Details for: 3810-E (Part 1 of 1).pdf


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Gary A. Stern, Ph.D.
Managing Director, State Regulatory Operations

May 29, 2018
ADVICE 3810-E
(U 338-E)
PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA
ENERGY DIVISION
Modifications to Electric Tariff Rule 21 to Incorporate Smart
Inverter Phase 3 Advanced Functions in Compliance with
Resolution E-4898

SUBJECT:

In compliance with California Public Utilities Commission (CPUC or Commission)
Resolution E-4898, Southern California Edison Company (SCE) hereby submits the
following changes to its tariffs. The revised tariff sheets are listed on Attachment A and
are attached hereto.
PURPOSE
The purpose of this advice letter is to modify Electric Tariff Rule 21, Generating Facility
Interconnections, to incorporate Phase 3 functions as adopted in Decision 16-06-052
(the Decision) and approved and modified in Resolution E-4898 (the Resolution).1
BACKGROUND
In Advice Letter 3647-E SCE requested approval of modifications to Electric Rule 21
Tariff (Rule 21) that incorporated the Smart Inverter Working Group (SIWG) Phase 3
advanced functions recommendations. The recommendations are comprised of eight
functions that can improve the performance of the distirbution grid and the network as a
whole.
The Resolution modifies the effective date of the function capability requirements,
makes adjustments to the technical requirements of the eight functions, approves
mandatory activation of two of the eight functions (Frequency Watt Mode and Volt Watt
Mode), and rejects the proposed modifications to smart inverter communications
requirements.

1

Resolution E-4898 was effective April 26, 2018.

P.O. Box 800

8631 Rush Street

Rosemead, California 91770

(626) 302-9645

Fax (626) 302-6396





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ADVICE 3810-E (U 338-E) -2- May 29, 2018 Final Effective Dates Function Function 1 - Monitor Key DER Data (Section Hh.7) Effective Date February 22, 2019, which is 9 months following SunSpec Alliance Communication Protocol Certification Test Function 2 - DER Disconnect and Earlier of: 1) December 2019 or 2) 12 Reconnect Command (Cease to Energize months after approval of the IEEE 1547.1 and Return to Service) (Section Hh.8a. standard revision. and b.) Function 3 - Limit Maximum Active Power Mode (Section Hh.8.c) Earlier of: 1) December 2019 or 2) 12 months after approval of the IEEE 1547.1 standard revision. Function 4 - Set Active Power Mode (Section Hh.2.n) 12 months after approval of a nationally recognized standard that includes the function. Function 5 - Frequency Watt Mode (Section Hh.2.l) February 22, 2019, which is 9 months following SunSpec Alliance Communication Protocol Certification Test Function 6 – Volt Watt Mode (Section Hh.2.m) February 22, 2019, which is 9 months following SunSpec Alliance Communication Protocol Certification Test Function 7 – Dynamic Reactive Support (Section Hh.2.o) 12 months after approval of a nationally recognized standard that includes the function. Function 8 – Scheduling Power Values and Modes (Section Hh.6) February 22, 2019, which is 9 months following SunSpec Alliance Communication Protocol Certification Test
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ADVICE 3810-E (U 338-E) -3- May 29, 2018 PROPOSED TARIFF CHANGES The following items are proposed in support of the Phase 3 Smart Inverter Advanced Functions:2 Section Hh. Section Hh.2.l This requirement will become mandatory for Generating Facilities utilizing inverterbased technologies for which an Interconnection Request is submitted on or after 12 months from the date the Phase 3 Smart Inverter Advanced Function Advice Letter (AL 3647-E) was made effective by the Commission beginning February 22, 2019. The utilization of this function is permissible under mutual agreement between the Distribution Provider3 and the generating facility before the effective date. Smart inverters shall reduce their real power production as a function of system frequency in accordance with the following: • When system frequency exceeds 60.0361 Hz, 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) • When system frequency moves under 59.964 Hz, 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. • The default dead-band should be +/- 0.0361 Hz from 60 hertz (59.9649 Hz to 60.0361 Hz). When the system frequency is in range of 59.9649 Hz and 60.03641 Hz, the Smart Inverter is not required to increase or decrease power as a function of system frequency. 2 3 Text that is underlined indicates new text and text being deleted is shown in strikeout mode. The Resolution requires SCE to add the following language to each Phase 3 function in Rule 21 with the effective dates: “The utilization of this function is permissible under mutual agreement between the utility and the generating facility before the effective date.” See Resolution E-4898, at p. 43 & Ordering Paragraph No. 2.g. SCE has substituted the defined term “Distribution Provider” for the term “utility” to ensure consistency within its tariff.
