May 8, 2018 Advice Letter 3647-E

Transcription

1 STATE OF CALIFORNIA Edmund G. Brown Jr., Governor PUBLIC UTILITIES COMMISSION 505 VAN NESS AVENUE SAN FRANCISCO, CA May 8, 2018 Advice Letter 3647-E Russell G. Worden Director, State Regulatory Operations Southern California Edison Company 8631 Rush Street Rosemead, CA SUBJECT: Modifications to Electric Tariff Rule 21 to Incorporate Communication Requirements for Smart Inverters (Phase 3) Dear Mr. Worden: Advice Letter 3647-E is effective as of April 26, 2018 per Resolution E-4898 Ordering Paragraphs. Sincerely, Edward Randolph Director, Energy Division

2 ADVICE LETTER (AL) SUSPENSION NOTICE ENERGY DIVISION Utility Name: Southern California Edison Utility Number/Type: U 338-E Advice Letter Number(s): 3647-E Date AL(s) Filed: August 18, 2017 Utility Contact Person: Darrah Morgan Utility Phone No.: Date Utility Notified: September 14, 2017 [ ] ed to: Darrah.Morgan@sce.com ED Staff Contact: Jeffrey Kwan ED Staff jeffrey.kwan@cpuc.ca.gov ED Staff Phone No.: [X] INITIAL SUSPENSION (up to 120 DAYS from the expiration of the initial review period) This is to notify that the above-indicated AL is suspended for up to 120 days beginning September 17, 2017 for the following reason(s) below. If the AL requires a Commission resolution and the Commission s deliberation on the resolution prepared by Energy Division extends beyond the expiration of the initial suspension period, the advice letter will be automatically suspended for up to 180 days beyond the initial suspension period. [X] A Commission Resolution is Required to Dispose of the Advice Letter [ ] Advice Letter Requests a Commission Order [ ] Advice Letter Requires Staff Review The expected duration of initial suspension period is 120 days [ ] FURTHER SUSPENSION (up to 180 DAYS beyond initial suspension period) The AL requires a Commission resolution and the Commission s deliberation on the resolution prepared by Energy Division has extended beyond the expiration of the initial suspension period. The advice letter is suspended for up to 180 days beyond the initial suspension period. If you have any questions regarding this matter, please contact Jeffrey Kwan at jeffrey.kwan@cpuc.ca.gov. cc: EDTariffUnit * Note: reference Decision D , dated February 21, 2002, and Rule 7.5 in appendix A of D.O

3 Russell G. Worden Managing Director, State Regulatory Operations August 18, 2017 ADVICE 3647-E (U 338-E) PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA ENERGY DIVISION SUBJECT: Southern California Edison Company s Proposed Modifications to Electric Tariff Rule 21 to Incorporate Smart Inverter Advanced Functions (Phase 3) In compliance with the California Public Utilities Commission (CPUC or Commission) Decision (D.) , 1 Southern California Edison Company (SCE) hereby submits for filing the following changes to its tariffs. The revised tariff sheets are listed on Attachment A and are attached hereto. PURPOSE The purpose of this filing is to modify Electric Tariff Rule 21, Generating Facility Interconnections, to incorporate Phase 3 functions and the Smart Inverter Working Group s (SIWG s) recommendation for synchronization with the Institute of Electrical and Electronics Engineers (IEEE) 1547 standard as adopted in D (the Decision). BACKGROUND AND DISCUSSION On September 22, 2011 the Commission initiated Rulemaking (R.) (Rule 21 proceeding) to review and, if necessary, revise the rules and regulations governing the interconnection of generation and storage resources to the electric distribution systems of SCE, Pacific Gas and Electric Company (PG&E), and San Diego Gas and Electric Company (SDG&E), collectively the investor-owned utilities (IOUs). The IOUs rules and regulations pertaining to the interconnection of generating facilities are generally set forth in Electric Tariff Rule 21 (Rule 21). 1 D adopted June 26, 2016, is entitled Alternate Decision Instituting Cost Certainty, Granting Joint Motions to Approve Proposed Revisions to Electric Tariff Rule 21, and Providing Smart Inverter Development a Pathway Forward to Pacific Gas and Electric Company, Southern California Edison Company, and San Diego Gas & Electric Company. P.O. Box Rush Street Rosemead, California (626) Fax (626)

