect of Withdrawal of Interconnection Request or Termination of the Generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Independent Study Process. (Continued)
ii) Schedule for Determining Non-Refundable Portion of the Interconnection Financial Security
for Network Upgrades. (Continued)
(4) Notification and Accounting by Distribution Provider
Distribution Provider will notify Applicant within three (3) Business Days of liquidating
any Interconnection Financial Security. Within seventy-five (75) Calendar Days of any
liquidating event, Distribution Provider will provide Applicant with an accounting of the
disposition of the proceeds of the liquidated Interconnection Financial Security and all
proceeds not otherwise reimbursed to Applicant or applied to costs incurred or
irrevocably committed by Distribution Provider on behalf of Applicant in accordance with
this Section F.4.e shall be applied as directed by the Commission. Where an Applicant
with remaining proceeds from Interconnection Financial Security cannot be located,
such remaining proceeds shall escheat to the State pursuant to the Unclaimed Property
Law commencing with the California Code of Civil Procedure §1500.
f. General Effect of Withdrawal of Interconnection Request or Termination of the generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Distribution Group Study Process.
Withdrawal of an Interconnection Request or termination of a Generator Interconnection
Agreement shall allow Distribution Provider to liquidate the Interconnection Financial Security, or
balance thereof, posted by Applicant for Network Upgrades or Distribution Upgrades at the time
of withdrawal. To the extent the amount of the liquidated Interconnection Financial Security plus
capital, if any, separately provided by Applicant to satisfy its obligation to finance Network
Upgrades or Distribution Upgrades in accordance with Section E.4 exceeds the total cost
responsibility for Network Upgrades or Distribution Upgrades assigned to Applicant by the final
DGS Phase II Interconnection study (or final DGS Phase I Interconnection Study if the DGS
Phase II Interconnection Study is waived), Distribution Provider shall remit to Applicant the
excess amount.
Withdrawal of an Interconnection Request or termination of a Generator Interconnection
Agreement shall result in the release to Applicant of any Interconnection Financial Security
posted by Applicant for Distribution Provider’s Interconnection Facilities, except with respect to
any amounts necessary to pay for costs incurred or irrevocably committed by Distribution
Provider on behalf of Applicant for Distribution Provider’s Interconnection Facilities and for which
Distribution Provider has not been reimbursed.
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Revised Cal. P.U.C. Sheet No. 27288-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 25024-E
RULE 21 Sheet 83
GENERATING FACILITY INTERCONNECTIONS
(Continued)
83C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
4. Interconnection Financial Security (Continued)
f. General Effect of Withdrawal of Interconnection Request or Termination of the generator
Interconnection Agreement on Interconnection Financial Security for Interconnection Requests
Studied Under the Distribution Group Study Process. (Continued)
i) Notification and Accounting by Distribution Provider.
Distribution Provider will notify Applicant within three (3) Business Days of liquidating any
Interconnection Financial Security. Within seventy-five (75) Calendar Days of any liquidating
event, Distribution Provider will provide Applicant with an accounting of the disposition of the
proceeds of the liquidated Interconnection Financial Security and all proceeds not otherwise
reimbursed to Applicant or applied to costs incurred or irrevocably committed by Distribution
Provider on behalf of Applicant in accordance with this Section F.4.f. Where an Applicant
with remaining proceeds from Interconnection Financial Security cannot be located, such
remaining proceeds shall escheat to the State pursuant to the Unclaimed Property Law
commencing with the California Code of Civil Procedure § 1500.
5. Commissioning Testing and Parallel Operation
a. Commissioning Testing
Producer Arranges for and Completes Commissioning Testing of Generating Facility and
Producer’s Interconnection Facilities: Producer is responsible for testing new Generating
Facilities and associated Interconnection Facilities according to Section L.5 to ensure
compliance with the safety and reliability provisions of this Rule prior to being operated in parallel
with Distribution Provider’s Distribution or Transmission System. For non-Certified Equipment,
Producer shall develop a written testing plan to be submitted to Distribution Provider for its
review and acceptance. Alternatively, Producer and Distribution Provider may agree to have
Distribution Provider conduct the required testing at Producer’s expense. Where applicable, the
test plan shall include the installation test procedures published by the manufacturer of the
Generating Facility or Interconnection Facilities. Facility testing shall be conducted at a mutually
agreeable time, and depending on who conducts the test, Distribution Provider or Producer shall
be given the opportunity to witness the tests.
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Revised Cal. P.U.C. Sheet No. 28028-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27289-E
RULE 21 Sheet 84
GENERATING FACILITY INTERCONNECTIONS
(Continued)
84C9 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
5. Commissioning Testing and Parallel Operation (Continued)
b. Parallel Operation or Momentary Parallel Operation
Producer shall not commence Parallel Operation of its Generating Facility with Distribution
Provider’s system unless it has received Distribution Provider’s express written permission to do
so. Distribution Provider shall authorize Producer’s Generating Facility for Parallel Operation or
Momentary Parallel Operation with Distribution Provider’s Distribution or Transmission System,
in writing, within five (5) Business Days of satisfactory compliance with the terms of all applicable
agreements. Compliance may include, but not be limited to, provision of any required
documentation and satisfactorily completing any required inspections or tests as described
herein or in the agreements formed between Producer and Distribution Provider.
6. Withdrawal
Applicant may withdraw its Interconnection Request at any time by written notice of such withdrawal
to Distribution Provider. In addition, after receipt of the Interconnection Request, if Applicant fails to
adhere to the requirements and timelines of this tariff, except as provided in Section K (Disputes),
Distribution Provider shall deem the Interconnection Request to be withdrawn and shall provide
written notice to Applicant of the deemed withdrawal within five (5) Business Days and an
explanation of the reasons for such deemed withdrawal. Upon receipt of such written notice,
Applicant shall have five (5) Business Days in which to either respond with information or action that
either cures the deficiency or supports its position that the deemed withdrawal was erroneous and
notifies Distribution Provider of its intent to pursue Dispute Resolution. If Applicant cures the
deficiency or supports its position that the deemed withdrawal was erroneous, Applicant shall not
lose its Queue Position established pursuant to Section E.5.
Withdrawal shall result in the removal of the Interconnection Request from the Interconnection Study
process. If Applicant disputes the withdrawal and removal from the Interconnection Study process
and has elected to pursue Dispute Resolution as set forth in Section K, Applicant's Interconnection
Request is not required to be considered in any ongoing Interconnection Study during the Dispute
Resolution process. In the event of such withdrawal, Distribution Provider, subject to the provisions
in Section D.7 and Sections E.3.a, as applicable, shall provide, at Applicant's request, all information
that Distribution Provider developed for any completed study conducted up to the date of withdrawal
of the Interconnection Request.
7. Cost Envelope Option
Interconnection Requests for Generating Facilities evaluated under the Fast Track Process or
Independent Study Process may qualify for the Cost Envelope Option described in this Section F.7
provided the requirements set forth in subsection (a) below are met. As further described below,
under the Cost Envelope Option, Distribution Provider will prepare a Cost Envelope Estimate that
includes an estimate of the costs to interconnect a Generating Facility in which (i) certain identified
elements of the estimated costs are subject to the Cost Envelope, and (ii) certain identified elements
of the estimated cost are excluded from the Cost Envelope and are Applicant’s responsibility based
on actual costs. Should an Applicant decide to proceed to a Generator Interconnection Agreement
following receipt of the Cost Envelope Estimate in accordance with Section F.2.e for the Fast Track
Process, or Section F.3.e for the Independent Study Process, the Generator Interconnection
Agreement shall include cost responsibility for required upgrades based upon the Cost Envelope
Estimate.
N N
Revised Cal. P.U.C. Sheet No. 28029-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27290-E
RULE 21 Sheet 85
GENERATING FACILITY INTERCONNECTIONS
(Continued)
85C10 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
7. Cost Envelope Option (Continued)
a. Eligibility for Cost Envelope Option
i) Eligibility of Interconnection Requests Under the Fast Track Process
Interconnection Requests processed under the Fast Track Process are eligible for the Cost
Envelope Option if all of the following criteria are met:
(1) Applicant selects the Cost Envelope Option in its Interconnection Request and provides
the additional required information specified therein for the Cost Envelope Option; and
(2) The Interconnection Request passes the Fast Track Process evaluation pursuant to
Section F.2.; and
(3) Applicant provides Distribution Provider the Cost Envelope Option deposit of $2,500
within ten (10) Business Days following receipt of the Distribution Provider’s non-binding
cost estimate provided in accordance with Sections F.2.a, F.2.b, F.2.c.iii, or F.2.d, as
applicable. The Cost Envelope Option deposit of $2,500 is subject to adjustment upon
mutual agreement of the Distribution Provider and Applicant.
In the event it is determined under the Initial Review or Supplemental Review that i)
there are no Distribution Provider Interconnection Facilities and/or Distribution Upgrades
required for interconnection of the Generating Facility, or ii) there are no Distribution
Provider Interconnection Facilities and/or Distribution Upgrades required for
interconnection of the Generating Facility for which Applicant bears cost responsibility,
Applicant’s election of the Cost Envelope Option shall be considered not applicable and
shall be deemed withdrawn. In such event, the Interconnection Request shall continue
to be processed in accordance with the Fast Track Process.
ii) Eligibility of Interconnection Requests Under The Independent Study Process
Interconnection Requests processed under the Independent Study Process are eligible for
the Cost Envelope Option if all of the following criteria are met:
(1) Applicant selects the Cost Envelope Option in its Interconnection Request and provides the additional required information specified therein for the Cost Envelope Option; and (2) The Interconnection Request qualifies for evaluation under the Independent Study Process pursuant to Section F.3.a; and, (3) An Interconnection System Impact Study and Interconnection Facilities Study are completed for the Interconnection Request pursuant to Sections F.3.b.ii and F.3.b.viii, respectively; and, (4) In the case of a NEM Generating Facility or Solar ≤1 MW Generating Facility, Applicant provides Distribution Provider the Cost Envelope Option deposit of $2,500 within the timeframe set forth in Section F.3.b.vi. The Cost Envelope Option deposit of $2,500 is
subject to adjustment upon mutual agreement of the Distribution Provider and Applicant.
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Revised Cal. P.U.C. Sheet No. 28030-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27291-E
RULE 21 Sheet 86
GENERATING FACILITY INTERCONNECTIONS
(Continued)
86C11 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
7. Cost Envelope Option (Continued)
b. Cost Responsibility Under the Cost Envelope Option
i) Cost Responsibility for Facilities Subject to Cost Envelope
Applicant shall be responsible for the actual cost of the portion of Interconnection Facilities
and/or Distribution Upgrades subject to the Cost Envelope within the range of plus or minus
twenty-five (25) percent of the estimated cost of such facilities identified in the Cost
Envelope Estimate. Applicant’s cost responsibility for that portion of the Interconnection
Facilities and/or Distribution Upgrades subject to the Cost Envelope shall be capped at
twenty-five (25) percent above the estimated cost, and Applicant shall not be responsible for
the portion of the actual cost of such Interconnection Facilities and/or Distribution Upgrades
that exceeds twenty-five (25) percent of the estimate. Correspondingly, Applicant’s cost
responsibility for the portion of the Interconnection Facilities and/or Distribution Upgrades
subject to the Cost Envelope shall not be less than the amount determined as twenty-five
(25) percent below the estimated cost, and any portion of the actual cost of such
Interconnection Facilities and/or Distribution Upgrades that is below twenty-five (25) percent
of the estimate shall not be refundable to Applicant.
ii) Cost Responsibility for Facilities Not Subject to Cost Envelope
Applicant shall be responsible for the actual cost of the portion of Interconnection Facilities
and/or Distribution Upgrades that are not subject to the Cost Envelope and the actual cost of
Network Upgrades in accordance with Section F.7.e.
c. Timing of Applicant’s Selection of Cost Envelope Option and Payment of Deposit
i) For Interconnection Requests under the Fast Track Process, Applicant must select the Cost
Envelope Option in its Interconnection Request to be eligible for the Cost Envelope Option,
in accordance with Section F.7.a.i. In addition, for Interconnection Requests that pass the
Fast Track Process, Applicant must provide the Distribution Provider a $2,500 Cost
Envelope Option deposit within ten (10) Business Days of receipt of the Distribution
Provider’s non-binding cost estimate for the Interconnection Facilities and/or Distribution
Upgrades required for interconnection. If Applicant fails to provide the Cost Envelope Option
deposit within ten (10) Business Days of receipt of the Distribution Provider’s non-binding
cost estimate for the Interconnection Facilities and/or Distribution Upgrades required for
interconnection, Applicant’s request for the Cost Envelope Option shall be deemed
withdrawn and the Interconnection Request shall not be eligible for the Cost Envelope
Option. However, if the Applicant fails to provide the Cost Envelope Option deposit within
the required timeframe, a Generator Interconnection Agreement may be requested by
Applicant in accordance with Section F.2.e, and such Generator Interconnection Agreement
will reflect the non-binding cost estimate for the Distribution Provider’s required
Interconnection Facilities and/or Distribution Upgrades provided during the Initial or
Supplemental Review, and Applicant shall be responsible for the actual cost of such
upgrades.
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Revised Cal. P.U.C. Sheet No. 28389-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27292-E
RULE 21 Sheet 87
GENERATING FACILITY INTERCONNECTIONS
(Continued)
87C5 Issued by Date Filed Dec 16, 2016
Advice Ltr. No. 2945-E-A Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
F. Review Process For Interconnection Requests (Continued)
7. Cost Envelope Option (Continued)
c. Timing of Applicant’s Selection of Cost Envelope Option and Payment of Deposit (Continued)
ii) For Interconnection Requests under the Independent Study Process, Applicant must select
the Cost Envelope Option in its Interconnection Request to be eligible for the Cost Envelope
Option, in accordance with Section F.7.a.ii. In the case of a NEM Generating Facility or
Solar ≤1 MW Generating Facility, Applicant must also provide Distribution Provider the Cost
Envelope Option deposit of $2,500 following completion of the Interconnection System
Impact Study within the timeframe set forth in Section F.3.b.vi. The Cost Envelope Option
deposit of $2,500 is subject to adjustment upon mutual agreement of the Distribution
Provider and Applicant.
An Applicant may withdraw its request for the Cost Envelope Option following the
Distribution Provider’s completion of the Interconnection System Impact Study in the event
the Distribution Provider and Applicant agree to waive the Interconnection Facilities Study in
accordance with Section F.3.b.vii, by so indicating on Attachment B of the Detailed Study
Agreement, or for NEM Generating Facilities by providing Distribution Provider written notice
of such withdrawal prior to commencement of the Interconnection Facilities Study in
accordance with Section F.3.b.vi.
d. Distribution Provider’s Preparation of the Cost Envelope Estimate
For Interconnection Requests evaluated under the Fast Track Process, Distribution Provider
shall complete and issue to Applicant the Cost Envelope Estimate within twenty (20) Business
Days following Distribution Provider’s receipt of the Cost Envelope Option deposit required
pursuant to Section F.7.a.i.3. For Interconnection Requests evaluated under the Independent
Study Process, the Cost Envelope Estimate will be developed as part of the Interconnection
Facilities Study and will be included in the Interconnection Facilities Study report in accordance
with Section F.3.b.viii.
Applicant shall be responsible for the actual cost of development of the Cost Envelope Estimate.
If full payment for the required Interconnection Facilities and/or Distribution Upgrades identified
in the Cost Envelope Estimate has not been paid by Applicant to the Distribution Provider
pursuant to a Generator Interconnection Agreement entered into by Applicant and Distribution
Provider in accordance with Section F.2.e or Section F.3.e, as applicable, within two hundred ten
(210) Calendar Days from the date Distribution Provider provides the Cost Envelope Estimate to
Applicant, the Cost Envelope Estimate shall be subject to re-evaluation and adjustment by the
Distribution Provider at Applicant’s expense.
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Revised Cal. P.U.C. Sheet No. 28975-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27293-E
RULE 21 Sheet 88
GENERATING FACILITY INTERCONNECTIONS
(Continued)
88C5 Issued by Date Filed Jun 8, 2017
Advice Ltr. No. 2945-E-B Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No. E-4850
F. Review Process For Interconnection Requests (Continued)
7. Cost Envelope Option (Continued)
e. Cost Elements Not Subject to Cost Envelope
Any and all costs of required environmental studies, environmental mitigation, permits, and/or
easements related to the construction and installation of Distribution Provider’s Interconnection
Facilities and/or Distribution Upgrades shall not be subject to the Cost Envelope. Such costs
shall be the responsibility of Applicant based on the actual cost incurred by the Distribution
Provider.
Any and all costs of required Network Upgrades shall not be subject to the Cost Envelope. Such
costs shall be the responsibility of Applicant based on the actual cost incurred by the Distribution
Provider.
The cost of any Distribution Provider’s Interconnection Facilities and/or Distribution Upgrades
triggered by one or more earlier queued Interconnection Requests that are also required for
interconnection of a later-queued Generating Facility under the Cost Envelope Option shall not
be subject to the Cost Envelope. In the event one or more of the earlier-queued projects
withdraws (or is delayed to the extent the upgrade will not be completed in time to meet the later-
queued Generating Facility’s requested In-Service Date), all, or a portion, of Distribution
Provider’s Interconnection Facilities and/or Distribution Upgrades may become the responsibility
of the later-queued Generating Facility. Upon such an occurrence, the Generator
Interconnection Agreement shall be amended to reflect the Applicant’s responsibility for such
Distribution Provider’s Interconnection Facilities and/or Distribution Upgrades based on actual
costs unless Applicant requests in writing, within ten (10) Business Days of Applicant’s receipt of
Distribution Provider’s non-binding estimated cost of such required facilities, that it elects to
include such facilities in the Cost Envelope. Within ten (10) Business Days of Applicant’s
request, Distribution Provider shall provide to Applicant an estimate of the cost required to
update the Cost Envelope Estimate. Applicant shall notify Distribution Provider in writing within
ten (10) Business Days of Applicant’s receipt of Distribution Provider’s estimate whether (i)
Applicant elects to proceed with the update to the Cost Envelope Estimate at Applicant’s
expense, or (ii) that Applicant withdraws its request to include the additional facilities in the Cost
Envelope. If Applicant elects to proceed with the update to the Cost Envelope Estimate,
Distribution Provider shall complete the update within the sum of the time allowed for each step
utilized by the Distribution Provider in preparation of the initial Cost Envelope Estimate pursuant
to Section F.2 for Interconnection Requests evaluated under the Fast Track Process, or Section
F.3.b for Interconnection Requests evaluated under the Independent Study Process, from
receipt of payment of the estimated cost of the update. Should Applicant fail to so notify
Distribution Provider within the ten (10) Business Day period, Applicant’s request to include such
additional facilities in the Cost Envelope shall be deemed withdrawn and such additional facilities
shall be the responsibility of Applicant based on actual cost.
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Revised Cal. P.U.C. Sheet No. 28976-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27294-E
RULE 21 Sheet 89
GENERATING FACILITY INTERCONNECTIONS
(Continued)
89C5 Issued by Date Filed Jun 8, 2017
Advice Ltr. No. 2945-E-B Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No. E-4850
F. Review Process For Interconnection Requests (Continued)
7. Cost Envelope Option (Continued)
f. Modifications
Under the Fast Track Process, modifications are not permitted to the Generating Facility, related
equipment, Point of Interconnection or other interconnection parameters that would require a re-
evaluation of the Initial Review or Supplemental Review. However, notwithstanding these
restrictions, an Applicant may identify and suggest minor changes to the Interconnection
Facilities (e.g., minor adjustments to physical location of switchgear or other equipment,
adjustments to routing of conductor from the Point of Common Coupling to the Point of
Interconnection, etc.) upon or near completion of Applicant’s final design of its Interconnection
Facilities. If an Applicant identifies such changes, Applicant shall notify Distribution Provider of
the requested changes and if, in the reasonable judgement of Distribution Provider, a re-
evaluation of the costs under the Cost Envelope Option is required, Distribution Provider will
provide Applicant within ten (10) Business Days of receipt of Applicant’s notice an estimate of
the time required to re-evaluate the costs under the Cost Envelope Option and the estimated
cost of such re-evaluation. Applicant may either (i) accept the additional time and cost to
complete the re-evaluation, (ii) withdraw the proposed changes, or (iii) proceed with a new
Interconnection Request for such changes. Applicant shall provide Distribution Provider written
notice of its election within ten (10) Business Days following Applicant’s receipt of Distribution
Provider’s estimated additional time and cost required for the re-evaluation. If Applicant elects to
proceed with the re-evaluation of the costs under the Cost Envelope Option, Distribution
Provider shall complete the re-evaluation within twenty (20) Business Days from receipt of all
required technical data related to the proposed changes and payment of the estimated cost of
the re-evaluation. Should Applicant fail to so notify Distribution Provider within such ten (10)
Business Day period, Applicant’s request to make the proposed changes shall be deemed
withdrawn.