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ADVICE 3810-E (U 338-E) -4- May 29, 2018 Figure Hh-2: Active power as a function of system frequency is revised as follows: Active Power Output in % of Nameplate Trip Zone Low Frequency Ride-Through Zone High Frequency RideThrough Zone Continuous Operation Trip Zone Dead-Band 100% 75% of Nameplate 75% 50% of Nameplate 50% 25% 62.000 Hz 60.500 Hz 60.036 Hz 60.000 Hz 59.964 Hz 58.500 Hz 57.000 Hz 0% Frequency Section Hh.2.m This requirement will become mandatory for Generating Facilities utilizing inverterbased technologies for which an Interconnection Request is submitted beginning February 22, 2019. on or after 12-months from the Phase 3 Smart Inverter Function Advice Letter (AL 3647-E) was made effective by the Commission. The utilization of this function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. Smart Inverters shall reduce their real power production as a function measured voltage at the inverter terminal or at the Generating Facility Point of Common Coupling (PCC) in accordance with the following: • When the measured voltage is greater than 106% of nominal voltage (Example: 127.2 volts on a 120 volts nominal), the export of active power at the PCC or the production of active power output produced by the Smart Inverter shall be reduced at a rate of 5025% of real active power nameplate rating per one percent of nominal voltage. Figure Hh-3 Volt-Watt Requirements illustrate the required rate of reduction. When export of active power is controlled, a certified inverter and control system shall be used. • When the measured voltage is greater than 108110% of nominal voltage (Example: 129.632 volts on a 120 volts nominal), the export of active power to the grid at the PCC or the production of active power output produced by the Smart Inverter shall be reduced to 0 watts. Figure Hh-3: Volt-Watt Requirements is revised as follows:
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-5- 100% May 29, 2018 Real Power Reduction Zone Full Power Production Capabilities Zone No Real Power Production Zone 50% 110% 109% 108% 107% 0% 106% Active Power as % of Nameplate ADVICE 3810-E (U 338-E) % Voltage Section Hh.2.n The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted twelve (12) months after approval of a nationally recognized standard that includes the function. The utilization of this function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. The utilization of this function is optional and allowed upon mutual agreement with the Distribution Provider and the Applicant. Section Hh.2.o The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted twelve (12) months after approval of a nationally recognized standard that includes the function. The utilization of this function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. The utilization of this function is optional and allowed upon mutual agreement with the Distribution Provider and the Applicant. Hh.5 The communication protocol requirements included in this Hh.5 shall become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted on or after the later of (a) March 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 standardbeginning February 22, 2019. The utilization of this
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ADVICE 3810-E (U 338-E) -6- May 29, 2018 function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. Until such date, this subsection may be used in all or in part by inverter-based technologies by mutual agreement of the Distribution Provider and the Applicant. The communications requirements herein shall be between (i) the Distribution Provider and the individual Generating Facility’s inverter control or energy management system; (ii) the Distribution Provider and communication to the Generating Facility through an aggregator not co-located or part of the Generating Facilityi; or (iii) other communication options as mutually agreed to by Applicant and Distribution Provide footnote i i Communication utilizing this aggregator action is not permitted at this time. Hh.6 Generating Facilities which incorporate Smart Inverters shall incorporate scheduling capabilities with minimum scheduling memory capability of at least 24 events. The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted beginning February 22, 2019on or after the later of (a) March 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 utilization of this function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. Each event is composed of modifications to each, selected group of, or all of the following Smart Inverter function: • Modification to the normal