4 ADVICE 3647-E (U 338-E) August 18, 2017 Phase 3 Ordering Paragraph (OP) 9 of D required the IOUs to file a Tier 3 advice letter with proposed revisions to Rule 21 to set forth any agreed upon technical requirements, testing and certification processes, and effective dates for Phase 2 communication protocols and Phase 3 advance inverter functions. 2 The filings were due within six months of the effective date of the Decision, or by December 20, On December 20, 2016, the IOUs filed a joint advice letter that provided a work plan and an outline of next steps for tariff development. 3 The filed work plan identified additional efforts to support the Phase 3 tariff development (inculding continuation of stakeholder discussions held as part of the Smart Inverter Working Group (SIWG), and proposed to submit a status update on the activities outlined in the work plan by March 30, Furthermore, the IOUs anticipated to each file the Tier 3 advice letter with proposed tariff revisions incorporating the Phase 3 functions in Rule 21 in June However, the proposed June 2017 date was contingent on additional efforts, and therefore, the IOUs stated in the December 2016 advice letter that the filing date for the Tier 3 advice letters may be modified upon approval from the Commission s Energy Division, with support of SIWG members, if deemed appropriate to maintain with IEEE 1547 and still be within reason of attaining the goal of smart inverters reaching full functionality by 2020 as stated in the Commission s DER Action Plan. 5 Discussions within the SIWG identified the benefit of additional dialogue continuing past June 2017 to assist with Phase 3 tariff development. As such, an extension to file the Tier 3 advice letter was discussed with stakeholders in meetings held on June 1, 2017 and June 8, 2017 and a filing date of August 2017 was proposed instead. No party objected to the proposed extension. On June 20, 2017, SDG&E, on behalf the IOUs, submitted a request to file the Tier 3 advice letter with tariff modification related to Phase 3 functions on August 18, The Commission s Executive Director appoved the IOUs request on June 27, SCE appreciates the stakeholder feedback gained during SIWG calls held throughout 2017 that has assisted with Rule 21 tariff development. SCE recongizes that additional discussion post Advice Letter filing may further assist stakeholders with review of the Advice Letter. Therefore, SCE proposes to work with the Commission to schedule three additional calls commencing no later than two weeks after the Advice Letter filing. SCE will consult with the Commission to determine if such calls could commence within the SIWG call format or will schedule a separate call if necessary. It is expected that the calls will have joint IOU representation. 2 Decision at p. 50 and Appendix E at pp See SCE Advice 3533-E, PG&E Advice 4983-E and SDG&E Advice 3022-E. 4 SCE, on behalf of the IOUs, submitted a status update letter to the Commission s Energy Division on March 30, Advice 3533-E et al at p. 7.