Under the Independent Study Process, any requested modifications, including required updates
to costs under the Cost Envelope Option, shall be made in accordance with Section F.3.b.v. If
Applicant elects to proceed with re-evaluation of the costs under the Cost Envelope Option
pursuant to Section F.3.b.v, Distribution Provider shall complete the re-evaluation within the sum
of the time allowed for each step utilized by the Distribution Provider for preparation of the initial
Cost Envelope Estimate pursuant Section F.3.b from receipt of all required technical data related
to the proposed changes and payment of the estimated cost of the re-evaluation.
g. Tender of the Generator Interconnection Agreement Under the Cost Envelope Option
Negotiation and execution of the Generator Interconnection Agreement shall be in accordance
with Section F.2.e for Interconnection Requests evaluated under the Fast Track Process, and in
accordance with Section F.3.e.ii for Interconnection Requests evaluated under the Independent
Study Process.
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Revised Cal. P.U.C. Sheet No. 28798-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28034-E
RULE 21 Sheet 90
GENERATING FACILITY INTERCONNECTIONS
(Continued)
90C5 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details
T
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*
* Inadvertent Export projects that meet the requirements
specified in Section Mm bypass Screens K and L, and
are processed under Screen M, as described in Section
Mm.
Revised Cal. P.U.C. Sheet No. 28035-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27296-E
RULE 21 Sheet 91
GENERATING FACILITY INTERCONNECTIONS
(Continued)
91C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
L
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Revised Cal. P.U.C. Sheet No. 28036-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27297-E
RULE 21 Sheet 92
GENERATING FACILITY INTERCONNECTIONS
(Continued)
92C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens
The Initial Review consists of Screens A through M. If any of the Screens A through H are not
passed, a quick review of the failed Screen(s) may determine the requirements to address the
failure(s). Otherwise, Supplemental Review is required.
Some examples of solutions that may be available to mitigate the impact of a failed Screen A
through H are:
1. Replace an overloaded distribution transformer with a larger transformer.
2. Replace overloaded secondary conductors with larger conductor.
3. Determine if phase balancing on the transformer is possible with minimal review.
4. If possible without further study check if the Generating Facility will actually
overstress equipment.
a. Screen A: Is the PCC on a Networked Secondary System?
• If Yes (fail), must go to Supplemental Review except if the Generating Facility is on a Spot
Network and meets the following criteria. If the Generating Facility meets the following
criteria, continue to Screen B pursuant to Section G.1.
The proposed Generating Facility must utilize an inverter-based equipment package and,
together with the aggregated other inverter-based generation, shall not exceed the smaller of 5%
of a Spot Network's maximum load or 50 kW. Under no condition shall the interconnection of a
Generating Facility result in a backfeed of a Spot Network or cause unnecessary operation of
any Spot Network protectors.
• If No (pass), continue to Screen B.
Significance: Special considerations must be given to Generating Facilities proposed to be
installed on Networked Secondary Systems because of the design and operational aspects of
network protectors. There are no such considerations for radial distribution systems.
b. Screen B: Is Certified Equipment used?
Does the Interconnection Request propose to use Certified Equipment as set out in Section L or
does the equipment have interim Distribution Provider approval?
• If Yes (pass), continue to Screen C.
• If No (fail) continue to Screen C pursuant to Section G.1.
Interim approval allows Distribution Provider to treat equipment that has not completed this
Rule’s Certification requirements as having met the intent of this screen. Interim approval is
granted at Distribution Provider’s discretion on case by case bases, and approval for one
Generating Facility does not guarantee approval for any other Generating Facility.
L
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Revised Cal. P.U.C. Sheet No. 28037-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27298-E
RULE 21 Sheet 93
GENERATING FACILITY INTERCONNECTIONS
(Continued)
93C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens (Continued)
b. Screen B: Is Certified Equipment used? (Continued)
Significance: If the Generating and/or Interconnection Facility has been Certified or previously
approved by Distribution Provider, Distribution Provider does not need to repeat its full review
and/or test of the Generating and/or Interconnection Facility’s Protective Functions. Site
Commissioning Testing may still be required to ensure that the Protective Functions are working
properly.
Certification indicates that the criteria in Section L, as appropriate, have been tested and verified.
c. Screen C: Is the Starting Voltage Drop within acceptable limits?
• If Yes (pass), continue to Screen D.
• If No (fail), continue to Screen D pursuant to Section G.1.
Note: This Screen only applies to Generating Facilities that start by motoring the Generator(s).
Distribution Provider has two options in determining whether Starting Voltage Drop is
acceptable. The option to be used is at Distribution Provider’s discretion.
Option 1: Distribution Provider may determine that the Generating Facility’s starting In-rush
Current is equal to or less than the continuous ampere rating of the Customer’s service
equipment.
Option 2: Distribution Provider may determine the impedances of the service distribution
transformer (if present) and the secondary conductors to Customer’s service equipment and
perform a voltage drop calculation. Alternatively, Distribution Provider may use tables or
nomographs to determine the voltage drop. Voltage drops caused by starting a Generator must
be less than 2.5% for primary Interconnections and 5% for secondary Interconnections.
Significance:
1. This Screen addresses potential voltage fluctuation problems that may be caused by
Generators that start by motoring.
2. When starting, Generating Facilities should have minimal impact on the service voltage to
other Distribution Provider Customers.
3. Passing this Screen does not relieve Producer from ensuring that its Generating Facility
complies with the flicker requirements of this Rule, Section H.2.d.
d. Screen D: Is the transformer or secondary conductor rating exceeded?
Do the maximum aggregated Gross Ratings for all the Generating Facilities connected to a
secondary distribution transformer exceed the transformer or secondary conductor rating,
modified per established Distribution Provider practice, absent any Generating Facilities?
L
L
Revised Cal. P.U.C. Sheet No. 28038-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27299-E
RULE 21 Sheet 94
GENERATING FACILITY INTERCONNECTIONS
(Continued)
94C10 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens (Continued)
d. Screen D: Is the transformer or secondary conductor rating exceeded? (Continued)
• If Yes (fail), continue to Screen E pursuant to Section G.1.
• If No (pass), continue to screen E.
Significance: This screen addresses potential secondary transformer or secondary conductor
overloads. When Distribution Provider’s analysis determines a transformer or conductor change
is required, Distribution Provider will furnish Applicant with an explanation of why the change is
needed.
e. Screen E: Does the Single-Phase Generator cause unacceptable imbalance?
If the proposed Generating Facility is single-phase and is to be interconnected on a center tap
neutral of a 240 volt service, does it cause unacceptable imbalance between the two phases of
the 240 volt service?
• If Yes (fail), continue to Screen E pursuant to Section G.1.
• If No (pass), continue to screen F.
Significance: Generating Facilities connected to a single-phase transformer with 120/240V
secondary voltage must be installed such that the aggregated gross output is as balanced as
practicable between the two phases of the 240 volt service. When Distribution Provider’s
analysis determines a transformer change is required; Distribution Provider will furnish the
customer with an explanation of why the change is needed.
f. Screen F: Is the Short Circuit Current Contribution Ratio within acceptable limits?
• If Yes (pass), continue to Screen G.
• If No (fail), continue to Screen G pursuant to Section G.1.
Note: This Screen does not apply to Generating Facilities with a Gross Rating of 11 kVA or less.
When measured at primary side (high side) of the Dedicated Distribution Transformer serving a
Generating Facility, the sum of the Short Circuit Contribution Ratios of all Generating Facilities
connected to Distribution Provider’s Distribution System circuit that serves the Generating
Facility must be less than or equal to 0.1.
Significance: If the Generating Facility passes this Screen, it can be expected that it will have no
significant impact on Distribution Provider’s Distribution System’s short circuit duty, fault
detection sensitivity, relay coordination or fuse-saving schemes.
L
L
Revised Cal. P.U.C. Sheet No. 28039-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27300-E
RULE 21 Sheet 95
GENERATING FACILITY INTERCONNECTIONS
(Continued)
95C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens (Continued)
g. Screen G: Is the Short Circuit Interrupting Capability Exceeded?
Does the proposed Generating Facility, in aggregate with other Generating Facilities on the
distribution circuit, cause any distribution protective devices and equipment (including, but not
limited to, substation breakers, fuse cutouts, and line reclosers), or Interconnection Request
equipment on the system to exceed 87.5 % of the short circuit interrupting capability; or is the
Interconnection proposed for a circuit that already exceeds 87.5 % of the short circuit interrupting
capability?
• If Yes (fail) continue to Screen H pursuant to Section G.1.
• If No (pass), continue to Screen H
Note: This Screen does not apply to Generating Facilities with a Gross Rating of 11 kVA or less.
Significance: If the Generating Facility passes this screen, it can be expected that it will not
cause any of Distribution Provider’s equipment to be overstressed.
h. Screen H: Is the line configuration compatible with the Interconnection type?
• If Yes (pass), continue to Screen I.
• If No (fail), continue to Screen I pursuant to Section G.1.
Note: This Screen does not apply to Generating Facilities with a Gross Rating of 11 kVA or less
Line Configuration Screen: Identify primary distribution line configuration that will serve the
Generating Facility. Based on the type of Interconnection to be used for the Generating Facility,
determine from Table G.1 if the proposed Generating Facility passes the Screen.
Table G-1 Type of Interconnection
Type of Interconnection
Primary Distribution to be made to
Line Type Configuration Primary Distribution Line Result/Criteria
Three-phase, three-wire Any type Pass Screen
Three-phase, four-wire Single-phase, Pass Screen
Three-phase, four-wire All others To pass, aggregate
(For any line that has such a Generating Facility nameplate
section OR mixed three-wire & four-wire) rating must be less than
or equal to 10% of Line
Section peak load.
L
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Revised Cal. P.U.C. Sheet No. 28799-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28040-E
RULE 21 Sheet 96
GENERATING FACILITY INTERCONNECTIONS
(Continued)
96C5 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens (Continued)
h. Screen H: Is the line configuration compatible with the Interconnection type? (Continued)
Significance: If the primary distribution line serving the Generating Facility is of a “three-wire”
configuration, or if the Generating Facility’s distribution transformer is single-phase and
connected in a line-to-neutral configuration, then there is no concern about over-voltages to
Distribution Provider’s, or other Customer’s equipment caused by loss of system neutral
grounding during the operating time of the Non-Islanding Protective Function.
i. Screen I: Will power be exported across the PCC?
• If Yes, Continue to Screen J. This includes Options 5 and 6 below.
• If No, then to ensure that the Generating Facility does not export across the PCC, the
Generating Facility must incorporate one of the first four options shown below. Following
that selection, Initial Review is complete.
Option 1: (“Reverse Power Protection”): To ensure power is never exported across the PCC, a
reverse power Protective Function may be provided. The default setting for this Protective
Function shall be 0.1% (export) of the service transformer’s rating, with a maximum 2.0 second
time delay. For multiple tariff interconnections refer to Section J.8.
Option 2: (“Minimum Power Protection”): To ensure at least a minimum amount of power is
imported across the PCC at all times (and, therefore, that power is not exported), an under-
power Protective Function may be provided. The default setting for this Protective Function shall
be 5% (import) of Generating Facility’s total Gross Rating, with a maximum 2.0 second time
delay.
Option 3: (Certified Non-Islanding Protection): To ensure the incidental export of power is limited
to acceptable levels, this option requires that all of the following conditions be met: a) the total
Gross Capacity of the Generating Facility must be no more than 25% of the nominal ampere
rating of Producer’s service equipment; b) the total Gross Capacity of the Generating Facility
must be no more than 50% of Producer’s service transformer capacity rating (this capacity
requirement does not apply to Customers taking primary service without an intervening
transformer); and c) the Generating Facility must be Certified as Non-Islanding.
The ampere rating of the Customer’s service equipment to be used in this evaluation will be that
rating for which the customer’s utility service was originally sized or for which an upgrade has
been approved. It is not the intent of this provision to allow increased export simply by increasing
the size of the customer’s service panel, without separate approval for the resize.
Option 4: (Relative Generating Facility Rating): This option, when used, requires the Net Rating
of the Generating Facility to be so small in comparison to its host facility’s minimum load, that the
use of additional Protective Functions is not required to ensure that power will not be exported to
Distribution Provider’s Distribution or Transmission System. This option requires the Generating
Facility capacity to be no greater than 50% of Producer’s verifiable minimum Host Load over the
past 12 months.
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Revised Cal. P.U.C. Sheet No. 28800-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28041-E
RULE 21 Sheet 97
GENERATING FACILITY INTERCONNECTIONS
(Continued)
97C7 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens (Continued)
i. Screen I: Will power be exported across the PCC? (Continued)
Option 5: Inadvertent Export as described in Section M.
Option 6: Inadvertent Export utilizing UL-1741 or UL-1741 SA-Listed grid support (non-islanding)
inverters as described in Section Mm.
Significance:
1. If it can be assured that the Generating Facility will not export power, Distribution Provider’s
Distribution or Transmission System does not need to be studied for load-carrying capability
or Generating Facility power flow effects on Distribution Provider voltage regulators.
2. This Screen permits the use of reverse-power or minimum-power relaying as a Non-
Islanding Protective Function (Option 1, 2, and 3).
3. This Screen allows, under certain defined conditions, for Generating Facilities that
incorporate Certified Non-Islanding protection to qualify for interconnection through the Fast
Track process without implementing reverse power or minimum power Protective Functions
(Option 3).
j. Screen J: Is the Gross Rating of the Generating Facility 11 kVA or less?
• If Yes (pass), skip Screens K, L and M; Initial Review is complete.
• If No (fail), continue to Screen K*.
Significance: The Generating Facility will have a minimal impact on fault current levels and any
potential line over-voltages from loss of Distribution Provider’s Distribution System neutral
grounding.
k. Screen K: Is the Generating Facility a Net Energy Metering (NEM) Generating Facility with
nameplate capacity less than or equal to 500kW?
• If Yes (pass), skip screen L and continue to screen M.
• If No (fail), continue to screen L.
Significance: The purpose of this Screen is solely to facilitate interconnection of NEM facilities
below this size threshold by allowing such facilities to bypass Screen M. The use of nameplate
capacity expedites the Initial Review analysis. In Supplemental Review, the net export will be
analyzed.
*Inadvertent Export systems that meet the requirements specified in Section Mm bypass Screens K and L,
and are processed under Screen M, as described in Section Mm.
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Revised Cal. P.U.C. Sheet No. 28801-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28042-E
RULE 21 Sheet 98
GENERATING FACILITY INTERCONNECTIONS
(Continued)
98C5 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
1. Initial Review Screens (Continued)
l. Screen L: Transmission Dependency and Transmission Stability Test.
Is the Interconnection Request for an area where: (i) there are known, or posted,
transient/dynamic stability limitations, or (ii) the proposed Generating Facility has
interdependencies, known to Distribution Provider, with earlier queued Transmission System
interconnection requests. Where (i) or (ii) above are met, the impacts of this Interconnection
Request to the Transmission System may require Detailed Study.
• If Yes (fail), Supplemental Review is required.
• If No (pass), continue to Screen M.
Significance: Special consideration must be given to those areas identified as having current or
future (due to currently queued interconnection requests) grid stability concerns.
m. Screen M: Is the aggregate Generating Facility capacity on the Line Section less than 15% of
Line Section peak load for all line sections bounded by automatic sectionalizing devices?*
• If Yes (pass), Initial Review is complete.
• If No (fail), Supplemental Review is required.
Significance:
1. Low penetration of Generating Facility capacity will have a minimal impact on the operation
and load restoration efforts of Distribution Provider’s Distribution System.
2. The operating requirements for a high penetration of Generating Facility capacity may be
different since the impact on Distribution Provider’s Distribution System will no longer be
minimal, therefore requiring additional study or controls. The purpose of this Screen is solely
to identify if the Generating Facility needs additional study and is not intended as justification
for limiting the penetration of generation on a line section.
2. Supplemental Review Screens
The Supplemental Review consists of Screens N through P. If any of the Screens are not passed, a
quick review of the failed Screen(s) will determine the requirements to address the failure(s) or that
Detailed Studies are required. In certain instances, Distribution Provider may be able to identify the
necessary solution and determine that Detailed Studies are unnecessary. Some examples of
solutions that may be available to mitigate the impact of a failed Screen are:
1. Replacing a fixed capacitor bank with a switched capacitor bank. 2. Adjustment of line regulation settings. 3. Simple reconfiguration of the distribution circuit.
*Inadvertent Export systems that meet the requirements specified in Section Mm are processed under
Screen M, as described in Section Mm.
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N
Revised Cal. P.U.C. Sheet No. 28802-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28043-E
RULE 21 Sheet 99
GENERATING FACILITY INTERCONNECTIONS
(Continued)
99C6 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
2. Supplemental Review Screens (Continued)
a. Screen N: Penetration Test
Where 12 months of line section minimum load data is available, can be calculated, can be
estimated from existing data, or determined from a power flow model, is the aggregate
Generating Facility capacity on the Line Section less than 100% of the minimum load for all line
sections bounded by automatic sectionalizing devices upstream of the Generating Facility?
• If yes (pass), continue to Screen O. • If no (fail), a quick review of the failure may determine the requirements to address the failure; otherwise Electrical Independence Tests and Detailed Studies are required. Continue to Screen O. (Note: If Electrical Independence tests and Detailed Studies are required, Applicant will continue to the Electrical Independence Tests and Detailed Studies after review of the remaining Supplemental Review Screens, if Applicant elects to proceed.)
Note 1: If none of the above options are available, this screen defaults to Screen M.
Note 2: The type of Generating Facility technology will be taken into account when calculating,
estimating, or determining circuit or Line Section minimum load relevant for the application of this
screen. For solar Generation Facilities with no battery storage, daytime minimum load will be
used (i.e., 10 am to 4 pm for fixed panel solar Generating Facilities and 8 am to 6 pm for solar
Generating Facilities utilizing tracking systems), while absolute minimum load will be used for all
other Generating Facility technologies.
Note 3: When this screen is being applied to a NEM Generating Facility, the net export in kW, if
known which may flow across the Point of Common Coupling into Distribution Provider’s
Distribution System will be considered as part of the aggregate generation.
Note 4: Distribution Provider will not consider as part of the aggregate Generating Facility
capacity for purposes of this screen Generating Facility capacity known to be already reflected in
the minimum load data.
Note 5: NEM Generating Facilities with net export less than or equal to 500 kW that may flow
across the Point of Common Coupling into Distribution Provider’s Distribution or Transmission
System will not be studied in the Transmission Cluster Study Process, but may be studied under
the Independent Study Process.
Significance: Penetration of Generating Facility capacity that does not result in power flow from
the circuit back toward the substation will have a minimal impact on equipment loading,
operation, and protection of the Distribution System.
b. Screen O: Power Quality and Voltage Tests
In aggregate with existing Generating Facility capacity on the Line Section:
i) Can it be determined within the Supplemental Review that the voltage regulation on the line
section can be maintained in compliance with Commission Rule 2 and/or Conservation
Voltage Regulation voltage requirements under all system conditions.
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Revised Cal. P.U.C. Sheet No. 28803-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28044-E
RULE 21 Sheet 100
GENERATING FACILITY INTERCONNECTIONS
(Continued)
100C5 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
2. Supplemental Review Screens (Continued)
b. Screen O: Power Quality and Voltage Tests (Continued)
ii) Can it be determined within the Supplemental Review that the voltage fluctuation is within
acceptable limits as defined by IEEE 1453 or utility practice similar to IEEE1453?
iii) Can it be determined within the Supplemental Review that the harmonic levels meet IEEE
519 limits at the Point of Common Coupling (PCC)?
• If yes to all of the above (pass), continue to Screen P.
• If no to any of the above (fail), a quick review of the failure may determine the
requirements to address the failure; otherwise Electrical Independence Tests and
Detailed Studies are required. Continue to Screen P. (Note: If Electrical Independence
tests and Detailed Studies are required, Applicants will continue to the Electrical
Independence Tests and Detailed Studies after review of the remaining Supplemental
Review Screens.)
Significance: Adverse voltages and undesirable interference may be experienced by other
Customers on Distribution Provider’s Distribution System caused by operation of the
Generating Facility(ies).
c. Screen P: Safety and Reliability Tests
Does the location of the proposed Generating Facility or the aggregate generation capacity on
the Line Section create impacts to safety or reliability that cannot be adequately addressed
without Detailed Study?
• If yes (fail), review of the failure may determine the requirements to address the failure;
otherwise Electrical Independence Tests and Detailed Studies are required. Continue to
Section G.3.
• If no (pass), Supplemental Review is complete.