ramp-up rate and reconnect ramp-up rate setpoints. The selected scheduling control system shall store the schedules and shall send operational commands to the Smart Inverters as required by the schedule received from the Distribution Provider. The Smart Inverter shall respond by changing its mode of operation as commanded at the schedule start time with no unreasonable delay. Hh.7 The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted beginning February 22, 2019on or after the later of (a) March 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 utilization of this function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. The Smart Inverter shall have the capability to communicate its performance information including:
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ADVICE 3810-E (U 338-E) -7- May 29, 2018 a. Smart Inverter production or consumption of active power (watts). b. Smart Inverter consumption or production of reactive power (vars) c. Phase currents measure at the AC terminal of the Smart Inverter (amps) d.c. Phase measured at the AC terminals of the Smart Inverter (volts) e.d. Frequency measured at the AC terminals of the Smart Inverter (Hz) When the Generating Facility includes energy-storage with Smart Inverters, the following monitoring and telemetry capability is required: The Smart Inverter shall be capable of communicating the available kWh for the percentage of operations energy-storage capacity. Available kWhOperational energy of the energy storage system is amount energy which can be used to support the energy needs of the electric system including the energy needs for the load within the generating facility or the Distribution System. • When the Generating Facility with Smart Inverters includes one or multiple energy storage systems. The available kWh operational energy should be communicated as an aggregate of all the energy storage systems. Hh.8 The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted the earlier of: 1) December 2019, or 2) twelve (12) months on or after the approval of the IEEE 1547.1 standard revisions. The utilization of this function is permissible under mutual agreement between the Distribution Provider and the generating facility before the effective date. Smart Inverters shall have the capabilities of accepting an operational controls through communications in accordance to the following: No cost information is required for this advice letter. This advice letter will not increase any rate or charge, cause the withdrawal of service, or conflict with any other schedule or rule. TIER DESIGNATION Pursuant to Ordering Paragraph 2 of the Resolution, this advice letter is submitted with a Tier 1 designation. EFFECTIVE DATE This advice letter will become effective on May 29, 2018, the same day as submitted.
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ADVICE 3810-E (U 338-E) -8- May 29, 2018 NOTICE Anyone wishing to protest this advice letter may do so by letter via U.S. Mail, facsimile, or electronically, any of which must be received no later than 20 days after the date of this advice letter. Protests should be mailed to: CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, California 94102 E-mail: EDTariffUnit@cpuc.ca.gov Copies should also be mailed to the attention of the Director, Energy Division, Room 4004 (same address above). In addition, protests and all other correspondence regarding this advice letter should also be sent by letter and transmitted via facsimile or electronically to the attention of: Gary A. Stern, Ph.D. Managing Director, State Regulatory Operations Southern California Edison Company 8631 Rush Street Rosemead, California 91770 Telephone: (626) 302-9645 Facsimile: (626) 302-6396 E-mail: AdviceTariffManager@sce.com Laura Genao Managing Director, State Regulatory Affairs c/o Karyn Gansecki Southern California Edison Company 601 Van Ness Avenue, Suite 2030 San Francisco, California 94102 Facsimile: (415) 929-5544 E-mail: Karyn.Gansecki@sce.com There are no restrictions on who may file a protest, but the protest shall set forth specifically the grounds upon which it is based and shall be submitted expeditiously. In accordance with General Rule 4 of GO 96-B, SCE is serving copies of this advice letter to the interested parties shown on the attached GO 96-B and R.11-09-011 service lists. Address change requests to the GO 96-B service list should be directed by electronic mail to AdviceTariffManager@sce.com or at (626) 302-4039. For changes to all other service lists, please contact the Commission’s Process Office at (415) 703-2021 or by electronic mail at Process_Office@cpuc.ca.gov.
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ADVICE 3810-E (U 338-E) -9- May 29, 2018 Further, in accordance with Public Utilities Code Section 491, notice to the public is hereby given by submitting and keeping the advice letter at SCE’s corporate headquarters. To view other SCE advice letters submitted with the Commission, log on to SCE’s web site at https://www.sce.com/wps/portal/home/regulatory/advice-letters. For questions, please contact Mary J. Brown at (626) 302-8103 or by electronic mail at mary.brown@sce.com Southern California Edison Company /s/ Gary A. Stern, Ph.D. Gary A. Stern, Ph.D. GAS:mb:jm Enclosures
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CALIFORNIA PUBLIC UTILITIES COMMISSION ADVICE LETTER SUMMARY ENERGY UTILITY MUST BE COMPLETED BY UTILITY (Attach additional pages as needed) Company name/CPUC Utility No.: Southern California Edison Company (U 338-E) Utility type: Contact Person: Darrah Morgan  ELC  GAS  PLC  HEAT Phone #: (626) 302-2086  WATER E-mail: Darrah.Morgan@sce.com E-mail Disposition Notice to: AdviceTariffManager@sce.com EXPLANATION OF UTILITY TYPE ELC = Electric PLC = Pipeline GAS = Gas HEAT = Heat Advice Letter (AL) #: Subject of AL: (Date Submitted/ Received Stamp by CPUC) WATER = Water 3810-E Tier Designation: 1 Modifications to Electric Tariff Rule 21 to Incorporate Smart Inverter Phase 3 Advanced Functions in Compliance with Resolution E-4898 Keywords (choose from CPUC listing): Compliance AL type:  Monthly  Quarterly  Annual  One-Time  Other If AL submitted in compliance with a Commission order, indicate relevant Decision/Resolution #: Resolution E-4898 Does AL replace a withdrawn or rejected AL? If so, identify the prior AL: Summarize differences between the AL and the prior withdrawn or rejected AL: Confidential treatment requested?  Yes  No If yes, specification of confidential information: Confidential information will be made available to appropriate parties who execute a nondisclosure agreement. Name and contact information to request nondisclosure agreement/access to confidential information: Resolution Required?  Yes  No Requested effective date: 5/29/18 No. of tariff sheets: -10- Estimated system annual revenue effect: (%): Estimated system average rate effect (%): When rates are affected by AL, include attachment in AL showing average rate effects on customer classes (residential, small commercial, large C/I, agricultural, lighting). Tariff schedules affected: Rule 21 and Table of Contents Service affected and changes proposed1: Pending advice letters that revise the same tariff sheets: 1 Discuss in AL if more space is needed. None
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Protests and all other correspondence regarding this AL are due no later 20 days after the date of this submittal, unless otherwise authorized by the Commission, and shall be sent to: CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, California 94102 E-mail: EDTariffUnit@cpuc.ca.gov Gary A. Stern, Ph.D. Managing Director, State Regulatory Operations Southern California Edison Company 8631 Rush Street Rosemead, California 91770 Telephone: (626) 302-9645 Facsimile: (626) 302-6396 E-mail: AdviceTariffManager@sce.com Laura Genao Managing Director, State Regulatory Affairs c/o Karyn Gansecki Southern California Edison Company 601 Van Ness Avenue, Suite 2030 San Francisco, California 94102 Facsimile: (415) 929-5544 E-mail: Karyn.Gansecki@sce.com
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Public Utilities Commission 3810-E Cal. P.U.C. Sheet No. Title of Sheet Attachment A Cancelling Cal. P.U.C. Sheet No. Revised 63988-E Revised 63989-E Revised 63990-E Revised 63991-E Revised 63992-E Revised 63993-E Revised 63994-E Revised 63995-E Rule 21 Rule 21 Rule 21 Rule 21 Rule 21 Rule 21 Rule 21 Rule 21 Revised 62071-E Revised 62072-E** Original 62073-E* Revised 62076-E Revised 62077-E Original 62078-E Original 62079-E Original 62080-E Revised 63996-E Revised 63997-E Table of Contents Table of Contents Revised 63337-E Revised 62121-E 1
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS Hh. 63988-E 62071-E Sheet 150 (Continued) SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 2. Prevention of Interference (Continued) k. Ramp Rate Requirements The Smart Inverter is required to have the following ramp controls for at least the following 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. • • l. 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. Connect/Reconnect Ramp-up rate: Upon starting 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. Frequency-Watt Requirements This requirement will become mandatory for Generating Facilities utilizing inverterbased technologies for which an Interconnection Request is submitted beginning February 22, 2019. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. Smart inverters shall reduce their real power production as a function of system frequency in accordance with the following: (T) | | (T) • When system frequency exceeds 60.036 Hz, 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) (T) • When system frequency moves under 59.964 Hz, 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. (T) • The default dead-band should be +/- 0.036 Hz from 60 hertz (59.964 Hz to 60.036 Hz). When the system frequency is in range of 59.964 Hz and 60.0364 Hz, the Smart Inverter is not required to increase or decrease power as a function of system frequency. (T) | (T) (Continued) (To be inserted by utility) Advice 3810-E Decision 150P16 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS Hh. 63989-E 62072-E** Sheet 151 (Continued) SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 2. Prevention of Interference (Continued) • Figure Hh-2 illustrated this requirement for three levels of output power. Figure Hh-2 is for illustration purpose only. • Open loop response time for Frequency-Watt shall be 5 seconds Figure Hh-2: Active power as a function of system frequency Active Power Output in % of Nameplate Trip Zone Low Frequency Ride-Through Zone High Frequency RideThrough Zone Continuous Operation Trip Zone Dead-Band 100% 75% of Nameplate 75% 50% of Nameplate 50% 25% 62.000 Hz 60.500 Hz 60.000 Hz 60.036 Hz 59.964 Hz 58.500 Hz 57.000 Hz 0% Frequency m. Voltage-Watt Default Settings Requirements This requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted beginning February 22, 2019. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. Smart Inverters shall reduce their real power production as a function measured voltage at the inverter terminal or at the Generating Facility Point of Common Coupling (PCC) in accordance with the following: • • When the measured voltage is greater than 106% of nominal voltage (Example: 127.2 volts on a 120 volts nominal), the export of active power at the PCC or the production of active power by the Smart Inverter shall be reduced at a rate of 25% of active power nameplate rating per one percent of nominal voltage. Figure Hh-3 Volt-Watt Requirements illustrate the required rate of reduction. When export of active power is controlled, a certified inverter and control system shall be used. When the measured voltage is greater than 110% of nominal voltage (Example: 132 volts on a 120 volts nominal), the export of active power to the grid at the PCC or the production of active power by the Smart Inverter shall be reduced to 0 watts. (T) | (T) (T) | | | | | | | (T) (Continued) (To be inserted by utility) Advice 3810-E Decision 151P20 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS 63989-E 62072-E** Sheet 151 (Continued) (Continued) (To be inserted by utility) Advice 3810-E Decision 151P20 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Revised Original Cancelling Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS Hh. 63990-E 62073-E* Sheet 152 (Continued) SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 2. Prevention of Interference (Continued) 100% Real Power Reduction Zone Full Power Production Capabilities Zone No Real Power Production Zone 50% 110% 109% 108% 107% 0% 106% Active Power as % of Nameplate Figure Hh-3: Volt-Watt Requirements % Voltage n. Set Active Power Level Mode Function The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted twelve (12) months after approval of a nationally recognized standard that includes the function. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. o. Dynamic Reactive Power Support Function The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted twelve (12) months after approval of a nationally recognized standard that includes the function. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. (N) | | | | | | | | | | | | (N) (Continued) (To be inserted by utility) Advice 3810-E Decision 152P14 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS 63991-E 62076-E Sheet 155 (Continued) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 4. Supplemental Generating Facility 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 protocol requirements included in this Hh.5 shall become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted beginning February 22, 2019. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. The communications requirements herein shall be between (i) the Distribution Provider and the individual Generating Facility’s inverter control or energy management system; (ii) the Distribution Provider and communication to the Generating Facility through an aggregator not co-located or part of the Generating Facility; or (iii) other communication options as mutually agreed to by Applicant and Distribution Provider. (T) | (T) a. Generating Facilities utilizing inverter-based technologies must adhere to all of the following communication protocol requirements for communication between Distribution Provider and the communication option selected under section Hh.5. This Rule does not specify the communication between the selected communication option and Smart Inverter but performance will be enforced by this Rule: 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. (Continued) (To be inserted by utility) Advice 3810-E Decision 155P14 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS 63992-E 62077-E Sheet 156 (Continued) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 5. Communication Requirements (Continued) 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; B. Cybersecurity and privacy requirements (these may additionally or alternatively be included in the application-level protocol implementation guide); and, C. Generic device communications registration management requirements, including how to register individual Generating Facilities, Generating Facilities with energy management systems, and aggregators (these requirements additionally or alternatively may be included in the application-level protocol implementation guide). ii. Application-Level Protocol Implementation Guide, which shall provide A. Communication requirements and implementation guidelines to ensure consistent interoperability of the Generating Facilities with all California investor-owned utilities under the Commission’s jurisdiction. 