Significance: In the safety and reliability test, there are several factors that may affect the nature
and performance of an Interconnection. These include, but are not limited to:
1. Generating Facility energy source 2. Modes of synchronization 3. Unique system topology 4. Possible impacts to critical load customers 5. Possible safety impacts
The specific combination of these factors will determine if any system study requirements are
needed. The following are some examples of the items that may be considered under this
screen:
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Revised Cal. P.U.C. Sheet No. 28045-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27306-E
RULE 21 Sheet 101
GENERATING FACILITY INTERCONNECTIONS
(Continued)
101C8 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
2. Supplemental Review Screens (Continued)
c. Screen P: Safety and Reliability Tests (Continued)
1. Does the Line Section have significant minimum loading levels dominated by a small number
of customers (i.e. several large commercial customers)?
2. Is there an even or uneven distribution of loading along the feeder?
3. Is the proposed Generating Facility located in close proximity to the substation (i.e. <2.5
electrical line miles), and is the distribution line from the substation to the customer
composed of large conductor/cable (i.e. 600A class cable)?
4. Does the Generating Facility incorporate a time delay function to prevent reconnection of the
generator to the system until system voltage and frequency are within normal limits for a
prescribed time?
5. Is operational flexibility reduced by the proposed Generating Facility, such that transfer of
the line section(s) of the Generating Facility to a neighboring distribution circuit/substation
may trigger overloads or voltage issues?
6. Does the Generating Facility utilize Certified anti-islanding functions and equipment?
3. Detailed Study Screens
a. Screen Q: Is the Interconnection Request electrically Independent of the Transmission System?
Distribution Provider, in consultation with the CAISO, will determine, based on knowledge of the
interdependencies with earlier-queued interconnection requests under any tariff, whether the
Interconnection Request to the Distribution System is of sufficient MW size and located at a point
of interconnection such that it is reasonably anticipated to require or contribute to the need for
Network Upgrades. If Distribution Provider determines that no interdependencies exist as
described above, then the Interconnection Request will be deemed to have passed Distribution
Provider’s Determination of Electrical Independence for the CAISO Controlled Grid. If
Distribution Provider determines that interdependencies exist as described above, then Applicant
may be studied under the Transmission Cluster Study Process as set forth in Section F.3.d.
Distribution Provider will coordinate with the CAISO if necessary to conduct the Determination of
Electrical Independence for the CAISO Controlled Grid as set forth in Section 4.2 of Appendix Y
to the CAISO Tariff. The results of the incremental power flow, aggregate power flow, and short-
circuit current contribution tests set out in Section 4.2 of Appendix Y to the CAISO Tariff will
determine whether the Interconnection Request is electrically independent from the CAISO
Controlled Grid.
• If Yes (pass), continue to Screen R.
• If No (fail), proceed to Section F.3.d.
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Revised Cal. P.U.C. Sheet No. 28046-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27307-E
RULE 21 Sheet 102
GENERATING FACILITY INTERCONNECTIONS
(Continued)
102C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
3. Detailed Study Screens (Continued)
a. Screen Q: Is the Interconnection Request electrically Independent of the Transmission System?
(Continued)
Note 1: NEM Generating Facilities with net export less than or equal to 500 kW that may flow
across the Point of Common Coupling will not be studied in the Transmission Cluster Study
Process, but may be studied under the Independent Study Process.
Significance: Generating Facilities that are electrically interdependent with the Transmission
System must be studied with other interconnection requests that have Transmission System
interdependencies. It is possible to pass this Screen Q (i.e., be found to have no electrical
interdependencies with earlier-queued Distribution System and/or Transmission System
interconnection requests as set out above), be studied under the Independent Study Process,
and still trigger a Reliability Network Upgrade.
b. Screen R: Is the Interconnection Request independent of other earlier-queued and yet to be
studied interconnection requests interconnecting to the Distribution System?
For Interconnection Requests that are electrically independent from the CAISO Controlled Grid,
Distribution Provider will evaluate each Interconnection Request for known or reasonably
anticipated relationships between the Interconnection Request and any earlier-queued
interconnection requests in the Distribution Group Study Process, the Independent Study
Process, or interconnection requests studied under predecessor interconnection procedures that
have yet to complete their respective interconnection studies. Distribution Provider may conduct
incremental power flow, aggregate power flow, and/or short-circuit duty tests using existing
interconnection studies, Base Case data, overall system knowledge, and engineering judgment
to determine whether an Interconnection Request can be studied independently of earlier-
queued interconnection requests. If the Interconnection Request being evaluated for electrical
independence on the Distribution System may be electrically related to earlier-queued
interconnection requests that have yet to complete their respective interconnection studies, then
it fails the evaluation of electrical independence for the Distribution System.
• If Yes (pass), continue to Independent Study Process
• If No (fail), continue to the Distribution Group Study Process
Significance: Interconnection Requests that are electrically related to earlier queued
interconnection requests that have not yet been studied do not qualify for independent study.
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Revised Cal. P.U.C. Sheet No. 28047-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27308-E
RULE 21 Sheet 103
GENERATING FACILITY INTERCONNECTIONS
(Continued)
103C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
3. Detailed Study Screens (Continued)
c. Independent Study Process and Distribution Group Study Process Interconnection Studies
The Interconnection Studies shall consist of an Interconnection System Impact Study and an
Interconnection Facilities Study for the Independent Study Process or the DGS Phase I
Interconnection Study and the DGS Phase II Interconnection Study for the Distribution Group
Study Process. The Interconnection Studies will identify Interconnection Facilities, Distribution
Upgrades and Reliability Network Upgrades necessary to mitigate thermal overloads and voltage
violations, and address short circuit, dynamic/stability and reliability issues associated with the
requested Interconnection Service. If Distribution Provider anticipates that Reliability Network
Upgrades will be required, or the Interconnection Studies identify the need for Reliability Network
Upgrades, then Distribution Provider will coordinate with the CAISO during the study process as
set forth in Sections F.3.b or F.3.c above.
The estimated costs of short circuit related upgrades and shared interconnection facilities, if any,
identified through a Distribution Group Study shall be assigned as provided in E.4.e.
i) Interconnection System Impact and DGS Phase I Interconnection Study
(1) Scope of the Interconnection System Impact and DGS Phase I Interconnection Study
The Interconnection System Impact Study or DGS Phase I Interconnection Study in the
case of the Distribution Group Study Process may consist of a localized short circuit
analysis, a stability/dynamic analysis, a power flow analysis, and any other studies that
are deemed necessary. The localized short circuit analysis will evaluate impacts to the
Distribution and Transmission System only with any local short circuit-duty related
Reliability Network Upgrades allocated to the Generating Facility or Generating Facilities
that require(s) the upgrades. Short circuit duty impacts to the CAISO Controlled Grid are
appropriately evaluated only in the Transmission Cluster Study Process as set forth in
Section F.3.d. The short circuit duty contribution of any Interconnection Requests
studied in the Independent Study Process or Distribution Group Study Process that are
subsequently identified in the Transmission Cluster Study Process will be allocated their
pro rata share of the short circuit duty-related Reliability Network Upgrades on the basis
of the short circuit duty contribution of each Generating Facility.
The Interconnection System Impact Study or DGS Phase I Interconnection Study in the
case of the Distribution Group Study Process, shall state the assumptions upon which it
is based, state the results of the analyses, and provide the requirement or potential
impediments to providing the requested Interconnection Service, including a preliminary
indication of the cost and length of time that would be necessary to correct any problems
identified in those analyses and implement the Interconnection.
The Interconnection System Impact Study or DGS Phase I Interconnection Study shall
provide a list of Distribution Provider’s Interconnection Facilities, Distribution Upgrades,
and Reliability Network Upgrades that are required as a result of the Interconnection
Request along with a non-binding good faith estimate of cost responsibility and the
amount of construction time required.
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Revised Cal. P.U.C. Sheet No. 28048-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27309-E
RULE 21 Sheet 104
GENERATING FACILITY INTERCONNECTIONS
(Continued)
104C7 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
G. Engineering Review Details (Continued)
3. Detailed Study Screens (Continued)
c. Independent Study Process and Distribution Group Study Process Interconnection Studies
(Continued)
i) Interconnection System Impact and DGS Phase I Interconnection Study (Continued)
(1) Scope of the Interconnection System Impact and DGS Phase I Interconnection Study.
(Continued)
If at any time the Distribution Provider determines that it will not meet the required time
frame for completing the DGS Phase I Interconnection Study due to the large number of
Interconnection Requests in the Distribution Group Study Application window, study
complexity, or unavailability of resources on a reasonable basis to perform the study in
the required time frame, the Distribution Provider shall notify the Interconnection
Customer(s) within the Distribution Group Study as to the schedule status of the DGS
Phase I Interconnection Study and provide an estimated completion date with an
explanation of the reasons why additional time is required.
Upon request, the Distribution Provider shall provide the Applicant(s) all supporting
documentation, work papers and relevant pre-Interconnection Request and post-
Interconnection Request power flow, short circuit and stability databases for the DGS
Phase I Interconnection Study, subject to confidentiality arrangements as outlined in
Section D.7.
ii) Interconnection Facilities Study and DGS Phase II Interconnection Study
(1) Scope and Purpose of the Interconnection Facilities and DGS Phase II
Interconnection Study
The Interconnection Facilities Study or DGS Phase II Interconnection Study in the case
of the Distribution Group Study Process shall specify and estimate the cost of the
equipment, engineering, procurement, and construction work (including overheads)
needed to implement the conclusions of the Interconnection System Impact Study or
DGS Phase I Interconnection Study technical analyses in accordance with Good Utility
Practice to physically and electrically connect the Generating Facility to the Distribution
or Transmission System. The Interconnection Facilities Study or DGS Phase II
Interconnection Study shall also identify (i) the electrical switching configuration of the
connection equipment, including, without limitation: the transformer, switchgear, meters,
and other station equipment; the nature and estimated cost of any Distribution Provider’s
Interconnection Facilities, Distribution Upgrades, and Network Upgrades necessary to
accomplish the interconnection; and an estimate of the time required to complete the
construction and installation of such facilities. The analyses in the Interconnection
System Impact Study (or DGS Phase I Interconnection Study in the case of the
Distribution Group Study Process) will be updated as necessary in the Interconnection
Facilities Study (or DGS Phase II Interconnection Study), to account for withdrawal of
interconnection requests in the interconnection queue.
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Revised Cal. P.U.C. Sheet No. 28095-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28049-E
RULE 21 Sheet 105
GENERATING FACILITY INTERCONNECTIONS
(Continued)
105C8 Issued by Date Filed Sep 13, 2016
Advice Ltr. No. 2956-E Dan Skopec Effective Sep 13, 2016
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements
Section H shall be used for interconnection of non-inverter based technologies.
Section H shall also continue to be used for interconnection of inverter based technologies until
September 8, 2017. Following such date, Section Hh shall apply for interconnection of inverter based
technologies. Until such date, Section Hh, may be used in all or in part, for inverter based technologies
by mutual agreement of the Distribution Provider and the Applicant.
This section is consistent with the requirements of ANSI/IEEE 1547-2003 Standard for Interconnecting
Distributed Resources with Electric Power Systems (IEEE 1547). Exceptions are taken to IEEE 1547
Clauses 4.1.4.2 Distribution Secondary Spot Networks and Clauses 4.1.8.1 or 5.1.3.1, which address
Protection from Electromagnetic Interference. These are being studied for inclusion in a subsequent
version of this Rule. Also, Rule 21 does not adopt the Generating Facility power limitation of 10 MW
incorporated in IEEE 1547.
1. General Interconnection and Protective Function Requirements.
The Protective Functions and requirements of this Rule are designed to protect Distribution
Provider’s Distribution and Transmission System and not the Generating Facility. A Producer shall be
solely responsible for providing adequate protection for its Generating Facility and Interconnection
Facilities. Producer’s Protective Functions shall not impact the operation of other Protective
Functions on Distribution Provider’s Distribution and Transmission System in a manner that would
affect Distribution Provider’s capability of providing reliable service to its customers.
a. Protective Functions Required.
Generating Facilities operating in parallel with Distribution Provider’s Distribution or Transmission
System shall be equipped with the following Protective Functions to sense abnormal conditions
on Distribution Provider’s Distribution or Transmission System and cause the Generating Facility
to be automatically disconnected from Distribution Provider’s Distribution or Transmission
System or to prevent the Generating Facility from being connected to Distribution Provider’s
Distribution or Transmission System inappropriately:
(i) Over and under voltage trip functions and over and under frequency trip functions;
(ii) A voltage and frequency sensing and time-delay function to prevent the Generating Facility
from energizing a de-energized Distribution or Transmission System circuit and to prevent
the Generating Facility from reconnecting with Distribution Provider’s Distribution or
Transmission System unless Distribution Provider’s Distribution System service voltage and
frequency is within the ANSI C84.1-1995 Table 1 Range B voltage Range of 106 volts to 127
volts (on a 120 volt basis), inclusive, and a frequency range of 59.3 Hz to 60.5 Hz, inclusive,
and are stable for at least 60 seconds; and
(iii) A function to prevent the Generating Facility from contributing to the formation of an
Unintended Island, and cease to energize Distribution Provider’s Distribution System within
two seconds of the formation of an Unintended Island.
T, D
Revised Cal. P.U.C. Sheet No. 28050-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27311-E
RULE 21 Sheet 106
GENERATING FACILITY INTERCONNECTIONS
(Continued)
106C6 Issued by Date Filed Aug 22, 2016
Advice Ltr. No. 2945-E Dan Skopec Effective Jun 8, 2017
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
1. General Interconnection and Protective Function Requirements (Continued)
a. Protective Functions Required (Continued)
The Generating Facility shall cease to energize Distribution Provider’s Distribution System for
faults on Distribution Provider’s Distribution System circuit to which it is connected (IEEE 1547-
4.2.1). The Generating Facility shall cease to energize Distribution Provider’s Distribution circuit
prior to re-closure by Distribution Provider’s Distribution System equipment (IEEE 1547-4.2.2).
b. Momentary Paralleling Generating Facilities
With Distribution Provider’s approval, the transfer switch or scheme used to transfer Producer’s
loads from Distribution Provider’s Distribution or Transmission System to Producer’s Generating
Facility may be used in lieu of the Protective Functions required for Parallel Operation.
c. Suitable Equipment Required
Circuit breakers or other interrupting equipment located at the Point of Common Coupling (PCC)
must be Certified or “Listed” (as defined in Article 100, the Definitions Section of the National
Electrical Code) as suitable for their intended application. This includes being capable of
interrupting the maximum available fault current expected at their location. Producer’s
Generating Facility and Interconnection Facilities shall be designed so that the failure of any
single device or component shall not potentially compromise the safety and reliability of
Distribution Provider’s Distribution and Transmission System. The Generating Facility paralleling-
device shall be capable of withstanding 220% of the Interconnection Facility rated voltage (IEEE
1547-4.1.8.3). The Interconnection Facility shall have the capability to withstand voltage and
current surges in accordance with the environments defined in IEEE Std C62.41.2-2002 or IEEE
Std C37.90.1-2002 as applicable and as described in L.3.e (IEEE 1547-4.1.8.2).
d. Visible Disconnect Required
When required by Distribution Provider’s operating practices, Producer shall furnish and install a
ganged, manually-operated isolating switch (or a comparable device mutually agreed upon by
Distribution Provider and Producer) near the Point of Interconnection to isolate the Generating
Facility from Distribution Provider’s Distribution or Transmission System. The device does not
have to be rated for load break nor provide over-current protection.
The device must:
(i) allow visible verification that separation has been accomplished. (This requirement may be
met by opening the enclosure to observe contact separation.)
(ii) include markings or signage that clearly indicates open and closed positions.
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Revised Cal. P.U.C. Sheet No. 27312-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26021-E
RULE 21 Sheet 107
GENERATING FACILITY INTERCONNECTIONS
(Continued)
107C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
1. General Interconnection and Protective Function Requirements (Continued)
d. Visible Disconnect Required (Continued)
(iii) be capable of being reached:
a) for Emergency purposes quickly and conveniently 24 hours a day by Distribution
Provider personnel for construction, operation, maintenance, inspection, testing or to
isolate the Generating Facility from Distribution Provider’s Distribution or Transmission
System without obstacles or requiring those seeking access to obtain keys, special
permission, or security clearances.
b) for Non-Emergency purposes during normal business hours. Distribution Provider, where
possible, will provide notice to Customer for gaining access to Customer’s premises.
(iv) be capable of being locked in the open position.
(v) be clearly marked on the submitted single line diagram and its type and location approved by
Distribution Provider prior to installation. If the device is not adjacent to the PCC, permanent
signage must be installed at a Distribution Provider approved location providing a clear
description of the location of the device. If the switch is not accessible outside the locked
premises, signage with contact information and a Distribution Provider approved locking
device for the premises shall be installed.
Generating Facilities with Non-Islanding inverters totaling one (1) kilovolt-ampere (kVA) or less
are exempt from this requirement.
e. Drawings Required
Prior to Parallel Operation or Momentary Parallel Operation of the Generating Facility,
Distribution Provider shall approve Producer’s Protective Function and control diagrams.
Generating Facilities equipped with Protective Functions and a control scheme previously
approved by Distribution Provider for system-wide application or only Certified Equipment may
satisfy this requirement by reference to previously approved drawings and diagrams.
f. Generating Facility Conditions Not Identified
In the event this Rule does not address the Interconnection conditions for a particular Generating
Facility, Distribution Provider and Producer may agree upon other arrangements.
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Revised Cal. P.U.C. Sheet No. 27313-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26022-E
RULE 21 Sheet 108
GENERATING FACILITY INTERCONNECTIONS
(Continued)
108C10 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference
Producer shall not operate Generating or Interconnection Facilities that superimpose a voltage or
current upon Distribution Provider’s Distribution or Transmission System that interferes with
Distribution Provider operations, service to Distribution Provider Customers, or communication
facilities. If such interference occurs, Producer must diligently pursue and take corrective action at its
own expense after being given notice and reasonable time to do so by Distribution Provider. If
Producer does not take corrective action in a timely manner, or continues to operate the facilities
causing interference without restriction or limit, Distribution Provider may, without liability, disconnect
Producer's facilities from Distribution Provider’s Distribution or Transmission System, in accordance
with Section D.9 of this Rule. To eliminate undesirable interference caused by its operation, each
Generating Facility shall meet the following criteria:
a. Voltage Regulation
The Generating Facility shall not actively regulate the voltage at the PCC while in parallel with
Distribution Provider’s Distribution System. The Generating Facility shall not cause the service
voltage at other customers to go outside the requirements of ANSI C84.1-1995, Range A (IEEE
1547-4.1.1).
b. Voltage Trip Setting
The voltage ranges in Table H.1 define protective trip limits for the Protective Function and are
not intended to define or imply a voltage regulation Function. Generating Facilities shall cease to
energize Distribution Provider’s Distribution System within the prescribed trip time whenever the
voltage at the PCC deviates from the allowable voltage operating range. The Protection Function
shall detect and respond to voltage on all phases to which the Generating Facility is connected.
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Revised Cal. P.U.C. Sheet No. 27314-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26023-E
RULE 21 Sheet 109
GENERATING FACILITY INTERCONNECTIONS
(Continued)
109C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
b. Voltage Trip Setting (Continued)
i) Generating Facilities (30 kVA or less)
Generating Facilities with a Gross Rating of 30 kVA or less shall be capable of operating
within the voltage range normally experienced on Distribution Provider’s Distribution System
from plus to minus 5% of the nominal voltage (e.g. 114 volts to 126 volts, on a 120 volt
base), at the service panel or PCC. The trip settings at the generator terminals may be
selected in a manner that minimizes nuisance tripping between 106 volts and 132 volts on a
120-volt base (88%-110% of nominal voltage) to compensate for voltage drop between the
generator terminals and the PCC. Voltage may be detected at either the PCC or the Point of
Interconnection. However, the voltage range at the PCC, with the generator on-line, shall
stay within +/-5% of nominal.
ii) Generating Facilities (greater than 30 kVA)
Distribution Provider may have specific operating voltage ranges for Generating Facilities
with Gross Ratings greater than 30 kVA, and may require adjustable operating voltage
settings. In the absence of such requirements, the Generating Facility shall be capable of
operating at a range between 88% and 110% of the applicable interconnection voltage.
Voltage shall be detected at either the PCC or the Point of Interconnection, with settings
compensated to account for the voltage at the PCC. However, the voltage range at the
PCC, with the generator on-line, shall stay within +/- 5% of nominal.
iii) Voltage Disturbances
Whenever Distribution Provider’s Distribution System voltage at the PCC varies from and
remains outside normal (Nominally 120 volts) for the predetermined parameters set forth in
Table H-1, the Generating Facility’s Protective Functions shall cause the Generator(s) to
become isolated from Distribution Provider’s Distribution System:
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Revised Cal. P.U.C. Sheet No. 27315-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26024-E
RULE 21 Sheet 110
GENERATING FACILITY INTERCONNECTIONS
(Continued)
110C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
b. Voltage Trip Setting (Continued)
iii) Voltage Disturbances (Continued)
Table H.1: Voltage Trip Settings for Generating Facilities*
Voltage at Point of Common Coupling (the ranges below
are used to trip the generator during abnormal distribution
system conditions)
Maximum Trip Time**
Assuming 120 Volt Base
% of Nominal Voltage
# of Cycles
(Assuming 60 Hz Nominal)
Seconds
Less than 60 volts
Less than 50%
10 cycles 0.16 Seconds
Greater than or equal to
60 volts but less than
106 volts
Greater than or equal to
50% but less than 88%
120 Cycles
2 Seconds
Greater than 132 volts but
less than or equal to 144
volts
Greater than 110% but less
than or equal to 120%
60 Cycles
1 Second
Greater than 144 volts
Greater than 120%
10 Cycles
0.16 Seconds
*For Generating Facilities with a Rating greater than 30 kVA, set points shall be field adjustable and different
voltage set points and trip times from those in Table H.1 may be negotiated with Distribution Provider.
** "Maximum Trip Time" refers to the time between the onset of the abnormal condition and the Generating
Facility ceasing to energize Distribution Provider’s Distribution System. Protective Function equipment and
circuits may remain connected to Distribution Provider’s Distribution System to allow sensing of electrical
conditions for use by the "reconnect" feature. The purpose of the allowed time delay is to allow for a
Generating Facility to minimize tripping during short term system disturbances. Set points shall not be user
adjustable for generating facilities less than 30 kW.
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Revised Cal. P.U.C. Sheet No. 27316-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26025-E
RULE 21 Sheet 111
GENERATING FACILITY INTERCONNECTIONS
(Continued)
111C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
c. Paralleling
The Generating Facility shall parallel with Distribution Provider’s Distribution or Transmission
System without causing a voltage fluctuation at the PCC greater than plus/minus 5% of the
prevailing voltage level of Distribution Provider’s Distribution or Transmission System at the
PCC, and meet the flicker requirements of Section H.2.d. Section L, Certification and Testing
Criteria, provides technology-specific tests for evaluating the paralleling Function. (IEEE 1547-
4.1.3)
d. Flicker
The Generating Facility shall not create objectionable flicker for other customers on Distribution
Provider’s Distribution or Transmission System. To minimize the adverse voltage effects
experienced by other customers (IEEE 1547-4.3.2), flicker at the PCC caused by the Generating
Facility should not exceed the limits defined by the "Maximum Borderline of Irritation Curve"
identified in IEEE 519-1992 (IEEE Recommended Practices and Requirements for Harmonic
Control in Electric Power Systems, IEEE STD 519-1992). This requirement is necessary to
minimize the adverse voltage affects experienced by other Customers on Distribution Provider’s
Distribution or Transmission System. Generators may be connected and brought up to
synchronous speed (as an induction motor) provided these flicker limits are not exceeded.
e. Integration with Distribution Provider’s Distribution System Grounding
The grounding scheme of the Generating Facility shall not cause over-voltages that exceed the
rating of the equipment connected to Distribution Provider’s Distribution System and shall not
disrupt the coordination of the ground fault protection on Distribution Provider’s Distribution
System (IEEE 1547-4.1.2) (See Section G.1.i, line configuration).
f. Frequency
Distribution Provider controls system frequency, and the Generating Facility shall operate in
synchronism with Distribution Provider’s Distribution or Transmission System. Whenever
Distribution Provider’s Distribution or Transmission System frequency at the PCC varies from
and remains outside normal (nominally 60 Hz) by the predetermined amounts set forth in Table
H.2, the Generating Facility’s Protective Functions shall cease to energize Distribution Provider’s
Distribution or Transmission System within the stated maximum trip time.
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Revised Cal. P.U.C. Sheet No. 27317-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26026-E
RULE 21 Sheet 112
GENERATING FACILITY INTERCONNECTIONS
(Continued)
112C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
f. Frequency (Continued)
Table H.2
Frequency Trip Settings
Frequency Range Maximum Trip Time [1]
Generating Facility Rating (Assuming 60Hz Nominal) (Assuming 60 Cycles per Second)
Less or equal to 30kW Less than 59.3 Hz 10 Cycles
Greater than 60.5 Hz 10 Cycles
Greater than 30 kW Less than 57.0 Hz 10 Cycles
Less than an adjustable value Adjustable between 10 and 18,000
between 59.8 Hz and 57 Hz but Cycles. [2, 3]
greater than 57 Hz. [2]
Greater than 60.5 Hz. 10 Cycles
[1] “Maximum Trip time” refers to the time between the onset of the abnormal condition and the
Generating Facility ceasing to energize Distribution Provider’s Distribution or Transmission
System. Protective Function sensing equipment and circuits may remain connected to
Distribution Provider’s Distribution or Transmission System to allow sensing of electrical
conditions for use by the “reconnect” feature. The purpose of the allowed time delay is to allow a
Generating Facility to “ride through” short-term disturbances to avoid nuisance tripping. Set
points shall not be user adjustable (though they may be field adjustable by qualified personnel).
For Generating Facilities with a Gross Rating greater than 30 kVA, set points shall be field
adjustable and different voltage set points and trip times from those in Table H.2 may be
negotiated with Distribution Provider.
[2] Unless otherwise required by Distribution Provider, a trip frequency of 59.3 Hz and a maximum
trip time of 10 cycles shall be used.
[3] When a 10 cycle Maximum trip time is used, a second under frequency trip setting is not
required.
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Revised Cal. P.U.C. Sheet No. 27318-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26027-E
RULE 21 Sheet 113
GENERATING FACILITY INTERCONNECTIONS
(Continued)
113C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
g. Harmonics
When the Generating Facility is serving balanced linear loads, harmonic current injection into
Distribution Provider’s Distribution or Transmission System at the PCC shall not exceed the limits
stated in Table H.3. The harmonic current injections shall be exclusive of any harmonic currents due
to harmonic voltage distortion present in Distribution Provider’s Distribution or Transmission System
without the Generating Facility connected (IEEE 1547-4.3.3.). The harmonic distortion of a
Generating Facility shall be evaluated using the same criteria as for the Host Loads.
Table H.3
Maximum harmonic current distortion in percent of current (I) [1,2]
Individual
harmonic order, h Total demand
(odd harmonics) [3] h<11 11< h<17 17< h<23 23< h<35 35< h distortion
Max Distortion 4.0 2.0 1.5 0.6 0.3 5.0
(%)
[1] IEEE1547-4.3.3
[2] I = the greater of the maximum Host Load current average demand over 15 or 30 minutes
without the GF, or the GF rated current capacity (transformed to the PCC when a transformer
exists between the GF and the PCC).
[3] Even harmonics are limited to 25% of the odd harmonic limits above.
h. Direct Current Injection
Generating Facilities should not inject direct current greater than 0.5% of rated output current
into Distribution Provider’s Distribution or Transmission System.
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Revised Cal. P.U.C. Sheet No. 27319-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26028-E
RULE 21 Sheet 114
GENERATING FACILITY INTERCONNECTIONS
(Continued)
114C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
i. Power Factor
Producer shall provide adequate reactive power compensation on site to maintain the
Generating Facility power factor near unity at rated output or an Distribution Provider specified
power factor within a power factor range from 0.9 leading to 0.9 lagging, based on local system
conditions. While not required, for generators that do not have inherent reactive power control
capability Distribution Provider at its option may offer reactive power support in the form of power
factor correction capacitors on its Distribution or Transmission System, under a Generator
Interconnection Agreement or an Added Facilities or Special Facilities agreement, as described
in Rule 2.H, as applicable.
3. Technology Specific Requirements
a. Technology Specific Requirements
Three-Phase Synchronous Generators: For three phase Generators, the Generating Facility
circuit breakers shall be three-phase devices with electronic or electromechanical control.
Producer shall be responsible for properly synchronizing its Generating Facility with Distribution
Provider’s Distribution or Transmission System by means of either manual or automatic
synchronous equipment. Automatic synchronizing is required for all synchronous Generators that
have a Short Circuit Contribution Ratio (SCCR) exceeding 0.05. Loss of synchronism protection
is not required except as may be necessary to meet Section H.2.d (Flicker) (IEEE1547-4.2.5).
Unless otherwise agreed upon by Producer and Distribution Provider, synchronous Generators
shall automatically regulate power factor, not voltage, while operating in parallel with Distribution
Provider’s Distribution System. A power system stabilization Function is specifically not required
for Generating Facilities under 10 MW Net Rating.
b. Induction Generators
Induction Generators (except self-excited Induction Generators) do not require a synchronizing
Function. Starting or rapid load fluctuations on induction Generators can adversely impact
Distribution Provider’s Distribution or Transmission System voltage. Corrective step-switched
capacitors or other techniques may be necessary and may cause undesirable ferro-resonance.
When these counter measures (e.g. additional capacitors) are installed on Producer's side of the
PCC, Distribution Provider must review these measures. Additional equipment may be required
as determined in a Supplemental Review or an Interconnection Study.
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Revised Cal. P.U.C. Sheet No. 28096-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27320-E
RULE 21 Sheet 115
GENERATING FACILITY INTERCONNECTIONS
(Continued)
115C7 Issued by Date Filed Sep 13, 2016
Advice Ltr. No. 2956-E Dan Skopec Effective Sep 13, 2016
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
H. Generating Facility Design and Operating Requirements (Continued)
3. Technology Specific Requirements (Continued)
c. Inverters
Grid-interactive inverters do not require separate synchronizing equipment. Non grid-interactive
or “stand-alone” inverters shall not be used for Parallel Operation with Distribution Provider’s
Distribution or Transmission System.
d. Limitations on inverters not classified as Smart Inverters
i. Inverter based systems may continue to be installed per Section H until September 8, 2017.
Section Hh, may be used in all or in part, for inverter based technologies by mutual
agreement of the Distribution Provider and the Applicant
ii. Notwithstanding Section H.3.d.i, the replacement of an existing inverter to an inverter that is
of equal or greater ability than the original is allowed per Section H. Section H may be used
in all or in part, for replacement inverter-based technologies by mutual agreement of the
Distribution Provider and the Applicant.
4. Supplemental Generating Facility Requirements
a. Fault Detection
A Generating Facility with an SCCR exceeding 0.1 or one that does not cease to energize
Distribution Provider’s Distribution or Transmission System within two seconds of the formation
of an Unintended Island shall be equipped with Protective Functions designed to detect
Distribution or Transmission System faults, both line-to-line and line-to-ground, and cease to
energize Distribution Provider’s Distribution or Transmission System within two seconds of the
initiation of a fault.
b. Transfer Trip
For a Generating Facility that cannot detect Distribution or Transmission System faults (both line-
to-line and line-to-ground) or the formation of an Unintended Island, and cease to energize
Distribution Provider’s Distribution or Transmission System within two seconds, Distribution
Provider may require a Transfer Trip system or an equivalent Protective Function.
c. Reclose Blocking
Where the aggregate Generating Facility capacity exceeds 15% of the peak load on any
automatic reclosing device, Distribution Provider may require additional Protective Functions,
including, but not limited to recluse-blocking on some of the automatic reclosing devices.
T, D
Revised Cal. P.U.C. Sheet No. 29029-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28399-E
RULE 21 Sheet 116
GENERATING FACILITY INTERCONNECTIONS
(Continued)
116C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements
Section H shall continue to be used for interconnection of inverter based technologies until September 8,
2017. Following such date, Section Hh shall apply for interconnection of inverter based technologies.
Until such date, Section Hh, may be used in all or in part, for inverter based technologies by mutual
agreement of the Distribution Provider and the Applicant.
The inverter requirements are intended to be consistent with UL 1741 – Supplement SA using Section
Hh of Rule 21 as the source requirement document and ANSI/IEEE 1547-2003 and 1547a Standard for
Interconnecting Distributed Resources with Electric Power Systems (IEEE 1547 including amendment
1547a), where possible. In the event of conflict between this Rule and UL 1741 – Supplement SA and/or
IEEE 1547-2003 or IEEE 1547a, this Rule shall take precedence. Exceptions are taken to IEEE 1547
Clauses 4.1.4.2 Distribution Secondary Spot Networks and Clauses 4.1.8.1 or 5.1.3.1, which address
Protection from Electromagnetic Interference. Rule 21 does not adopt the Generating Facility power
limitation of 10 MW incorporated in IEEE 1547.
1. General Interconnection and Protective Function Requirements.
The Protective Functions and requirements of this Rule are designed to protect Distribution
Provider’s Distribution and Transmission System and not the Generating Facility. A Producer shall be
solely responsible for providing adequate protection for its Generating Facility and Interconnection
Facilities. Producer’s Protective Functions shall not impact the operation of other Protective
Functions on Distribution Provider’s Distribution and Transmission System in a manner that would
affect Distribution Provider’s capability of providing reliable service to its customers.
1 “The Standard for Inverters, Converters, and Controllers for Use in Independent Power Systems”
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Revised Cal. P.U.C. Sheet No. 27322-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26031-E
RULE 21 Sheet 117
GENERATING FACILITY INTERCONNECTIONS
(Continued)
117C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
1. General Interconnection and Protective Function Requirements. (Continued)
a. Protective Functions Required
Smart Inverters operating in parallel with Distribution Provider’s Distribution or Transmission
System shall be equipped with the following Protective Functions to sense abnormal conditions
on Distribution Provider’s Distribution or Transmission System and cause the Smart Inverter to
be automatically disconnected from Distribution Provider’s Distribution or Transmission System
or to prevent the Smart Inverter from being connected to Distribution Provider’s Distribution or
Transmission System inappropriately:
(i) Over and under voltage trip functions and over and under frequency trip functions;
(ii) A voltage and frequency sensing and time-delay function to prevent the Smart Inverter from
energizing a de-energized Distribution or Transmission System circuit and to prevent the
Smart Inverter from reconnecting with Distribution Provider’s Distribution or Transmission
System unless Distribution Provider’s Distribution System service voltage and frequency is
within the ANSI C84.1-1995 Table 1 Range B voltage Range of 106 volts to 127 volts (on a
120 volt basis), inclusive, and a frequency range of 58.5 Hz to 60.5 Hz, inclusive, and are
stable for at least 15 seconds; and
(iii) A function to prevent the Smart Inverter from contributing to the formation of an Unintended
Island, and cease to energize Distribution Provider’s Distribution System within two seconds
of the formation of an Unintended Island.
The Smart Inverter shall cease to energize Distribution Provider’s Distribution System for
faults on Distribution Provider’s Distribution System circuit to which it is connected (IEEE
1547-4.2.1). The Smart Inverter shall cease to energize Distribution Provider’s Distribution
circuit prior to re-closure by Distribution Provider’s Distribution System equipment (IEEE
1547-4.2.2).
b. Momentary Paralleling Generating Facilities
With Distribution Provider’s approval, the transfer switch or scheme used to transfer Producer’s
loads from Distribution Provider’s Distribution or Transmission System to Producer’s Generating
Facility may be used in lieu of the Protective Functions required for Parallel Operation.
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Revised Cal. P.U.C. Sheet No. 27323-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26032-E
RULE 21 Sheet 118
GENERATING FACILITY INTERCONNECTIONS
(Continued)
118C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
1. General Interconnection and Protective Function Requirements. (Continued)
c. Suitable Equipment Required
Circuit breakers or other interrupting equipment located at the Point of Common Coupling (PCC)
must be Certified or “Listed” (as defined in Article 100, the Definitions Section of the National
Electrical Code) as suitable for their intended application. This includes being capable of
interrupting the maximum available fault current expected at their location. Producer’s Smart
Inverter and Interconnection Facilities shall be designed so that the failure of any single device or
component shall not potentially compromise the safety and reliability of Distribution Provider’s
Distribution and Transmission System. The Smart Inverter paralleling-device shall be capable of
withstanding 220% of the Interconnection Facility rated voltage (IEEE 1547-4.1.8.3). The
Interconnection Facility shall have the capability to withstand voltage and current surges in
accordance with the environments defined in IEEE Std C62.41.2-2002 or IEEE Std C37.90.1-
2002 as applicable and as described in L.3.e (IEEE 1547-4.1.8.2).
d. Visible Disconnect Required
When required by Distribution Provider’s operating practices, Producer shall furnish and install a
ganged, manually-operated isolating switch (or a comparable device mutually agreed upon by
Distribution Provider and Producer) near the Point of Interconnection to isolate the Smart Inverter
from Distribution Provider’s Distribution or Transmission System. The device does not have to be
rated for load break nor provide over-current protection.
The device must:
(i) allow visible verification that separation has been accomplished. (This requirement may be
met by opening the enclosure to observe contact separation.)
(ii) include markings or signage that clearly indicates open and closed positions.
(iii) be capable of being reached:
a) for Emergency purposes quickly and conveniently 24 hours a day by Distribution
Provider personnel for construction, operation, maintenance, inspection, testing or to
isolate the Smart Inverter from Distribution Provider’s Distribution or Transmission
System without obstacles or requiring those seeking access to obtain keys, special
permission, or security clearances.
b) for Non-Emergency purposes during normal business hours. Distribution Provider, where
possible, will provide notice to Customer for gaining access to Customer’s premises.
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Revised Cal. P.U.C. Sheet No. 27324-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 26033-E
RULE 21 Sheet 119
GENERATING FACILITY INTERCONNECTIONS
(Continued)
119C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
1. General Interconnection and Protective Function Requirements. (Continued)
d. Visible Disconnect Required (Continued)
(iv) be capable of being locked in the open position.
(v) be clearly marked on the submitted single line diagram and its type and location approved by
Distribution Provider prior to installation. If the device is not adjacent to the PCC, permanent
signage must be installed at a Distribution Provider approved location providing a clear
description of the location of the device. If the switch is not accessible outside the locked
premises, signage with contact information and a Distribution Provider approved locking
device for the premises shall be installed.
Generating Facilities with Non-Islanding inverters totaling one (1) kilovolt-ampere (kVA) or less
are exempt from this requirement.
e. Drawings Required
Prior to Parallel Operation or Momentary Parallel Operation of the Smart Inverter, Distribution
Provider shall approve Producer’s Protective Function and control diagrams. Generating
Facilities equipped with Protective Functions and a control scheme previously approved by
Distribution Provider for system-wide application or only Certified Equipment may satisfy this
requirement by reference to previously approved drawings and diagrams.
f. Generating Facility Conditions Not Identified
In the event this Rule does not address the Interconnection conditions for a particular Smart
Inverter, Distribution Provider and Producer may agree upon other arrangements.
2. Prevention of Interference
Producer shall not operate Smart Inverters that superimpose a voltage or current upon Distribution
Provider’s Distribution or Transmission System that interferes with Distribution Provider operations,
service to Distribution Provider Customers, or communication facilities. If such interference occurs,
Producer must diligently pursue and take corrective action at its own expense after being given
notice and reasonable time to do so by Distribution Provider. If Producer does not take corrective
action in a timely manner, or continues to operate the facilities causing interference without restriction
or limit, Distribution Provider may, without liability, disconnect Producer's facilities from Distribution
Provider’s Distribution or Transmission System, in accordance with Section D.9 of this Rule. To
eliminate undesirable interference caused by its operation, each Smart Inverter shall meet the
following criteria:
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Revised Cal. P.U.C. Sheet No. 27325-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 26034-E
RULE 21 Sheet 120
GENERATING FACILITY INTERCONNECTIONS
(Continued)
120C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
a. Voltage Regulation
If approved by the Distribution Provider, the Smart Inverter may actively regulate the voltage at
the PCC while in parallel with Distribution Provider’s Distribution System. The Smart Inverter
shall not cause the service voltage at other customers to go outside the requirements of ANSI
C84.1-1995, Range A (IEEE 1547-4.1.1).
b. Voltage Trip and Ride Through Setting
The voltage ranges in Table Hh-1 define protective trip limits for the Protective Function and are
not intended to define or imply a voltage regulation Function. Generating Facilities shall cease to
energize Distribution Provider’s Distribution System within the prescribed trip time whenever the
voltage at the PCC deviates from the allowable voltage operating range. The Protection Function
shall detect and respond to voltage on all phases to which the Generating Facility is connected.
i) Smart Inverters
Smart Inverters shall be capable of operating within the voltage range normally experienced
on Distribution Provider’s Distribution System from plus to minus 5% of the nominal voltage
(e.g. 114 volts to 126 volts, on a 120 volt base), at the service panel or PCC. The trip
settings at the generator terminals may be selected in a manner that minimizes nuisance
tripping in accordance with Table Hh-1 to compensate for voltage drop between the
generator terminals and the PCC. Voltage may be detected at either the PCC or the Point of
Interconnection. However, the voltage range at the PCC, with the generator on-line, shall
stay within +/-5% of nominal.
ii) Voltage Disturbances
Whenever Distribution Provider’s Distribution System voltage at the PCC varies from and
remains outside Near Nominal voltage for the predetermined parameters set forth in Table
Hh-1, the Smart Inverter’s Protective Functions shall cause the Smart Inverter(s) to become
isolated from Distribution Provider’s Distribution System:
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Revised Cal. P.U.C. Sheet No. 27326-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 26035-E
RULE 21 Sheet 121
GENERATING FACILITY INTERCONNECTIONS
(Continued)
121C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
b. Voltage Trip and Ride Through Setting (Continued)
ii) Voltage Disturbances (Continued)
1. The Smart Inverter shall stay connected to the Distribution Provider’s Transmission
or Distribution System while the grid remains within the “Ride-Through Until” voltage-
time range and must stay connected in the corresponding “Operating Mode.