6. Scheduling Capability Requirements Generating Facilities which incorporate Smart Inverters shall incorporate scheduling capabilities with minimum scheduling memory capability of at least 24 events. The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request beginning February 22, 2019. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. Each event is composed of modifications to each, selected group of, or all of the following Smart Inverter function: (T) | (T) (Continued) (To be inserted by utility) Advice 3810-E Decision 156P13 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Original Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS 63993-E 62078-E Sheet 157 (Continued) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 6. Scheduling Capability Requirements (Continued) • Modifications to the voltage and reactive set-points of the Dynamic volt/var function. • Modifications to the reactive power set-points for the fixed power factor function. • Modifications to the voltage and watt-reduction level set-points for the volt/watt function. The Generating Facility’s scheduling capability requirement herein shall be met by one or more of the following options: • Scheduling capability requirements may be stored at the Generating Facility Energy Management System (GFEMS). The GFEMS shall communicate the necessary commands to the Smart Inverters within 10 minutes from when GFEMS received the scheduling information. • Scheduling capability requirements may be stored at the Smart Inverter Control Unit (SMCU) within the Generating Facility. The SMCU shall communicate necessary commands to the Smart Inverters within 10 minutes from when SCMU received the scheduling information. • Scheduling capability requirements may be stored at an aggregator not co-located within the Generating Facility. The aggregator shall communicate the necessary commands to the Smart Inverter within 15 minutes of the aggregator receiving the scheduling information. • Other options may be utilized by mutual agreement between the Applicant and Distribution Provider The selected scheduling control system shall store the schedules and shall send operational commands to the Smart Inverters as required by the schedule received from the Distribution Provider. The Smart Inverter shall respond by changing its mode of operation as commanded at the schedule start time with no unreasonable delay. (T) Each scheduled mode of operation shall include and start-time and duration The Smart Inverter should return to its default settings at the end of the duration time or shall enter a new operational mode as directed by the scheduling control system. (Continued) (To be inserted by utility) Advice 3810-E Decision 157P9 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Original Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS 63994-E 62079-E Sheet 158 (Continued) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 7. Monitoring and Telemetry Requirements The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted beginning February 22, 2019. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. The Smart Inverter shall have the capability to communicate its performance information including: (T) (T) a. Smart Inverter production or consumption of active power (watts). b. Smart Inverter consumption or production of reactive power (vars) c. Phase measured at the AC terminals of the Smart Inverter (volts) d. Frequency measured at the AC terminals of the Smart Inverter (Hz) When the Generating Facility includes energy-storage with Smart Inverters, the following monitoring and telemetry capability is required: The Smart Inverter shall be capable of communicating the percentage of operations energy-storage capacity. Operational energy of the energy storage system is amount energy which can be used to support the energy needs of the electric system including the energy needs for the load within the generating facility or the Distribution System. (T) (T) Operational State as In-Service or not In-service communication capability requirements. The Smart Inverter shall be capable of communicating when the Smart Inverter is capable of providing electric services as follows: • In-Service state An operational state which indicates that the Smart Inverter is connected to the electric system and operating as determined locally by the Generating Facility operator or by a scheduling control system as outlined in section Hh.6 • No In-Service state An operating state which indicates that the Smart Inverter is not capable of connecting to the electric system and not capable of providing any type of electrical support as required locally or as commanded by a scheduling control system as outlined in section Hh.6 Monitoring and performance information should be communicated in aggregate at the Generating Facility as follows: (Continued) (To be inserted by utility) Advice 3810-E Decision 158P20 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Original Cal. PUC Sheet No. Cal. PUC Sheet No. Rule 21 GENERATING FACILITY INTERCONNECTIONS 63995-E 62080-E Sheet 159 (Continued) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS (Continued) 7. Monitoring and Telemetry Requirements (Continued) • When the Generating Facility includes only Smart Inverters, the production or consumption of active and reactive power shall be communicated as an aggregate of all Smart Inverters within the Generating Facility. • When a Generating Facility includes Smart Inverters and other technologies such as synchronous or induction generation systems, the Generating Facility shall communicate the following: o o • The production or consumption of active and reactive power shall be communicated in aggregate of all Smart Inverters within the Generating Facility. The production or consumption of active and reactive power shall be communicated in aggregate of all the other technologies within the Generating Facility. When the Generating Facility with Smart Inverters includes one or multiple energy storage systems. The available operational energy should be communicated as an aggregate of all the energy storage systems. (T) 8. Control through communication capabilities The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted the earlier of: 1) December 2019 or 2) 12 months after approval of the IEEE 1547.41 standard revision. The utilization of this function is permissible under mutual agreement between Distribution Provider and the generating facility before the effective date. Smart Inverters shall have the capabilities of accepting an operational controls through communications in accordance to the following: (T) (T) a. Cease to energize control command When the Smart Inverter receives a cease-to-energize command through communication it must enter into a cease-to-energize state of operation or shall initiate the opening of the DER switch referenced in the inverter terminal in order to galvanically isolate the DER system from the Distribution System b. Return to service control command When the Smart Inverter receives a return-to-service control command, the Smart Inverter may return to service operation as required by Generating Facility operator or as required by the scheduling control system as required by section H.6 c. Limit Active Power command When the Smart Inverter receives a command to limit its production of real power, the Smart Inverter shall reduce its real power production to the specified percent of real power capacity of the Smart Inverter or to a specified real power value (Continued) (To be inserted by utility) Advice 3810-E Decision 159P14 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised TABLE OF CONTENTS Cal. PUC Sheet No. Cal. PUC Sheet No. 63996-E 63337-E Sheet 1 Cal. P.U.C. Sheet No. TITLE PAGE ............................................................................................................................. 11431-E TABLE OF CONTENTS - RATE SCHEDULES ....63996-63036-63037-63207-63317-63093-63094-E ........................................................................................................... 63338-63043-63044-E TABLE OF CONTENTS - LIST OF CONTRACTS AND DEVIATIONS ................................... 63044-E TABLE OF CONTENTS - RULES ............................................................................................ 63997-E TABLE OF CONTENTS-INDEX OF COMMUNITIES, MAPS, BOUNDARY DESCRIPTIONS 58961-E TABLE OF CONTENTS - SAMPLE FORMS.. .................. 59608-61801-61576-61817-63318-61631-E ........................................................................................................... 61970-61971-63296-E (T) (T) PRELIMINARY STATEMENT: A. B. C. D. E. F. G. H. I. J. K. L. M. N. O. P. Territory Served ......................................................................................................... 22909-E Description of Service ................................................................................................ 22909-E Procedure to Obtain Service ..................................................................................... 22909-E Establishment of Credit and Deposits ....................................................................... 22909-E General .......................................................................... 45178-45179-45180-53818-45182-E Symbols ..................................................................................................................... 45182-E Gross Revenue Sharing Mechanism .......26584-26585-26586-26587-27195-27196-54092-E .................................................................................................. 51717-53819-27200-27201-E Baseline Service ........................................................... 52027-52028-52029-52030-52031-E Charge Ready Program Balancing Account.................................................... 58633-58634-E Not In Use ............................................................................................................................. -E Nuclear Decommissioning Adjustment Mechanism ........................................ 36582-57779-E Purchase Agreement Administrative Costs Balancing Account ........... 55207-51922-55208-E Income Tax Component of Contributions ....................................................... 58419-58420-E Memorandum Accounts.... 21344-62633-61164-58221-49492-61165-61166-61167-53821-E ........ 50418-42841-42842-44948-44949-44950-62634-62635-44953-42849-42850-42851-E ........ 61169-61170-55623-61171-42856-61172-61173-52033-50419-55048-61174-42863-E ........ 