2. For voltage excursions beyond the Near Nominal (NN) magnitude range and within
the range of the HV1 or LV3 regions, the Smart Inverter shall momentarily cease to
energize within 0.16 seconds.
3. In the HV1 region, the Smart Inverter is permitted to reduce power output as a
function of voltage under mutual agreement between the generating facility operator
and the utility.
4. If the distribution system voltage does not exit the ride-through region and recovers
to normal system voltage, the Smart Inverter shall restore continuous operation
within 2 sec.
5. If the Distribution Provider’s Transmission or Distribution System voltage does not
exit the ride-through region and returns from the LV3 region to the LV2 or LV1
region, the Smart Inverter shall restore available current within 2 sec.
6. Different voltage-time settings could be permitted by the utility.
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Revised Cal. P.U.C. Sheet No. 27327-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 26036-E
RULE 21 Sheet 122
GENERATING FACILITY INTERCONNECTIONS
(Continued)
122C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
b. Voltage Trip and Ride Through Setting (Continued)
ii) Voltage Disturbances (Continued)
Table Hh-1: Voltage Ride-Through Table
Region
Voltage at Point of
Common Coupling
(% Nominal Voltage)
Ride-Through
Until Operating Mode Maximum Trip
Time
High Voltage 2
(HV2) V >120 0.16 sec.
High Voltage 1
(HV1) 110 < V < 120 12 sec. Momentary
Cessation 13 sec.
Near Nominal
(NN) 88 < V < 110 Indefinite Continuous
Operation
Not Applicable
Low Voltage 1
(LV1) 70 < V < 88 20 sec. Mandatory
Operation 21 sec.
Low Voltage 2
(LV2) 50 < V < 70 10 sec. Mandatory
Operation 11 sec.
Low Voltage 3
(LV3) V < 50 1 sec Momentary
Cessation 1.5 sec.
c. Paralleling
The Smart Inverter shall parallel with Distribution Provider’s Distribution or Transmission System
without causing a voltage fluctuation at the PCC greater than plus/minus 5% of the prevailing
voltage level of Distribution Provider’s Distribution or Transmission System at the PCC, and meet
the flicker requirements of Section H.2.d. Section L, Certification and Testing Criteria, provides
technology-specific tests for evaluating the paralleling Function. (IEEE 1547-4.1.3)
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Revised Cal. P.U.C. Sheet No. 27328-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 26037-E
RULE 21 Sheet 123
GENERATING FACILITY INTERCONNECTIONS
(Continued)
123C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
d. Flicker
The Smart Inverter shall not create objectionable flicker for other customers on Distribution
Provider’s Distribution or Transmission System. To minimize the adverse voltage effects
experienced by other customers (IEEE 1547-4.3.2), flicker at the PCC caused by the Generating
Facility should not exceed the limits defined by the "Maximum Borderline of Irritation Curve"
identified in IEEE 519-1992 (IEEE Recommended Practices and Requirements for Harmonic
Control in Electric Power Systems, IEEE STD 519-1992). This requirement is necessary to
minimize the adverse voltage affects experienced by other Customers on Distribution Provider’s
Distribution or Transmission System.
e. Integration with Distribution Provider’s Distribution System Grounding
The grounding scheme of the Smart Inverter shall not cause over-voltages that exceed the
rating of the equipment connected to Distribution Provider’s Distribution System and shall not
disrupt the coordination of the ground fault protection on Distribution Provider’s Distribution
System (IEEE 1547-4.1.2) (See Section G.1.i, line configuration).
f. Frequency
Distribution Provider controls system frequency, and the Smart Inverter shall operate in
synchronism with Distribution Provider’s Distribution or Transmission System. Whenever
Distribution Provider’s Distribution or Transmission System frequency at the PCC varies from
and remains outside normal (nominally 60 Hz) by the predetermined amounts set forth in Table
Hh-2 , the Smart Inverter’s Protective Functions shall cease to energize Distribution Provider’s
Distribution or Transmission System within the stated maximum trip time.
i) Frequency Ride-Through Requirements
Smart Inverter based systems shall remain connected to the Distribution Provider’s
Distribution or Transmission System while the grid is within the frequency-time range
indicated in Table Hh-2, and shall disconnect from the electric grid during a high or low
frequency event that is outside that frequency-time range.
The frequency values are shown in Table Hh-2. These values provide default
interconnection system response to abnormal frequencies. The inverter shall disconnect by
the default clearing times. In the high frequency range between 60.2 Hz and 61.5 Hz, or
some other mutually agreed range, the Smart Inverter is permitted to reduce real power
output until it ceases to export power by 61.5 Hz, or other frequency value mutually agreed
between the generating facility operator and the Distribution Provider. Islands and
microgrids may need different default frequency settings.
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Revised Cal. P.U.C. Sheet No. 27329-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 26038-E
RULE 21 Sheet 124
GENERATING FACILITY INTERCONNECTIONS
(Continued)
124C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
f. Frequency (Continued)
i) Frequency Ride-Through Requirements (Continued)
Table Hh-2: Frequency Ride-Through Table
System
Frequency
Default settings
Minimum Range
of Adjustability
(Hz)
Ride-Through
Until (s)
Ride-Through
Operational
Mode
Trip Time (s)
f > 62 62 - 64 No Ride
Through
Not Applicable 0.16
60.5 < f < 62 60.1 - 62 299 Mandatory
Operation
300
58.5 < f < 60.5 Not Applicable Indefinite Continuous
Operation
Not
Applicable
57.0 < f < 58.5 57 – 59.9 299 Mandatory
Operation
300
f < 57.0 53 - 57 No Ride
Through
Not Applicable 0.16
g. Harmonics
When the Smart Inverter is serving balanced linear loads, harmonic current injection into
Distribution Provider’s Distribution or Transmission System at the PCC shall not exceed the
limits stated in Table Hh-3. The harmonic current injections shall be exclusive of any harmonic
currents due to harmonic voltage distortion present in Distribution Provider’s Distribution or
Transmission System without the Smart Inverter connected (IEEE 1547-4.3.3.). The harmonic
distortion of a Smart Inverter shall be evaluated using the same criteria as for the Host Loads.
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Revised Cal. P.U.C. Sheet No. 29030-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27330-E
RULE 21 Sheet 125
GENERATING FACILITY INTERCONNECTIONS
(Continued)
125C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
g. Harmonics (Continued)
Table Hh-3
Maximum harmonic current distortion in percent of current (I) [1,2]
Individual
harmonic order, h Total demand
(odd harmonics) [3] h<11 11< h<17 17< h<23 23< h<35 35< h distortion
Max Distortion 4.0 2.0 1.5 0.6 0.3 5.0
(%)
[1] IEEE1547-4.3.3
[2] I = the greater of the maximum Host Load current average demand over 15 or 30 minutes without the GF,
or the GF rated current capacity (transformed to the PCC when a transformer exists between the GF and
the PCC).
[3] Even harmonics are limited to 25% of the odd harmonic limits above.
h. Direct Current Injection
Smart Inverter should not inject direct current greater than 0.5% of rated output current into
Distribution Provider’s Distribution or Transmission System.
i. Power Factor
Producer shall provide adequate reactive power compensation on site to maintain the Smart
Inverter power factor near unity at rated output or a Distribution Provider specified power factor
in accordance with the following requirements:
i) Default Power Factor setting: Absorbing reactive power at 0.95 lagging power factor
ii) Aggregate generating facility is greater than 15 kW: : 1.0 +/- 0.15 (0.85 Lagging to 0.85
Leading) down to 20% rated power based on available reactive power
iii) Aggregate generating facility is less than or equal to 15 kW: : 1.0 +/- 0.10 (0.90 Lagging to
0.90 Leading) down to 20% rated power based on available reactive power
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Revised Cal. P.U.C. Sheet No. 29031-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27331-E
RULE 21 Sheet 126
GENERATING FACILITY INTERCONNECTIONS
(Continued)
126C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
j. Dynamic Volt/VAr Operations
The Smart Inverter shall be capable of operating dynamically within a power factor range of
+/- 0.85 PF for larger (>15 kW) systems, down to 20% of rated active power, and +/- 0.9 PF
for smaller systems (≤15 kW), down to 20% of rated active power, based on available
reactive power. This dynamic volt/var capability shall be able to be activated or deactivated
in accordance with Distribution Provider requirements.
The Distribution Provider may permit or require the Smart Inverter systems to operate in
larger power factor ranges, including in 4-quadrant operations for storage systems with the
implementation of additional anti-islanding protection as determined by the utility.
The Smart Inverter shall be capable of providing dynamic reactive power compensation
(dynamic Volt/Var operation) within the following constraints:
i) The Smart Inverter shall be able to consume reactive power in response to an increase in
line voltage, and produce reactive power in response to a decrease in line voltage.
ii) The reactive power provided shall be based on available reactive power, but the maximum
reactive power provided to the system shall be as directed by the Distribution Provider.
Dynamic Volt/Var Operations Default Settings
Table Hh-4 and Figure Hh-1 depict the default setting, which should be applied for all inverter
size. Specific volt/var settings may be required for larger generating facilities (such as 100 kW or
greater) or for specific areas with the Distribution System as determined by the Distribution
Provider.
Default Open Loop Response Time for volt/var operation setting should be five (5) seconds.
Table Hh-4: Voltage and Reactive Default Settings
T
T
D
T
T
N
N
Voltage
Setpoint
Voltage
Value
Reactive
Setpoint
Reactive
Value Operation
V1 92.0% Q1 30% Reactive Power Injection
V2 96.7% Q2 0 Unity Power Factor
V3 103.3% Q3 0 Unity Power Factor
V4 107.0% Q4 30% Reactive Power Absorption
Revised Cal. P.U.C. Sheet No. 29032-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27332-E
RULE 21 Sheet 127
GENERATING FACILITY INTERCONNECTIONS
(Continued)
127C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
j. Dynamic Volt/VAr Operations (Continued)
Dynamic Volt/Var Operations Default Settings (Continued)
Figure Hh-1: Voltage and Reactive Default Settings
k. Ramp Rate Requirements
The Smart Inverter is required to have the following ramp controls for at least the following four
conditions. These functions can be established by multiple control functions or by one general
ramp rate control function. Ramp rates are contingent upon sufficient energy available from the
Smart Inverter.
i) Normal ramp-up rate: For transitions between energy output levels over the normal course
of operation. The default value is 100% of maximum current output per second with a range
of adjustment between 1% to 100%, with specific setting as mutually agreed by the
Distributor Provider and the Producer.
ii) Connect/Reconnect ramp-up rate: Upon starting to inject power into the grid, following a
period of inactivity or a disconnection, the inverter shall be able to control its rate of increase
of power from 1 to 100% maximum current per second. The default value is 2% of maximum
current output per second with specific settings as mutually agreed upon by the Distributor
Provider and the Producer.
l. Recommended Frequency-Watt Settings
The Smart Inverters, which have this optional function available, may enable this function with
the following recommended settings. Smart Inverters with different frequency-watt capabilities
may be enabled with Distribution Provider.
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Revised Cal. P.U.C. Sheet No. 29033-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28400-E
RULE 21 Sheet 128
GENERATING FACILITY INTERCONNECTIONS
(Continued)
128C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
l. Recommended Frequency-Watt Settings (Continued)
i) When system frequency exceeds 60.1Hz, the active power output produced by the
Smart Inverter shall be reduced by 50% of real power nameplate rating per hertz (5% of
real power nameplate rating reduction per 0.1 hertz)
ii) When system frequency moves under 59.9Hz, the active power output produced by the
Smart Inverter shall be increased by 50% of real power nameplate rating per hertz (5%
of real power nameplate rating increase per 0.1 hertz) when inverter is capable of
increasing real power production.
iii) The default dead-band should be +/- 0.1 Hz from 60 hertz (59.9Hz to 60.1Hz). When the
system frequency is in range of 59.9Hz and 60.1Hz, the Smart Inverter is not required to
increase or decrease power as a function of system frequency.
iv) Open loop response time for Frequency-Watt shall be 5 seconds.
Figure Hh-2: Active Power as a Function of System Frequency
m. Voltage-Watt Default Settings
Smart Inverters, which have this optional function available, may enable this function in
accordance with Distribution Provider setting requirements.
n. Default Activation States for Phase 1 Functions
Unless otherwise provided by Distribution Provider, pursuant to Distribution Provider’s
Distribution Generation Interconnection Handbook, the default settings will be as follows:
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Revised Cal. P.U.C. Sheet No. 29034-E*
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28401-E
RULE 21 Sheet 129
GENERATING FACILITY INTERCONNECTIONS
(Continued)
129C10 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
2. Prevention of Interference (Continued)
n. Default Activation States for Phase 1 Functions (Continued)
i) Anti-islanding – activated
ii) Low/High Voltage Ride-Through – activated
iii) Low/High Frequency Ride-Through – activated
iv) Dynamic Volt/Var operations – activated
v) Ramp rates – activated
vi) Fixed power factor – deactivated
vii) Reconnect by “soft-start” methods – activated
viii) Frequency-Watt (Optional) – Implemented when available
ix) Volt/Watt (Optional) – Deactivated. Activated under mutual agreement with Distribution
Provider instruction(s)
These default activation states may be modified by mutual agreement between Distribution
Provider and Producer.
o. The voltage and frequency ride-through requirements of Hh.2.b.(ii) and Hh.2.f.(i) shall not apply
if either: a) the real power across the Point of Common Coupling is continuously maintained at a
value less than 10% of the aggregate rating of the Smart Inverters connected to the Generating
Facility prior to any voltage disturbance, and the Generating Facility disconnects from the
Distribution Provider’s Distribution or Transmission System, along with Generating Facility load,
such that the net change in real power flow from or to the Distribution Provider’s Distribution or
Transmission System is less than 10% of the aggregate Smart Inverter capacity; or b)
Generating Facility load real power demand equal to 90% to 120% of the pre-disturbance
aggregate Smart Inverter real power is shed within 0.1 seconds of Smart Inverter disconnection.
3. Technology Specific Requirements
Grid-interactive inverters do not require separate synchronizing equipment. Non grid-interactive or
“stand-alone” inverters shall not be used for Parallel Operation with Distribution Provider’s
Distribution or Transmission System.
4. Supplemental Smart Inverter Requirements
a. Fault Detection A Smart Inverter with an SCCR exceeding 0.1 or one that does not cease to energize Distribution Provider’s Distribution or Transmission System within two seconds of the formation of an Unintended Island shall be equipped with Protective Functions designed to detect Distribution or Transmission System faults, both line-to-line and line-to-ground, and cease to energize Distribution Provider’s Distribution or Transmission System within two seconds of the initiation of a fault.
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Revised Cal. P.U.C. Sheet No. 29035-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28402-E
RULE 21 Sheet 130
GENERATING FACILITY INTERCONNECTIONS
(Continued)
130C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
4. Supplemental Smart Inverter Requirements (Continued)
b. Transfer Trip
For a Generating Facility that cannot detect Distribution or Transmission System faults (both
line-to-line and line-to-ground) or the formation of an Unintended Island, and cease to energize
Distribution Provider’s Distribution or Transmission System within two seconds, Distribution
Provider may require a Transfer Trip system or an equivalent Protective Function.
c. Reclose Blocking
Where the aggregate Generating Facility capacity exceeds 15% of the peak load on any
automatic reclosing device, Distribution Provider may require additional Protective Functions,
including, but not limited to recluse-blocking on some of the automatic reclosing devices.
5. Communication Requirements
The Communication Protocols included in this section shall become mandatory for Generating
Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted on
or after the later of (a) April 1, 2018 or (b) nine months after the release of the SunSpec Alliance
communication protocol certification test standard or the release of another industry-recognized
communication protocol certification test standard. The communications requirements shall be
between (i) the Distribution Provider and the individual Generating Facility; (ii) the Distribution
Provider and the Generating Facility energy management systems that manage the Generating
Facility within a facility, plant and/or microgrid; or (iii) the Distribution Provider and aggregators, who
manage and operate Generating Facilities at various locations.
a. Generating Facilities utilizing inverter-based technologies must adhere to all of the following
communication protocol requirements:
i. Shall be capable of communications;
ii. Software shall be updateable via communications remotely;
iii. The transport level protocol shall be TCP/IP; and,
iv. The default application-level protocol shall be IEEE 2030.5 (i.e., Smart Energy Profile 2.0
(SEP 2)) as defined in the California IEEE 2030.5 Implementation Guide, but other
application-level protocols may be used by mutual agreement of the parties including IEEE
1815/DNP3 for SCADA real-time monitoring and control and IEC 61850.
b. Additional communication protocol requirements shall also apply to Generating Facilities
utilizing inverter-based technologies as provided in the following documents:
i. Distribution Provider Generation Interconnection Handbook, which shall include:
(a) Details and guidelines for the implementation of communications with Generating
Facilities utilizing inverter-based technologies;
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Revised Cal. P.U.C. Sheet No. 29036-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28403-E
RULE 21 Sheet 131
GENERATING FACILITY INTERCONNECTIONS
(Continued)
131C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
Hh. Smart Inverter Generating Facility Design and Operating Requirements (Continued)
5. Communication Requirements (Continued)
b. (Continued)
i. Distribution Provider Generation Interconnection Handbook, which shall include: (Continue)
(b) Requirements for which application-level protocols are supported and references to an
application-level protocol implementation guide;
(c) Cybersecurity and privacy requirements (these may additionally or alternatively be
included in the application-level protocol implementation guide);
(d) Generic device communications registration management requirements, including how to
register individual Generating Facilities, Generating Facilities with energy management
systems, and Aggregators (these additionally or alternatively may be included in the
application-level protocol implementation guide); and,
(e) Conditions under which communication functions are mandatory.
ii. Application-Level Protocol Implementation Guide, which shall provide:
(a) Detailed communication requirements and implementation guidelines to ensure
consistent interoperability of the Generating Facilities with all California investor-owned
utilities under the Commission’s jurisdiction.
I. Third-Party Installations, Reservation of Unused Facilities, and Refund of Salvage Value
1. Interconnection Facilities and Distribution Upgrades
Except as provided for in the Generator Interconnection Agreement of this Rule, Interconnection
Facilities connected to Distribution Provider’s side of the PCC and Distribution Upgrades shall be
provided, installed, owned, and maintained by Distribution Provider at Producer’s expense.
2. Third-Party Installations
Subject to the approval of Distribution Provider, a Producer may, at its option, employ a qualified
contractor to provide and install Interconnection Facilities or Distribution Upgrades, to be owned and
operated by Distribution Provider, on Distribution Provider’s side of the PCC. Such Interconnection
Facilities and Distribution Upgrades shall be installed in accordance with Distribution Provider's
design and specifications. Upon final inspection and acceptance by Distribution Provider, Producer
shall transfer ownership of such Producer installed Interconnection Facilities or Distribution Upgrades
to Distribution Provider and such facilities shall thereafter be owned and maintained by Distribution
Provider at Producer’s expense. Producer shall pay Distribution Provider's reasonable cost of design,
administration, and monitoring of the installation for such facilities to ensure compliance with
Distribution Provider's requirements. Producer shall also be responsible for all costs, including any
income tax liability, associated with the transfer of Producer installed Interconnection Facilities and
Distribution Upgrades to Distribution Provider.
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Revised Cal. P.U.C. Sheet No. 29037-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28404-E
RULE 21 Sheet 132
GENERATING FACILITY INTERCONNECTIONS
(Continued)
132C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
I. Third-Party Installations, Reservation of Unused Facilities, and Refund of Salvage Value (Continued)
3. Reservation of Unused Facilities
When a Producer wishes to reserve Distribution Provider-owned Interconnection Facilities or
Distribution Upgrades installed and operated as Added Facilities for Producer at Producer’s expense,
but idled by a change in the operation of Producer's Generating Facility or otherwise, Producer may
elect to abandon or reserve such facilities consistent with the terms of its agreement with Distribution
Provider. If Producer elects to reserve idle Interconnection Facilities or Distribution Upgrades,
Distribution Provider shall be entitled to continue to charge Producer for the costs related to the
ongoing operation and maintenance of the Added Facilities.
4. Refund of Salvage Value
When a Producer elects to abandon the Special Facilities or Added Facilities for which it has either
advanced the installed costs or constructed and transferred to Distribution Provider, Producer shall,
at a minimum, receive from Distribution Provider a credit for the net salvage value of the Added
Facilities.
J. Metering, Monitoring and Telemetering
1. General Requirements
All Generating Facilities shall be metered in accordance with this Section J and shall meet all
applicable standards of Distribution Provider contained in Distribution Provider’s applicable tariffs and
published Distribution Provider manuals dealing with Metering specifications.
2. Metering by Non-Distribution Provider Parties
The ownership, installation, operation, reading, and testing of revenue Metering Equipment for
Generating Facilities shall be by Distribution Provider except to the extent that the Commission
authorizes any or all these services be performed by others.
3. Net Generation Output Metering
Generating Facility customers may be required to install Net Generation Output Metering for
evaluation, monitoring, and verification purposes and to determine applicable standby and non-
bypassable charges as defined in Distribution Provider’s tariffs, to satisfy applicable California
Independent System Operator (CAISO) reliability requirements, and for Distribution System planning
and operations.
However, Generating Facility customers do not need to install Net Generation Output Metering where
less intrusive and/or more cost effective options, for Producer/Customer, are available for providing
generator data to Distribution Provider. These Generating Facilities may opt to have Distribution
Provider estimate load data in accordance with Distribution Provider’s applicable tariffs to determine
or meet applicable standby and non-bypassable and other applicable charges and tariff
requirements. However, if a Generating Facility customer objects to Distribution Provider’s estimate
of the Generator(s) output, the customer may elect to install the Net Generation Output Metering, or
have Distribution Provider install Net Generation Output Metering at the customer’s expense.
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Revised Cal. P.U.C. Sheet No. 29038-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28405-E
RULE 21 Sheet 133
GENERATING FACILITY INTERCONNECTIONS
(Continued)
133C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
J. Metering, Monitoring and Telemetering (Continued)
3. Net Generation Output Metering (Continued)
All metering options available to the customer must conform to the requirements set forth in
Distribution Provider’s Rule 22 [Rule 25 for SDG&E]. If Distribution Provider does not receive meter
data in accordance with Rule 22, Distribution Provider shall have the right to install Distribution
Provider-owned Net Generation Output Metering at the customer’s expense. The relevant factors in
determining the need for Net Generation Output Metering are as listed below:
(a) Data requirements in proportion to need for information;
(b) Producer’s election to install equipment that adequately addresses Distribution Provider’s
operational requirements;
(c) Accuracy and type of required Metering consistent with purposes of collecting data;
(d) Cost of Metering relative to the need for and accuracy of the data;
(e) The Generating Facility’s size relative to the cost of the Metering/monitoring;
(f) Other means of obtaining the data (e.g. Generating Facility logs, proxy data, etc.);
(g) Requirements under any Generator Interconnection Agreement with Producer.
The requirements in this Section may not apply to Metering of Generating Facilities operating under
Distribution Provider’s Net Energy Metering tariffs. Nothing in this Section J.3 supersedes Section
D.4, Compliance with Laws, Rules and Tariff Schedules.
Distribution Provider will report to the Commission or designated authority, on a quarterly basis, the
rationale for requiring Net Generation Output Metering equipment in each instance along with the
size and location of the facility.
4. Point of Common Coupling (PCC) Metering
For purposes of assessing Distribution Provider’s charges for retail service, Producer’s PCC
Metering shall be reviewed by Distribution Provider, and if required, replaced to ensure that it will
appropriately measure electric power according to the provisions of the Customer’s electric service
Tariff. Where required, the Customer’s existing meter may be replaced with a bi-directional meter so
that power deliveries to and from Producer’s site can be separately recorded. Alternately, Producer
may, at its sole option and cost, require Distribution Provider to install multi-metering equipment to
separately record power deliveries to Distribution Provider’s Distribution System and retail purchases
from Distribution Provider. Where necessary, such PCC Metering shall be designed to prevent
reverse registration.
Generating Facilities participating in Net Energy Metering under shall have metering provided
pursuant to the terms of the applicable Net Energy Metering tariff schedule.
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Revised Cal. P.U.C. Sheet No. 29039-E
San Diego Gas & Electric Company San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 28406-E
RULE 21 Sheet 134
GENERATING FACILITY INTERCONNECTIONS
(Continued)
134C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
J. Metering, Monitoring and Telemetering (Continued)
5. Telemetering
If the nameplate rating of the Generating Facility is 1 MW or greater, Telemetering equipment at the
Net Generation Output Metering location may be required at Producer's expense. If the Generating
Facility is Interconnected to a portion of Distribution Provider’s Distribution System operating at a
voltage below 10 kV, then Telemetering equipment may be required on Generating Facilities 250 kW
or greater. Distribution Provider shall only require Telemetering to the extent that less intrusive
and/or more cost effective options for providing the necessary data in real time are not available.
Distribution Provider will report to the Commission or designated authority, on a quarterly basis, the
rationale for requiring Telemetering equipment in each instance along with the size and location of
the facility.
6. Location
Where Distribution Provider-owned Metering is located on Producer’s premises, Producer shall
provide, at no expense to Distribution Provider, a suitable location for all such Metering Equipment.
7. Costs of Metering
Producer will bear all costs of the Metering required by this Rule, including the incremental costs of
operating and maintaining the Metering Equipment.
8. Multiple Tariff Metering
The requirements of Section J.3 may not apply where a Generating Facility includes multiple
generators eligible for service under more than one Net Energy Metering (NEM) tariff schedule (e.g.
NEM-1, NEM-2, BG-NEM, NEM-FC), or where a Generating Facility consists of one or more NEM-
eligible generators in combination with one or more non-NEM eligible generators without Non-Export
relays (“Reverse Power Protection”). To ensure proper tariff administration, metering will be required
at the PCC and at each of the NEM eligible generator groups eligible for service under the same
NEM tariff schedule. For combinations of multiple NEM eligible generators under different tariffs,
billing administration and metering requirements will be as specified in the appropriate NEM tariff
schedule.
Where a Generating Facility consists of one or more NEM eligible generator groups in combination
with one or more non-NEM generators, metering of the non-NEM generators is not required, except
as specified in Section J.3.
K. Dispute Resolution Process
In addition to the informal procedures for timeline-related disputes set out in Section F.1.d, the following
procedures will apply for disputes arising from this Rule:
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Revised Cal. P.U.C. Sheet No. 29040-E
San Diego Gas & Electric Company San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27340-E
RULE 21 Sheet 135
GENERATING FACILITY INTERCONNECTIONS
(Continued)
135C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
K. Dispute Resolution Process (Continued)
1. Scope
The Commission shall have initial jurisdiction to interpret, add, delete or modify any provision of this
Rule or of any agreements entered into between Distribution Provider and Applicant or Producer to
implement this tariff (“Implementing Agreements") and to resolve disputes regarding Distribution
Provider’s performance of its obligations under Commission-jurisdictional tariffs, the applicable
agreements, and requirements related to the interconnection of Applicant’s or Producer’s Generating
Facility or Interconnection Facilities pursuant to this Rule.
2. Procedures
Any dispute arising between Distribution Provider and Producer (individually referred to in Section K
as “Party” and collectively “the Parties”) regarding Distribution Provider’s or Producer’s performance
of its obligations under its tariffs, the Implementing Agreements, and requirements related to the
interconnection of Producer’s Facilities pursuant to this Rule shall be resolved according to the
following procedures:
a. The dispute shall be documented in a written notice (“notice”)by the aggrieved Party to the other
Party containing the relevant known facts pertaining to the dispute, the specific dispute and the
relief sought, and express notice by the aggrieved Party that it is invoking the procedures under
this Section. The notice shall be sent to the Party’s email address and physical address set forth
in the Generator Interconnection Agreement or Interconnection Request, if there is no Generator
Interconnection Agreement. A copy of the notice shall also be sent to the Energy Division, Office
of the Director, at the Commission. The receiving Party shall acknowledge the notice within five
(5) Calendar Days of its receipt
Upon the aggrieved Party notifying the other Party of the dispute, each Party must designate a
representative with the authority to make decisions for its respective Party to review the dispute
within seven (7) Calendar Days. In addition, upon receipt of the notice, Distribution Provider shall
provide the aggrieved Party with all relevant regulatory and/or technical details and analysis
regarding any Distribution Provider interconnection requirements under dispute within twenty-
one (21) Calendar Days.
Within forty-five (45) Calendar Days of the date of the notice, the Parties’ authorized
representatives will be required to meet and confer to try to resolve the dispute. Parties are
expected to operate in good faith and use best efforts to resolve the dispute.
b. If a resolution is not reached in forty-five (45) Calendar Days from the date of the notice, either 1)
a Party may request to continue negotiations for an additional forty-five (45) Calendar Days or 2)
the Parties may by mutual agreement make a written request for mediation to the ADR
Coordinator in the Commission’s ALJ Division. The request may be submitted by electronic mail
to adr_program@cpuc.ca.gov. Alternatively, both Parties by mutual agreement may request
mediation from an outside third-party mediator with costs to be shared equally between the
Parties.
c. At any time, either Party may file a formal complaint before the Commission pursuant to
California PUC section 1702 and Article 4 of the Commission’s Rules of Practice and Procedure.
Nothing in this section shall be construed to limit the rights of any Party to exercise rights and
remedies under Commission law.
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Revised Cal. P.U.C. Sheet No. 29041-E
San Diego Gas & Electric Company San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27341-E
RULE 21 Sheet 136
GENERATING FACILITY INTERCONNECTIONS
(Continued)
136C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
K. Dispute Resolution Process (Continued)
3. Performance During Dispute
Pending resolution of any dispute under this Section, the Parties shall proceed diligently with the
performance of their respective obligations under this Rule and the Implementing Agreements,
unless the Implementing Agreements have been terminated. Disputes as to the Interconnection
Request and implementation of this Section shall be subject to resolution pursuant to the procedures
set forth in this Section.
L. Certification and Testing Criteria
1. Introduction
This Section describes the test procedures and requirements for equipment used for the
Interconnection of Generating Facilities to Distribution Provider’s Distribution or Transmission
System. Included are Type Testing, Production Testing, Commissioning Testing, and Periodic
Testing. The procedures listed rely heavily on those described in appropriate Underwriters
Laboratory (UL), Institute of Electrical and Electronic Engineers (IEEE), and International
Electrotechnical Commission (IEC) documents—most notably UL 1741 and IEEE 929 as well as the
testing described in May 1999 New York State Public Service Commission’s Interconnection
Requirements. As noted in Section B, this Rule has been revised to be consistent with ANSI/IEEE
1547-2003 Standard for Interconnecting Distribution Resources with Electric Power Systems.
The tests described here, together with the technical requirements in Section H of this Rule, are
intended to provide assurance that the Generating Facility’s equipment will not adversely affect
Distribution Provider’s Distribution or Transmission System and that a Generating Facility will cease
providing power to Distribution Provider’s Distribution or Transmission System under abnormal
conditions. The tests were developed assuming a low level of Generating Facility penetration or
number of connections to Distribution Provider’s Distribution or Transmission System. At high levels
of Generating Facility for Section H but it is a prerequisite for inverter installed after September 8,
2017 pursuant to Section Hh of this Rule.
Section L also provides criteria for “Certifying” Generators or inverters. Once a Generator or inverter
has been Certified per this Rule, it may be considered suitable for Interconnection with Distribution
Provider’s Distribution or Transmission System. Subject to the exceptions described in Section L,
Distribution Provider will not repeat the design review or require retesting of such Certified
Equipment. It should be noted that the Certification process is intended to facilitate Generating
Facilities Interconnections. Certification is not a prerequisite to interconnect a Generating Facility.
2. Certified and Non-Certified Interconnection Equipment
a. Certified Equipment
Equipment tested and approved (i.e. “Listed”) by an accredited NRTL as having met both the
Type Testing and Production Testing requirements described in this document is considered to
be Certified Equipment for purposes of Interconnection with Distribution Provider’s Distribution or
Transmission System. Certification may apply to either a pre-packaged system or an assembly
of components that address the necessary functions. Type Testing may be done in the
manufacturer’s factory or test laboratory, or in the field. At the discretion of the testing laboratory,
field-certification may apply only to the particular installation tested. In such cases, some or all of
the tests may need to be repeated at other installations.
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Revised Cal. P.U.C. Sheet No. 29042-E
San Diego Gas & Electric Company San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27342-E
RULE 21 Sheet 137
GENERATING FACILITY INTERCONNECTIONS
(Continued)
137C7 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
2. Certified and Non-Certified Interconnection Equipment (Continued)
a. Certified Equipment (Continued)
When equipment is Certified by a NRTL, the NRTL shall provide to the manufacturer, at a
minimum, a Certificate with the following information for each device:
Administrative:
(i) The effective date of Certification or applicable serial number (range or first in series), and/or
other proof that certification is current;
(ii) Equipment model number(s) of the Certified equipment;
(iii) The software version utilized in the equipment, if applicable;
(iv) Test procedures specified (including date or revision number); and
(v) Laboratory accreditation (by whom and to what standard).
Technical (as appropriate):
(i) Device ratings (kW, kV, Volts, amps, etc.);
(ii) Maximum available fault current in amps;
(iii) In-rush Current in amps;
(iv) Trip points, if factory set (trip value and timing);
(v) Trip point and timing ranges for adjustable settings;
(vi) Nominal power factor or range if adjustable;
(vii) If the equipment is Certified as Non-Exporting and the method used (reverse power or
under-power); and
(viii) If the equipment is Certified as Non-Islanding
It is the responsibility of the equipment manufacturer to ensure that Certification information is
made publicly available by the manufacturer, the testing laboratory, or by a third party.
b. Non-Certified Equipment
For non-Certified equipment, some or all of the tests described in this Rule may be required by
Distribution Provider for each Generating and/or Interconnection Facility. The manufacturer or
laboratory acceptable to Distribution Provider may perform these tests. Test results for non-
Certified equipment must be submitted to Distribution Provider for the Supplemental Review.
Approval by Distribution Provider for equipment used in a particular Generating and/or
Interconnection Facility does not guarantee Distribution Provider’s approval for use in other
Generating and/or Interconnection Facilities.
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Revised Cal. P.U.C. Sheet No. 29043-E
San Diego Gas & Electric Company San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27343-E
RULE 21 Sheet 138
GENERATING FACILITY INTERCONNECTIONS
(Continued)
138C9 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued) 3. Type Testing
a. Type Tests and Criteria for Interconnection Equipment Certification Type testing provides a basis for determining that equipment meets the specifications for being
designated as Certified equipment under this Rule. The requirements described in this Section cover only issues related to Interconnection and are not intended to address device safety or other issues. Table L.1 defines the test criteria by Generator or inverter technology. While UL 1741(1) and UL
1741 – Supplement SA were written specifically for inverters, the requirements are readily adaptable to synchronous Generators, induction Generators, as well as single/multi-function controllers and protection relays. Until a universal test standard is developed, Distribution
Provider or NRTL shall adopt the procedures referenced in Table L.1 as appropriate and
necessary for a Generating Facility and/or Interconnection Facilities or associated equipment performance and its control and Protection Functions. These tests shall be performed in the sequence shown in Table L.2.
Table L.1
Type Test and Requirements for Interconnection Equipment Certification
Type Test Referance (1) Inverter
(6)
Smart
Inverter (7)
Synchronous
Generators
Induction
Generators
Utility Interaction UL 1741-39, 40 X X X X
Utility Compatibility (Required testing to
1547 and 1547.1) UL 1741-46 X X X X
DC Isolation IEEE 1541.1(8) – 5.6 X X - -
Dielectric Voltage Withstand IEEE 1547.1(8) – 5.5.3 X X X X
Harmonic Distortion IEEE 1547.1(8) – 5.11 X X X X
DC Injection IEEE 1547.1(8) – 5.6 X X - -
Distribution Provider Voltage Variations IEEE 1547.1 – 5.2 X - X X
Distribution Provider Frequency Variations IEEE 1547.1 – 5.3 X - X X
Abnormal Tests UL 1741 – 47
Loss of Control Circuit UL 1741 – 47.8 X X X X
Short Circuit UL 1741 – 47.3 X X X X
Load Transfer UL 1741 – 47.7 X X X X
Surge Withstand Capability L.3.e X X X X
Anti-Islanding (Traditional) L.3.b (2) - (2) (2)
Non-Export L.3.c (3) (3) (3) (3)
In-rush Current L.3.d - - - (4)
Synchronization L.3.f (5) (5) X (5)
Anti-Islanding (Smart Inverters) UL 1741SA – SA8 - X - -
Low and High Voltage Ride-through UL 1741SA – SA9 - X - -
Low and High Frequency Ride-through UL 1741SA – SA10 - X - -
Normal and Soft-Start Ramp Rate UL 1741SA – SA11 - X - -
Specified Power Factor UL 1741SA – SA12 - X - -
Volt/VAR Mode (Q(V)) UL 1741SA – SA13 - X - -
Frequency-Watt (optional) UL 1741SA – SA14 - X - -
Volt-Watt (optional) UL 1741SA – SA15 - X - -
Markings and Instructions UL 1741SA – SA6, SA16 - X - -
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Revised Cal. P.U.C. Sheet No. 29044-E
San Diego Gas & Electric Company San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27344-E
RULE 21 Sheet 139
GENERATING FACILITY INTERCONNECTIONS
(Continued)
139C9 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
3. Type Testing (Continued)
a. Type Tests and Criteria for Interconnection Equipment Certification (Continued)
Table L.1 - Type Test and Requirements for Interconnection Equipment Certification (Continued)
(1) References are to section numbers in either UL 1741 (Inverters, Converters and Charge Controllers for
Use in Independent Power Systems) or this Rule. References in UL 1741 to “photovoltaics” or “inverter”
may have to be adapted to the other technologies by the testing laboratory to appropriately apply in the
tests to other technologies.
(2) Required only if Non-Islanding designation
(3) Required only if Non-Export designation is desired.
(4) Required for Generators that use Distribution Provider power to motor to speed.
(5) Required for all self-excited induction Generators as well as Inverters that operate as voltage sources
when connected to Distribution Provider’s Distribution or Transmission System.
(6) Inverters compliant with Section H
(7) Inverters compliant with Section Hh
(8) IEEE-1547.1 refers to the 2005 revision
X = Required
- = Not Required
Table L.2 Type Tests Sequence for Interconnection Equipment Certification Test No. Type Test 1 Distribution Provider Voltage and Frequency Variation
2 Synchronization
3 Surge Withstand Capability
4 Distribution Provider Voltage and Frequency Variation, including ride through
5 Synchronization
6 Other Required and Optional Tests Tests 1, 2, and 3 must be done first and in the order shown. Tests 4 and on follow in order
convenient to the test agency.
b. Anti-Islanding Test
Devices that pass the Anti-Islanding test procedure described in UL 1741 Section 46.3 and/or UL
1741 – Supplement SA Section SA8 will be considered Non-Islanding for the purposes of these
Interconnection requirements. The test is required only for devices for which a Certified Non-
Islanding designation is desired.
c. Non-Export Test
Equipment that passes the Non-Export test procedure described in Section L.7.a will be
considered Non-Exporting for the purposes of these Interconnection requirements. This test is
required only for devices for which a Certified Non-Export designation is desired.
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Revised Cal. P.U.C. Sheet No. 29045-E
San Diego Gas & Electric Company San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27345-E
RULE 21 Sheet 140
GENERATING FACILITY INTERCONNECTIONS
(Continued)
140C6 Issued by Date Filed Jun 30, 2017
Advice Ltr. No. 3094-E Dan Skopec Effective Jul 30, 2017
Vice President
Decision No. 14-12-035 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
3. Type Testing (Continued)
d. In-rush Current Test
Generation equipment that utilizes Distribution Provider power to motor up to speed will be
tested using the procedure defined in Section L.7.b to determine the maximum current draw
during this startup process. The resulting In-rush Current is used to estimate the Starting Voltage
Drop.
e. Surge Withstand Capability Test
The interconnection equipment shall be tested for the surge withstand requirement in Section
H.1.c in all normal operating modes in accordance with IEEE Std C62.45-2002 for equipment
rates less than 1000 V to confirm that the surge withstand capability is met by using the selected
test level(s) from IEEE Std C62.41.2-2002. Interconnection equipment rated greater than 1000
V shall be tested in accordance with manufacturer or system integrator designated applicable
standards. For interconnection equipment signal and control circuits, use IEEE Std C37.90.1-
2002. These tests shall confirm the equipment did not fail, did not misoperate, and did not
provide misinformation (IEEE 1547-5.1.3.2).