42864-56204-56205-51235-45920-51236-42870-50209-42872-42873-50421-46539-E ........ 42876-42877-42878-42879-42880-42881-42882-54534-53371-56253-44959-42887-E ........ 53321-53322-47098-52551-52552-49928-56235-56236-56237-55144-55145-44029-E ........ 53016-57156-57157-51163-51164-51165-51166-51167-51168-51169-51170-51171-E ........ 51244-55806-56393-56394-56395-56396-56397-56398-56399-58978-59917-59918-E California Alternate Rates for Energy (CARE) Adjustment Clause ................. 34705-41902-E .................................................................................................. 36472-38847-56788-60261-E Optional Pricing Adjustment Clause (OPAC) ........................... 27670-27671-27673-27674-E (Continued) (To be inserted by utility) Advice 3810-E Decision 1P6 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised TABLE OF CONTENTS Cal. PUC Sheet No. Cal. PUC Sheet No. 63997-E 62121-E Sheet 11 (Continued) RULES Rule No. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 20 21 Title of Sheet Cal. P.U.C. Sheet No. Definitions ................ 59339-58-55551-56605-58779-55554-56606-55556-55557-55558-E ...................................................................................................................... 55559-55560-E ............................................................................................... 55561-55562-55563-55564-E Description of Service .........................22926-22927-22928-25264-22930-22931-22932-E ............................ 22933-22934-58022-58023-47145-47146-47147-47148-47149-47150-E Application for Service ................................................................................. 50441-22943-E Contracts .......................................................................................... 55734-39859--55679E Special Information Required on Forms ............................... 27742-27743-51306-31052-E Establishment and Re-establishment of Credit ........................................... 55074-55075-E Deposits ........................................................................................... 55076-55077-47771-E Notices ......................................................................................................... 55078-27747-E Rendering and Payment of Bills ................................ 56607-58024-51308-52504-52692-E Disputed Bills ............................................................................................... 27748-55079-E Discontinuance and Restoration of Service .............. 55680-55080-22966-22967-22968-E .................................................................................... 55681-55682-22971-45093-49671-E Rates and Optional Rates ................................................................ 40634-35618-51311-E Temporary Service ................................................................................................. 51312-E Shortage of Supply and Interruption of Delivery ......................................... 53899-26339-E Distribution Line Extensions .... 24684-47151-47152-47153-47154-58026-47156-47157-E ................ 47158-58027-47160-47161-47162-47163-47164-58028-51853-47167-47168-E Service Extensions ...............................24700-49672-48155-24703-24704-47169-47170-E ..... 47171-47172-47173-47174-47175-47176-47177-47178-47179-47180-48156-48157-E Adjustment of Bills and Meter Tests .......................... 19616-47773-47774-19619-19620-E Supply to Separate Premises and Use by Others ............... 47472-45543-51854-45545-E Replacement of Overhead With Underground Electric Facilities ...... 31867-23019-23020-E ........................................................................................................... 31868-26177-31869-E Generating Facility Interconnections ....58780-54719-54720-54721-54722-56118-56119-E ..... 56120-54726-54727-54728-56121-54730-54731-54732-54733-54734-54735-54736-E ..... 56122-58781-58782-54740-56125-56126-56127-54744-54745-54746-58783-58784-E ..... 57537-54750-58784-54752-54753-58785-58786-58787-54757-54758-54759-58788-E ..... 54761-54762-58789-54764-58790-58791-58792-54768-54769-58793-58794-54772-E ..... 54773-54774-54775-54776-54777-54778-54779-54780-54781-54782-54783-54784-E ..... 54785-54786-54787-54788-54789-54790-54791-54792-54793-54794-54795-54796-E ..... 54797-54798-54799-54800-54801-54802-54803-54804-54805-54806-54807-54808-E ..... 54809-54810-54811-54812-58796-54814-54815-54816-54817-54818-54819-54820-E ..... 54821-54822-54823-54824-54825-54826-54827-54828-54829-54830-54831-54832-E ..... 54833-56129-54835-54836-54837-54838-54839-54840-54841-54842-54843-54844-E ..... 56130-56131-56132-56133-56134-56135-56136-56137-56138-56139-56140-56141-E ..... 56142-56143-56144-56145-56146-58797-58798-62070-56150-63988-63989-63990-E ... 62074-62075-63991-63992-63993-63994-63995-62081-62082-62083-62084-62085-E ..... 62086-62087-62088-62089-62090-62091-62092-62093-62094-62095-62096-62097-E ... 62098-62099-62100-62101-62102-62103-62104-62105-62106-62107-62108-62109-E .......................... 62110-62111-62112-62113-62114-62115-62116-62117-62118-62119-E (T) (T) (Continued) (To be inserted by utility) Advice 3810-E Decision 11P6 Issued by Caroline Choi Senior Vice President (To be inserted by Cal. PUC) Date Filed May 29, 2018 Effective Resolution E-4898
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