The location/exposure category for which the equipment has been tested shall be clearly marked
on the equipment label or in the equipment documentation. External surge protection may be
used to protect the equipment in harsher location/exposure categories.
f. Synchronization Test
This test is applied to synchronous Generators, self-excited induction generators, and inverters
capable of operating as voltage-source while connected to Distribution Provider’s Distribution or
Transmission System. The test is also applied to the resynchronization Function (transition from
stand-alone to parallel operation) on equipment that provides such functionality. This test may
not need to be performed on both the synchronization and re-synchronization functions if the
manufacturers can verify to the satisfaction of the testing organization that monitoring and
controls hardware and software are common to both functions. This test is not necessary for
induction generators or current-source inverters. Instead, the ln-rush Current test Section L.3.d
shall be applied to those generators.
This test shall demonstrate that at the moment of the paralleling-device closure, all three
synchronization parameters in Table L.3 are within the stated limits. This test shall also
demonstrate that if any of the parameters are outside of the limits stated in the table, the
paralleling-device shall not close (IEEE 1547-5.1.2A). The test will start with only one of the
three parameters: (1) voltage difference between Generating Facility and Distribution Provider’s
Distribution or Transmission System; (2) frequency difference; or (3) phase angle outside of the
synchronization specification. Verify that the Generating Facility is brought within specification
prior to synchronization. Repeat the test five times for each of the three parameters. For manual
synchronization with synch check or manual control with auto synchronization, the test must
verify that paralleling does not occur until the parameters are brought within specifications.
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Original Cal. P.U.C. Sheet No. 27346-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 141 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
141C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
3. Type Testing (Continued)
f. Synchronization Test (Continued)
Table L.3
Synchronization Parameter Limits [1]
Aggregate Rating Frequency Voltage Difference
of Generator Units Difference Phase Angle Difference
(kVA) (Hz) (V, %)
0-500 0.3 10 20
>500-1,500 0.2 5 15
>1,500-10,000 0.1 3 10
[1] – IEEE 1547-5.1.1B
g. Paralleling Device Withstand Test
The di-electric voltage withstand test specified in Section L.1 shall be performed on the
paralleling device to ensure compliance with those requirements specified in Section H.1.c (IEEE
1547-5.1.3.3).
4. Production Testing
As a minimum, each interconnection system shall be subjected to Distribution Provider Voltage and
Frequency Variation Test procedure described in UL1741 under Manufacturing and Production
Tests, Section 68 and the Synchronization test specified in Section L.3.f. Interconnection systems
with adjustable set points shall be tested at a single set of set points as specified by the
manufacturer. This test may be performed in the factory or as part of a Commissioning Test (Section
L.5).
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Original Cal. P.U.C. Sheet No. 27347-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 142 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
142C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
5. Commissioning Testing (Continued)
a. Commissioning Testing
Commissioning Testing, where required, will be performed on-site to verify protective settings
and functionality. Upon initial Parallel Operation of a Generating Facility, or any time interface
hardware or software is changed that may affect the functions listed below; a Commissioning
Test must be performed. An individual qualified in testing protective equipment (professional
engineer, factory–certified technician, or licensed electrician with experience in testing protective
equipment) must perform Commissioning Testing in accordance with the manufacturer’s
recommended test procedure to verify the settings and requirements per this Rule.
Distribution Provider may require written Commissioning test procedure be submitted to
Distribution Provider at least 10 working days prior to the performance of the Commissioning
Test. Distribution Provider has the right to witness Commissioning Test, Distribution Provider
may also require written certification by the installer describing which tests were performed and
their results. Protective Functions to be tested during commissioning, particularly with respect to
non-Certified equipment, may consist of the following:
(i) Over and under voltage
(ii) Over and under frequency
(iii) Anti-Islanding function (if applicable)
(iv) Non-Exporting function (if applicable)
(v) Inability to energize dead line
(vi) Time delay on restart after Distribution Provider source is stable
(vii) Distribution Provider system fault detection (if used)
(viii)Synchronizing controls (if applicable)
(ix) Other Interconnection Protective Functions that may be required as part of the Generator
Interconnection Agreement
Commissioning Test shall include visual inspections of the interconnection equipment and
protective settings to confirm compliance with the interconnection requirements.
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San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 143 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
143C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
5. Commissioning Testing (Continued)
b. Review, Study, and Additional Commissioning Test Verification Costs
A Producer shall be responsible for the reasonably incurred costs of the reviews, studies and
additional Commissioning Test verifications conducted pursuant to Section E of this Rule. If the
initial Commissioning Test verification is not successful through no fault of Distribution Provider,
Distribution Provider may impose upon Producer a cost based charge for subsequent
Commissioning Test verifications. All Costs for additional Commissioning Test verifications shall
be paid by Producer within thirty days of receipt of Distribution Provider’s invoice. The invoice
provided by Distribution Provider shall consist of the hourly rate multiplied by the hours incurred
by Distribution Provider and will separately specify the amount of time spent on-site from that
spent in roundtrip travel to the Commissioning Test site. Additional cost, if any, will be specified
on the invoice. If the initial Commissioning Test verification is not successful through the fault of
Distribution Provider, that visit will not be considered the initial Commissioning Test verification.
c. Other Checks and Tests
Other checks and tests that may need to be performed include:
(i) Verifying final Protective Function settings
(ii) Trip test (L.5.g)
(iii) In-service tests (L.5.h)
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Original Cal. P.U.C. Sheet No. 27349-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 144 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
144C8 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
5. Commissioning Testing (Continued)
d. Certified Equipment
Generating Facilities qualifying for interconnection through the Fast Track process incorporate
Certified Equipment that have, at a minimum, passed the Type Tests and Production Tests
described in this Rule and are judged to have little or no potential impact on Distribution
Provider’s Distribution or Transmission System. For such Generating Facilities, it is necessary to
perform only the following tests:
(i) Protective Function settings that have been changed after Production Testing will require
field verification. Tests shall be performed using injected secondary frequencies, voltages
and currents, applied waveforms, at a test connection using a Generator to simulate
abnormal Distribution Provider voltage or frequency, or varying the set points to show that
the device trips at the measured (actual) Distribution Provider voltage or frequency.
(ii) The Non-Islanding function shall be checked by operating a load break disconnect switch to
verify the Interconnection equipment ceases to energize Distribution Provider’s Distribution
or Transmission System and does not re-energize it for the required time delay after the
switch is closed.
(iii) The Non-Exporting function shall be checked using secondary injection techniques. This
function may also be tested by adjusting the Generating Facility output and local loads to
verify that the applicable Non-Exporting criteria (i.e., reverse power or under-power) are met.
The Supplemental Review or an Interconnection Study may impose additional components or
additional testing.
e. Non-Certified Equipment
Non-certified Equipment shall be subjected to the appropriate tests described in Type Testing
(Section L.3) as well as those described in Certified Equipment Commissioning Tests (Section
L.5.d). With Distribution Provider’s approval, these tests may be performed in the factory, in the
field as part of commissioning, or a combination of both. Distribution Provider, at its discretion,
may also approve a reduced set of tests for a particular Generating Facility or, for example, if it
determines it has sufficient experience with the equipment.
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Original Cal. P.U.C. Sheet No. 27350-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 145 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
145C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
5. Commissioning Testing (Continued)
f. Verification of Settings
At the completion of Commission testing, Producer shall confirm all devices are set to
Distribution Provider-approved settings. Verification shall be documented in the Commissioning
Test Certification.
g. Trip Tests
Interconnection Protective Functions and devices (e.g. reverse power relays) that have not
previously been tested as part of the Interconnection Facilities with their associated interrupting
devices (e.g. contactor or circuit breaker) shall be trip tested during commissioning. The trip test
shall be adequate to prove that the associated interrupting devices open when the protective
devices operate. Interlocking circuits between Protective Function devices or between
interrupting devices shall be similarly tested unless they are part of a system that has been
tested and approved during manufacturing
h. In-service Tests
Interconnection Protective Functions and devices that have not previously been tested as part of
the Interconnection Facilities with their associated instrument transformers or that are wired in
the field shall be given an in-service test during commissioning. This test will verify proper wiring,
polarity, CT/PT ratios, and proper operation of the measuring circuits. The in-service test shall be
made with the power system energized and carrying a known level of current. A measurement
shall be made of the magnitude and phase angle of each Alternating Current (AC) voltage and
current connected to the protective device and the results compared to expected values. For
protective devices with built-in Metering Functions that report current and voltage magnitudes
and phase angles, or magnitudes of current, voltage, and real and reactive power, the metered
values may be used for in-service testing. Otherwise, portable ammeters, voltmeters, and phase-
angle meters shall be used.
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Original Cal. P.U.C. Sheet No. 27351-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 146 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
146C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
6. Periodic Testing
Periodic Testing of Interconnection-related Protective Functions shall be performed as specified by
the manufacturer, or at least every four years. All Periodic Tests prescribed by the manufacturer
shall be performed. Producer shall maintain Periodic Test reports or a log for inspection by
Distribution Provider. Periodic Testing conforming to Distribution Provider test intervals for the
particular Line Section may be specified by Distribution Provider under special circumstances, such
as high fire hazard areas. Batteries used to activate any Protective Function shall be checked and
logged once per month for proper voltage. Once every four years, the battery must be either
replaced or a discharge test performed.
7. Type Testing Procedures Not Defined in Other Standards
This Section describes the additional Type Tests necessary to qualify a device as Certified under this
Rule. These Type Tests are not contained in Underwriters Laboratories UL 1741 Standard Inverters,
Converters and Controllers for Use in Independent Power Systems, or other referenced standards.
a. Non-Exporting Test Procedures
The Non-Exporting test is intended to verify the operation of relays, controllers and inverters
designed to limit the export of power and certify the equipment as meeting the requirements of
Screen I, Options 1 and 2, of the review process. Tests are provided for discrete relay packages
and for controllers and inverters with the intended Functions integrated.
i) Discrete Reverse Power Relay Test
This version of the Non-Exporting test procedure is intended for discrete reverse power an
under-power relay packages provided to meet the requirements of Options 1 and 2 of
Screen I. It should be understood that in the reverse power application, the relay will provide
a trip output with power flowing in the export (toward Distribution Provider’s Distribution or
Transmission System) direction.
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Original Cal. P.U.C. Sheet No. 27352-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 147 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
147C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
7. Type Testing Procedures Not Defined in Other Standards (Continued)
a. Non-Exporting Test Procedures (Continued)
i) Discrete Reverse Power Relay Test (Continued)
Step 1: Power Flow Test at Minimum, Midpoint and Maximum Pickup Level Settings
Determine the corresponding secondary pickup current for the desired export power flow of
0.5 secondary watts (the minimum pickup setting, assumes 5 amp and 120V CT/PT
secondary). Apply nominal voltage with minimum current setting at zero (0) degrees phase
angle in the trip direction. Increase the current to pickup level. Observe the relay’s (LCD or
computer display) indication of power values. Note the indicated power level at which the
relay trips. The power indication should be within 2% of the expected power. For relays with
adjustable settings, repeat this test at the midpoint, and maximum settings. Repeat at phase
angles of 90, 180 and 270 degrees and verify that the relay does not operate (measured
watts will be zero or negative).
Step 2: Leading Power Factor Test
Apply rated voltage with a minimum pickup current setting (calculated value for system
application) and apply a leading power factor load current in the non-trip direction (current
lagging voltage by 135 degrees). Increase the current to relay rated current and verify that
the relay does not operate. For relays with adjustable settings, this test should be repeated
at the minimum, midpoint, and maximum settings.
Step 3: Minimum Power Factor Test
At nominal voltage and with the minimum pickup (or ranges) determined in Step 1, adjust the
current phase angle to 84 or 276 degrees. Increase the current level to pickup (about 10
times higher than at 0 degrees) and verify that the relay operates. Repeat for phase angles
of 90, 180 and 270 degrees and verify that the relay does not operate.
Step 4: Negative Sequence Voltage Test
Using the pickup settings determined in Step 1, apply rated relay voltage and current at 180
degrees from tripping direction, to simulate normal load conditions (for three-phase relays,
use Ia at 180, Ib at 60 and Ic at 300 degrees). Remove phase-1 voltage and observe that the
relay does not operate. Repeat for phases-2 and 3.
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Original Cal. P.U.C. Sheet No. 27353-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 148 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
148C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
7. Type Testing Procedures Not Defined in Other Standards (Continued)
a. Non-Exporting Test Procedures (Continued)
i) Discrete Reverse Power Relay Test (Continued)
Step 5: Load Current Test
Using the pickup settings determined in Step 1, apply rated voltage and current at 180
degrees from the tripping direction, to simulate normal load conditions (use Ia at 180, Ib at
300 and Ic at 60 degrees). Observe that the relay does not operate.
Step 6: Unbalanced Fault Test
Using the pickup settings determined in Step 1, apply rated voltage and 2 times rated
current, to simulate an unbalanced fault in the non-trip direction (use Va at 0 degrees, Vb
and Vc at 180 degrees, Ia at 180 degrees, Ib at 0 degrees, and Ic at 180 degrees). Observe
that the relay, especially single phase, does operate properly.
Step 7: Time Delay Settings Test
Apply Step 1 settings and set time delay to minimum setting. Adjust the current source to the
appropriate level to determine operating time, and compare against calculated values. Verify
that the timer stops when the relay trips. Repeat at midpoint and maximum delay settings.
Step 8: Dielectric Test
Perform the test described in IEC 414 using 2 kV RMS for 1 minute.
Step 9: Surge Withstand Test
Perform the surge withstand test described in IEEE C37.90.1.1989 or the surge withstand
capability test described in L.3.e.
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Original Cal. P.U.C. Sheet No. 27354-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 149 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
149C10 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
7. Type Testing Procedures Not Defined in Other Standards (Continued)
a. Non-Exporting Test Procedures (Continued)
ii) Discrete Under-power Relay Test
This version of the Non-Exporting test procedure is intended for discrete Under-power relay
packages and meets the requirements of Option 2 of Screen I. A trip output will be provided
when import power (toward Producer’s load) drops below the specified level.
Note: For an under-power relay, pickup is defined as the highest power level at which the
relay indicates that the power is less than the set level.
Step 1: Power Flow Test at Minimum, Midpoint and Maximum Pickup Level Settings
Determine the corresponding secondary pickup current for the desired power flow pickup
level of 5% of peak load minimum pickup setting. Apply rated voltage and current at 0 (zero)
degrees phase angle in the direction of normal load current. Decrease the current to pickup
level. Observe the relay’s (LCD or computer display) indication of power values. Note the
indicated power level at which the relay trips. The power indication should be within 2% of
the expected power. For relays with adjustable settings, repeat the test at the midpoint, and
maximum settings. Repeat at phase angles of 90, 180 and 270 degrees and verify that the
relay operates (measured watts will be zero or negative).
Step 2: Leading Power Factor Test
Using the pickup current setting determined in Step 1, apply rated voltage and rated leading
power factor load current in the normal load direction (current leading voltage by 45
degrees). Decrease the current to 145% of the pickup level determined in Step 1 and verify
that the relay does not operate. For relays with adjustable settings, repeat the test at the
minimum, midpoint, and maximum settings.
Step 3: Minimum Power Factor Test
At nominal voltage and with the minimum pickup (or ranges) determined in Step 1, adjust the
current phase angle to 84 or 276 degrees. Decrease the current level to pickup (about 10%
of the value at 0 degrees) and verify that the relay operates. Repeat for phase angles 90,
180 and 270 degrees and verify that the relay operates for any current less than rated
current.
L
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Original Cal. P.U.C. Sheet No. 27355-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 150 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
150C10 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
7. Type Testing Procedures Not Defined in Other Standards (Continued)
a. Non-Exporting Test Procedures (Continued)
ii) Discrete Under-power Relay Test (Continued)
Step 4: Negative Sequence Voltage Test
Using the pickup settings determined in Step 1, apply rated relay voltage and 25% of rated
current in the normal load direction, to simulate light load conditions. Remove phase 1
voltage and observe that the relay does not operate. Repeat for Phases-2 and 3.
Step 5: Unbalanced Fault Test
Using the pickup settings determined in Step 1, apply rated voltage and two times rated
current, to simulate an unbalanced fault in the normal load direction (use Va at 0 degrees,
Vb and Vc at 180 degrees, Ia at 0 degrees, Ib at 180 degrees, and Ic at 0 degrees). Observe
that the relay (especially single-phase types) operates properly.
Step 6: Time Delay Settings Test
Apply Step 1 settings and set time delay to minimum setting. Adjust the current source to the
appropriate level to determine operating time, and compare against calculated values. Verify
that the timer stops when the relay trips. Repeat at midpoint and maximum delay settings.
Step 7: Dielectric Test
Perform the test described in IEC 414 using 2 kV RMS for 1 minute.
Step 8: Surge Withstand Test
Perform the surge withstand test described in IEEE C37.90.1.1989 or the surge withstand
test described in Section L.3.e.
L
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Original Cal. P.U.C. Sheet No. 27356-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 151 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
151C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
7. Type Testing Procedures Not Defined in Other Standards (Continued)
a. Non-Exporting Test Procedures (Continued)
iii) Tests for Inverters and Controllers with Integrated Functions
Inverters and controllers designed to provide reverse or under-power functions shall be
tested to certify the intended operation of this function. Two methods are acceptable:
Method 1: If the inverter or controller utilizes external current/voltage measurement to
determine the reverse or under-power condition, then the inverter or controller shall be
functionally tested by application of appropriate secondary currents and potentials as
described in the Discrete Reverse Power Relay Test, Section L.7.a.i of this Rule.
Method 2: If external secondary current or voltage signals are not used, then unit-specific
tests must be conducted to verify that power cannot be exported across the PCC for a period
exceeding two seconds. These may be factory tests, if the measurement and control points
are integral to the unit, or they may be performed in the field.
Inverters and controllers designed to provide reverse or under-power functions shall be
tested to certify the intended operation of this function. Two methods are acceptable:
Method 1: If the inverter or controller utilizes external current/voltage measurement to
determine the reverse or under-power condition, then the inverter or controller shall be
functionally tested by application of appropriate secondary currents and potentials as
described in the Discrete Reverse Power Relay Test, Section L.7.a.i of this Rule.
Method 2: If external secondary current or voltage signals are not used, then unit-specific
tests must be conducted to verify that power cannot be exported across the PCC for a period
exceeding two seconds. These may be factory tests, if the measurement and control points
are integral to the unit, or they may be performed in the field.
iv) Tests for Inadvertent Export Inverters Test requirements for certified inverters with integrated
functions for Inadvertent Export shall verify the performance requirements specified in
Section Mm of this Rule.
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Original Cal. P.U.C. Sheet No. 27357-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 152 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
152C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
L. Certification and Testing Criteria (Continued)
7. Type Testing Procedures Not Defined in Other Standards (Continued)
b. In-rush Current Test Procedures
This test will determine the maximum In-rush Current drawn by the Generator.
(i) Locked-Rotor Method
Use the test procedure defined in NEMA MG-1 (manufacturer’s data is acceptable if
available).
(ii) Start-up Method
Install and setup the Generating Facility equipment as specified by the manufacturer. Using
a calibrated oscilloscope or data acquisition equipment with appropriate speed and
accuracy, measure the current draw at the Point of Interconnection as the Generating
Facility starts up and parallels with Distribution Provider’s Distribution or Transmission
System. Startup shall follow the normal, manufacturer-specified procedure. Sufficient time
and current resolution and accuracy shall be used to capture the maximum current draw
within 5%. In-rush Current is defined as the maximum current draw from Distribution
Provider during the startup process, using a 10-cycle moving average. During the test,
Distribution Provider source, real or simulated, must be capable of maintaining voltage within
+/- 5% of rated at the connection to the unit under test. Repeat this test five times. Report
the highest 10-cycle current as the In-rush Current. A graphical representation of the time-
current characteristic along with the certified In-rush Current must be included in the test
report and made available to Distribution Provider.
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Revised Cal. P.U.C. Sheet No. 28111-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27358-E
RULE 21 Sheet 153
GENERATING FACILITY INTERCONNECTIONS
(Continued)
153C7 Issued by Date Filed Sep 21, 2016
Advice Ltr. No. 2959-E Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
M. Inadvertent Export
Under certain operating conditions, an Applicant may choose to completely offset their facility load by
installing generation systems which are optimally sized to meet their peak demand with load following
functionality on the Generator controls to ensure conditional export of electrical power from the
Generating Facility to Distribution Provider’s Distribution or Transmission System. In situations where the
loading changes rapidly and/or the Generator cannot ramp down quickly enough, the Generating Facility
may need to export small amounts of power for limited duration. The event of exporting uncompensated
power for a short time is referred to as Inadvertent Export.
The following are the minimum requirements for Inadvertent Export systems. Other factors relevant to
the interconnection study process (e.g. 15% screen results, short circuit current ratio, etc.) may
necessitate additional technical requirements (e.g. reclose block, transfer trip, ground bank, etc.) that are
not explicitly noted here. This option may not be available for interconnections to Networked Secondary
Systems.
1) For Inadvertent Export Interconnection Requests, additional Protective Functions and equipment to
detect Distribution or Transmission System faults (per Distribution Providers standard practices) may
be required over and above the basic Protective Functions and equipment associated with the four
options in the Export Screen. Protective Functions may include, but are not limited to, directional
over-current/voltage-restraint over-current Protective Functions for line-to-line fault detection and
over-current/overvoltage Protective Functions for line-to-ground detection. The addition of a ground
bank or ground detector may also be necessary.
2) The effect on equipment ratings can be mitigated by limiting the amount of inadvertent export
allowed. To a large degree, Voltage Regulation may be similarly handled. The amount of Inadvertent
Export is dependent on specific Distribution Provider requirements and should be limited to the
lesser of the following values:
a. 50% of the Generating Facility Capacity, or
b. 10% of the continuous conductor rating in watts at 0.9 power factor for the lowest rated feeder
conductor upstream of the GF (i.e. 200kW @ 12kV), or
c. 110% of the largest load block in the facility, or
d. 500kW or some other maximum level indicated by Distribution Provider
To govern this quantity, a reverse power Protective Function will be provided to trip the connected
Generator(s) within two seconds if the proposed amount of Inadvertent Export is exceeded.
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Original Cal. P.U.C. Sheet No. 27359-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 154 N
GENERATING FACILITY INTERCONNECTIONS N
(Continued)
154C9 Issued by Date Filed Feb 29, 2016
Advice Ltr. No. 2860-E Dan Skopec Effective Jul 5, 2016
Vice President
Decision No. D.16-01-044 Regulatory Affairs Resolution No.
M. Inadvertent Export (Continued)
3. Similarly, to ensure limited impact to the Distribution or Transmission System, the expected
frequency of Inadvertent Export occurrences should be less than two occurrences per 24-hour
period. Additionally, a separate reverse power or under-power Protective Function will be required
(in addition to the reverse power Protective Function described in 2) above) to trip the connected
Generator(s) if the duration of reverse power or under-power (i.e. ANY export) exceeds 60
seconds.
Mm. Inadvertent Export Utilizing Ul-1741 Or Ul-1741 Sa-Listed Grid Support (Non Islanding) Inverters
The following are the minimum requirements for Inadvertent Export systems that meet the criteria
specified below. Other factors relevant to the interconnection study process (e.g., 15% screen results,
short circuit current ratio, etc.) may necessitate additional technical requirements (e.g., reclose block,
transfer trip, ground break, etc.) that are not explicitly noted here. This option may not be available for
interconnections to Networked Secondary Systems.
The certified control functions internal to the inverter control or external control systems may be used
to replace the discrete reverse/under power relay functions described in Section M provided the
requirements outlined below are met.
1. All of the following requirements must be met by the Generating Facility to be eligible for
Inadvertent Export under this Section.
a. The Generating Facility must utilize only UL-1741 certified or UL-1741 SA-listed grid support
non-islanding inverters; and,
b. The Generating Facility must have an aggregate maximum nameplate capacity of 500 kVA or
less; and,
c. The Generating Facility’s total energy export must not exceed its nameplate rating (kVA-gross)
multiplied by 0.1 hours per day over a rolling 30-day period (e.g., for a 100 kVA-gross
nameplate Generating Facility, the maximum energy allowed to be exported for a 30-day
period is 300 kWh); and,
d. Export from the Generating Facility across the PCC to the Distribution System is less than 100
kVA.
2. To govern the level of Inadvertent Export allowable under this Section, the Generating Facility
must utilize a NRTL-certified control system or NRTL-certified inverter system that meets all of the
following requirements.
a. Must result in the Generating Facility disconnecting from the Distribution System, ceasing to
energize the Distribution System or halting energy production within two (2) seconds after
either:
i. The period of continuous export exceeds 30 seconds; or,
ii. The level of export exceeds 100 kVA.
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Revised Cal. P.U.C. Sheet No. 28112-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27360-E
RULE 21 Sheet 155
GENERATING FACILITY INTERCONNECTIONS
(Continued)
155C8 Issued by Date Filed Sep 21, 2016
Advice Ltr. No. 2959-E Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
Mm. Inadvertent Export Utilizing Ul-1741 Or Ul-1741 Sa-Listed Grid Support (Non Islanding) Inverters
(Continued)
2. (Continued)
b. Must monitor that the total energy export is maintained within the allowable energy export
outlined above in 1.c and provide an indication or notification (e.g., electronic notification,
alarm, etc.) if that energy export limit is exceeded.
c. Failure of the control or inverter system for more than thirty (30) seconds, resulting from loss of
control signal, loss of control power or a single component failure or related control sensing of
the control circuitry, must result in the Generating Facility entering Non-Export operation
whereby no energy is exported across the PCC to the Distribution System.
Interim approval of the control or inverter system may be permitted upon mutual agreement of SDG&E
and the Producer.
3. Applicability of Engineering Review Screens.
Inadvertent Export systems that meet the requirements described herein are processed under
Initial Review Screens A through J as described in Section H. If these systems fail Screen J, they
then bypass Screens K and L and are processed under Screens M and M1 as described below.
Screen M: Is the aggregate Generating Facility capacity on the Line Section less than 15% of Line
Section peak load for all line sections bound by automatic sectionalizing devices?
• If Yes (pass), Initial Review is complete.
• If No (fail), continue to Screen M1.
Screen M1: Is the aggregate of all distributed energy resources (DER) causing reverse power flow
(1) at a line section with a voltage regulator device(s) or (2) at a protection device, including the
circuit breaker / field recloser?*,**
• If No (pass), existing DER does not cause reverse power flow at (1) or (2) and Initial Review is complete.
• If Yes (fail), existing DER causes reverse power flow at (1) or (2); fail Initial Review and Supplemental Review is required.
*For the purposes of applying Screen M1 herein, Distribution Provider shall utilize a zero coincidence factor
when considering the impact of other Inadvertent Export systems that meet the requirements of Section Mm
(i.e., projects that qualify for Option 6 under Section G.1.i) such that those Inadvertent Export systems do not
impact Screen M1’s aggregate analysis determination for the individual Inadvertent Export project being
evaluated.
**The presence of existing non-certified DER on the line section may require additional review to ensure safe
and reliable grid operation.
N, L
N, L
Revised Cal. P.U.C. Sheet No. 28804-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27361-E
RULE 21 Sheet 156
GENERATING FACILITY INTERCONNECTIONS
(Continued)
156C7 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
Mm. Inadvertent Export Utilizing Ul-1741 Or Ul-1741 Sa-Listed Grid Support (Non Islanding) Inverters
(Continued)
3. Applicability of Engineering Review Screens. (Continued)
N, L
N, L
Revised Cal. P.U.C. Sheet No. 28805-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27362-E
RULE 21 Sheet 157
GENERATING FACILITY INTERCONNECTIONS
(Continued)
157C7 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
N. Expedited Interconnection Process for Non-Export Battery Storage Generating Facilities
Upon implementation by Distribution Provider,1 Applicants with Interconnection Requests for Non-
Export Energy Storage Generating Facilities who meet the requirements outlined below are eligible for
expedited interconnection, as provided herein, in accordance with the Fast Track Process technical
review requirements of Section F.2.
1. Eligibility Requirements.
Applicants seeking to interconnect a Generating Facility under the provisions of this Section N
must meet the following eligibility requirements.
a. Applicant must submit a completed Interconnection Request in which the expedited
interconnection option is selected, including completing all application fields and submitting all
supporting documentation necessary to facilitate the expedited review as required by
Distribution Provider. Such documentation may include, but is not limited to, single line
diagrams with specific details, manufacturer data sheets for proposed equipment, description
of control systems, validation of the right to do business in the state, etc. Distribution Provider
shall clearly communicate these requirements as part of the application process.
b. Applicant’s Generating Facility must meet the requirements outlined in Section N.2 below.
c. Applicant’s Interconnection Request must be eligible for and select the Fast Track Process.
d. Applicant’s Interconnection Request must pass Fast Track Initial Review and not require any
Interconnection Facilities, Distribution Upgrades or Network Upgrades to remain eligible under
this Section. As such, Interconnection Requests that select the Cost Envelope Option are not
eligible.
2. Generating Facility Eligibility Criteria.
An Applicant’s Generating Facility must meet and adhere to the following criteria.
a. The Generating Facility must be comprised solely of the following specific categories of
generation technology: Non-Exporting inverter-based energy storage.
b. The Generating Facility must have an aggregate maximum inverter nameplate rating of no
greater than 500 kW. There is no limitation on an energy storage device’s kWh capacity
rating.
1 Implementation is targeted by the end of Q3 2017. In accordance with Advice Letter 2987-E, the provisions
provided for herein are being implemented under a pilot-like approach with a October 1, 2017 through
September 30, 2018 reporting period. As such, the provisions may be continued, modified and/or withdrawn
as determined by the Commission.
N, L
N, L
Original Cal. P.U.C. Sheet No. 28806-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 158
GENERATING FACILITY INTERCONNECTIONS
(Continued)
158C7 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
N. Expedited Interconnection Process for Non-Export Battery Storage Generating Facilities (Continued)
2. Generating Facility Eligibility Criteria. (Continued)
c. The Generating Facility must be located behind an existing single retail meter and Point of
Common Coupling with a single, clearly marked and accessible disconnect.2 No other
Generators, other than isolated back-up Generators, may be at the same Point of
Interconnection or Point of Common Coupling.
d. The Generating Facility must utilize Option 3 or Option 4 to meet the non-export protection
requirements of Screen I in Section G.1.i.
e. The Generating Facility must have a single or coordinated control system for all charging
functions if utilizing multiple inverters. The control system must also ensure that there is no
increase in the Interconnection Customer’s existing peak load demand.
f. The Generating Facility must be inverter-based and utilize only UL 1741 and UL 1741 SA-
listed equipment. Additionally, all installed equipment must meet Distribution Provider’s
current electric service requirements with no violations or variances.
3. Expedited Processing Provisions.
a. Applicants with Interconnection Requests that meet the requirements specified in Sections
N.1 and N.2 above shall be issued a draft Generator Interconnection Agreement within 30
Business Days of Distribution Provider providing written notice that the Interconnection
Request is deemed complete and valid, pursuant to the requirements of Sections E.5.a and
E.5.b, and of Distribution Provider’s receipt of all applicable fees.3 In accordance with
Section D.16, if Distribution Provider is unable to meet this timeline, Distribution Provider
shall notify Applicant.
b. For otherwise eligible Interconnection Requests that require additional information from
Applicant as identified by Distribution Provider during the Fast Track Initial Review,
Distribution Provider shall request such additional information from Applicant. When such a
request is made by Distribution Provider, additional time shall be added to the 30 Business
Days applicable under Section N.3.a above on a Business Day-for-Business Day basis (but
not less than 1 Business Day) from the date Distribution Provider issues the request to the
date the Applicant provides the necessary information.
c. Any Interconnection Request that fails to meet the requirements specified in Section N is no
longer eligible for processing under the provisions of this Section N. Such Interconnection
Requests shall continue to be processed in accordance with the applicable provisions and
timelines of Rule 21, unless the Applicant chooses to withdraw the Interconnection Request. 2 For Generating Facilities interconnecting at 120/240V service, Distribution Provider may utilize the meter to
satisfy the disconnect requirement if the Interconnection Customer’s panel is equipped with a main breaker. 3 To facilitate this process, Distribution Provider may provide Applicant with a preliminary Generator
Interconnection Agreement that uses information from Applicant’s Interconnection Request. Applicant shall
communicate any requested changes to the Generator Interconnection Agreement to Distribution Provider
prior to the issuance of the draft Generator Interconnection Agreement.
N, L
N, L
Revised Cal. P.U.C. Sheet No. 28807-E
San Diego Gas & Electric Company
San Diego, California Canceling Original Cal. P.U.C. Sheet No. 27363-E
RULE 21 Sheet 159 T
GENERATING FACILITY INTERCONNECTIONS
(Continued)
159C11 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
Appendix A
Forms Associated with Rule 21 – Generating Facility Interconnections
Form
Number Title Associated
Tariffs Use Guidance
Pre-Application Request
142-05204 Rule 21 Pre-Application Report Request Rule 21
For Generator Developer to
request basic information
about local distribution
circuit.
Study Agreement
142-02772 Rule 21 Detailed Study Agreement Rule 21
Independent Study and
Distribution Group Study
Process Study Agreement
NEM and Non-Export Interconnection Forms
117-2160
Generating Facility Interconnection
Agreement
(NEM /Non- NEM Generating Facility
Export)
NEM,
Rule 21 Used with Form 142-05203
117-2160-A
Federal - Generating Facility
Interconnection Agreement
(NEM /Non-NEM Generating Facility
Export)
NEM,
Rule 21 Used with Form 142-05203
142-02760
Interconnection Agreement for Net
Energy Metering Renewable Electric
Generating Facilities
NEM,
Rule 21 Used with Form 142-05203
142-02760-A
Interconnection Agreement for Net
Energy Metering Renewable Electric
Generating Facilities (Federal
Government Only)
NEM,
Rule 21 Used with Form 142-05203
142-2760.5 Interconnection Agreement for Virtual Net
Energy Metering
VNM-A,
NEM-V,
Rule 21
Used with Forms 142-
05203; 142-02763
142-02762
Fuel Cell Electrical Generating Facility
Net Energy Metering and Interconnection
Agreement
NEM-FC,
Rule 21
Used with Forms 142-
05203 and 142-0761 or
117-2160 142-02763
142-02765
Application and Interconnection
Agreement for Customers with Solar
and/or Wind Electric Generating Facilities
of 30 Kilowatts or Less
NEM,
Rule 21
142-02766
Application for Interconnection for
Customers with Solar and/or Wind ONLY
Electric Generating Facilities Greater than
30 Kilowatts up to 1000 Kilowatts
NEM,
Rule 21
Used with Forms 142-
02760 or 142-02760.5
Revised Cal. P.U.C. Sheet No. 28808-E
San Diego Gas & Electric Company
San Diego, California Canceling Revised Cal. P.U.C. Sheet No. 27743-E*
RULE 21 Sheet 160 T
GENERATING FACILITY INTERCONNECTIONS
(Continued)
160C10 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
Appendix A
Forms Associated with Rule 21 – Generating Facility Interconnections
Form
Number Title Associated
Tariffs Use Guidance
NEM and Non-Export Interconnection Forms (Continued)
142-05202 Generating Facility Interconnection Rule 21 Used with Form 142-05203
142-05203 Generating Facility Interconnection
Application
NEM,
Rule 21
142-0541 Customer Generation Rule 21 Used with Form 142-0542 or
142-0543
142-0542 Generating Facility Interconnection
Agreement (3rd Party Inadvertent-Exporting) Rule 21 Used with Forms 142-05203
and 142-0541
142-0543 Generating Facility Interconnection
Agreement (3rd Party Non-Exporting) Rule 21 Used with Forms 142-05203
and 142-0541
142-0544 Generating Facility Interconnection
Agreement (Inadvertent-Export) Rule 21 Used with Form 142-05203
142-0546
Local Government - Generation Bill Credit
Transfer Allocation Request Form (RES-
BCT)
RES-BCT Used with Forms 142-05203
and 142-0545
Other NEM Forms
142-02763 NEM/VNM-A Inspection Report
NEM,
VNM-A,
NEM-V
For an existing facility that
enters into a new NEM
contract unless the facility
has been installed or
inspected within the previous
three years. Used with Form
142-02760
142-2768 Solar Generation Credit Allocation Request
Form
VNM-A
Credits applied to qualified
customers
142-2770 Generation Credit Allocation Request Form NEM-V Credits applied to qualified
customers
182-1000 Renewable Energy Credits Compensation
NEM,
VNM-A,
NEM-V
Request for REC
compensation for providing
“net surplus electricity”
Original Cal. P.U.C. Sheet No. 28809-E
San Diego Gas & Electric Company
San Diego, California Canceling Cal. P.U.C. Sheet No.
RULE 21 Sheet 161 T
GENERATING FACILITY INTERCONNECTIONS
161C9 Issued by Date Filed Feb 24, 2017
Advice Ltr. No. 2959-E-A Dan Skopec Effective Oct 21, 2016
Vice President
Decision No. 16-06-052 Regulatory Affairs Resolution No.
Appendix B
Unit Cost Guide
Distribution Provider shall publish a Unit Cost Guide for facilities generally required to interconnect
generation in Distribution Provider’s Distribution System. The Unit Cost Guide shall not be binding for actual
facility costs and is provided only for additional cost transparency, developer reference, and Distribution
Provider’s reference when preparing the cost estimate provided in any applicable studies. The Unit Cost
Guide shall not replace the estimated cost provided by Distribution Provider in an Interconnection Study or
an initial or supplemental review under the Fast Track Process.
The Unit Cost Guide shall include the anticipated cost of procuring and installing Interconnection Facilities
and Distribution Upgrades generally utilized by the Applicant. An annual adjustment shall be performed
within the Unit Cost Guide for five (5) years to account for the anticipated timing of procurement to
accommodate a potential range of Commercial Operation Dates.
The Unit Cost Guide shall be updated annually in accordance with the process set forth in D.16-06-052.
Appendix A
Forms Associated with Rule 21 – Generating Facility Interconnections
Form
Number Title Associated
Tariffs Use Guidance
Export for Sale Interconnection Forms
142-05200
Generator Interconnection Agreement for
Exporting Generating Facilities
Interconnection Under the Fast Track Process
Rule 21 Used with Form 142-05201
142-05201 Rule 21 Exporting Generator Interconnection
Request Rule 21 Fast Track
142-0545 Generating Facility Interconnection Agreement
(Continuous Export) Rule 21 Used with Form 142-05203
142-02771
Rule 21 Generator Interconnection Agreement
(GIA) For Exporting Generating Facilities
Interconnecting Under The Detailed Study
Process
Rule 21
Interconnection Agreement to
be used for Interconnecting
Under The Independent
Study, Distribution Group
Study, or Transmission
Cluster Study Process
Renewable Energy
Generation Credit Transfer
Shoshana Aguilar, Senior Management Analyst
Carlsbad Municipal Water District
January 11, 2022
(_carlsbad
Municipal Water District
RECOMMENDED ACTION
Adopt a resolution authorizing the Executive Manager
or designee to execute agreements with the Clean
Energy Alliance, San Diego Gas & Electric, Western
Renewable Energy Generation Information System and
the California Energy Commission in order to transfer
renewable energy generation credits produced by the
Carlsbad Municipal Water District to the Clean Energy
Alliance.
ITEM 8: RENEWABLE ENERGY CREDITS
(_carlsbad
Municipal Water District
BACKGROUND
•The CMWD has been operating a
hydroelectric turbine generator at the
Maerkle Reservoir site since 2015
•This generator uses potable water moving
through a conduit to produce clean,
renewable energy, which SDG&E credited
back to the CMWD to offset electrical
demands at other CMWD sites
ITEM 8: RENEWABLE ENERGY CREDITS
(_carlsbad
Municipal Water District
DISCUSSION
•On April 13, 2021, the City Council and the CMWD
Board of Directors voted to purchase electric
service from the Clean Energy Alliance
•The accompanying Resolution No. 1650 and the
CMWD ordinances do not expressly authorize the
Executive Manager to execute the agreements
necessary to transition the renewable energy
credits
ITEM 8: RENEWABLE ENERGY CREDITS
l._Carlsbad
Municipal Water District
NEXT STEPS
•Staff will execute the agreements to
transfer from the SDG&E’s energy credit
transfer program to the CEA’s energy credit
transfer program to continue to receive
credits for clean energy produced by the
CMWD’s hydroelectric generator.
ITEM 8: RENEWABLE ENERGY CREDITS
(_carlsbad
Municipal Water District
RECOMMENDED ACTION
Adopt a resolution authorizing the Executive Manager
or designee to execute agreements with the Clean
Energy Alliance, San Diego Gas & Electric, Western
Renewable Energy Generation Information System and
the California Energy Commission in order to transfer
renewable energy generation credits produced by the
Carlsbad Municipal Water District to the Clean Energy
Alliance
ITEM 8: RENEWABLE ENERGY CREDITS
l._Carlsbad
Municipal Water District
THANK YOU
(.__carlsbad
Municipal Water District
OPTIONS
1.Authorize the Executive Manager or designee to execute
agreements with the CEA, SDG&E, Western Renewable
Energy Generation Information System and the
California Energy Commission to transition the CMWD
hydroelectric turbine generator at the Maerkle
Reservoir from SDG&E’s renewable energy program to
the CEA
2.Do not authorize the Executive Manager or designee to
execute agreements to transition the CMWD
hydroelectric turbine generator at the Maerkle
Reservoir from SDG&E’s renewable energy program to
the CEA
ITEM 8: RENEWABLE ENERGY CREDITS
l._Carlsbad
Municipal Water District