5 ADVICE 3647-E (U 338-E) August 18, 2017 As this Advice Letter addresses both function capability and requirement dates, the following summary reflects the propsosed Smart Inverter advanced function dates for ease of review: As tariff reivsions within this Advice Letter propose function capability or requirement dates (for Function 5 and 6), the following summary reflects the proposed function requirement dates for ease of review: 6 Function Function One Monitor Key DER Data (Section H.h.7) Function Two DER Disconnect and Reconnect Command (Cease to Energize and Return to Service) (Section H.h.8) Function Three Limit Maximum Active Power Mode (Section H.h.8) Function Four Set Active Power Mode (Section H.h.2.n) Function Five Frequency Watt Mode (Function H.h.2.I) Function Six Volt-Watt Mode (H.h.2.m) Function Seven Dynamic Reactive Support (H.h.2.o) Function Eight Scheduling Power Values and Modes (H.h.6) Requirement Date Later of March 1, 2018 or 9 months after the release of SunSpec Alliance Approved Test Procedure (or another industry-recognized protocol standard) 12 months after IEEE standard revision approval 12 months after IEEE standard revision approval Optional Upon Mutual Agreement between Utility and Applicant 12 months from Phase 3 Advance Function Advice Letter effective date 12 months from Phase 3 Advance Function Advice Letter effective date Optional Upon Mutual Agreement between Utility and Applicant Later of March 1, 2018 or 9 months after the release of SunSpec Alliance Approved Test Procedure (or another industry-recognized protocol standard) PROPOSED TARIFF CHANGES New tariff sheets have been inserted to accommodate the changes discussed below, requiring renumbering of approximately 44 pages. The following items are proposed in support of the Phase 3 Smart Inverter Advanced Functions: 7 6 SCE's proposed tariff language for Section Hh.5 indicates that communication utilizing an aggregator not co-located or part of the Generating Facility is not available at this time. SCE includes this clarification because applicable forms, agreements and/or requirements necessary for such an aggregator have not yet been developed or approved by the Commission. 7 Text that is underlined indicates new text and text being deleted is shown in strikeout mode.

6 ADVICE 3647-E (U 338-E) August 18, 2017 Section Hh. Section Hh. 2.i The subheading was modified to better align with the naming convention in Table Hh. 4 i. Fixed Power Factor Section Hh. 2.l Modified the Recommended Frequency-Watt Settings as follows to incorporate the Phase 3 requirements: l. Recommended Frequency-Watt Settings Requirements 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. This requirement will become mandatory for Generating Facilities utilizing inverterbased technologies for which and 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. Smart inverters shall reduce their real power production as a function of system frequency in accordance with the following: o Open loop response time for Frequency-Watt shall be 5 seconds. Figure Hh-2 Modified heading to remove uppercase Active Power power as a Function function of System system Frequency frequency Section Hh.2.m Modified the Voltage-Watt Default Settings as follows to incorporate the Phase 3 requirements: 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 on or after 12 months from the Phase 3 Smart Inverter Function Advice Letter 3647-E was made effective by the Commission. Smart Inverters, which have this optional function available, may enable this function in accordance with Distribution Provider setting requirements. 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: volts on a 120 volts nominal), the active power output produced

7 ADVICE 3647-E (U 338-E) August 18, 2017 by the Smart Inverter shall be reduced at a rate of 50% of real power nameplate rating per one percent of nominal voltage. Figure X-Volt-Watt Requirements illustrate the required rate of reduction. When the measured voltage is greater than 108% of nominal voltage (Example: volts on a 120 volts nominal), the active power output produced by the Smart Inverter shall be reduced to 0 watts. Figure Hh-3: Volt-Watt Requirements Section Hh.2.n Relocate existing Hh.2.n to Hh.2.p and inserted new requirement, Set Active Power Level Mode Function as follows: n. Set Active Power Level Mode Function The utilization of this function is optional and allowed upon mutual agreement with the Distribution Provider and the Applicant. Section Hh.2.o Relocate existing Hh.2.o to Hh.2.q and inserted new requirement, Dynamic Reactive Power Support Function as follows: Dynamic Reactive Power Support Function The utilization of this function is optional and allowed upon mutual agreement with the Distribution Provider and the Applicant.

8 ADVICE 3647-E (U 338-E) August 18, 2017 Section Hh.2.p Added new section Hh.2.p to relocate the requirement for Default Activation States for Phase 1 Function and change list to a table format as follows: Unless otherwise provided by Distribution Provider, pursuant to Distribution Provider s Distribution Generation Interconnection Handbook, the default settings will be as follows: Table Hh-4: Default Activation States for Phase 1 Functions Section Hh.2.q Added new section Hh.2.q to relocate the requirement for Load Shedding or Transfer Section Hh.5 Modified the Communication Requirements as follows: The communication protocol requirements included in this Hh. 5 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) March 1, 2018 or (b) nine months after the release of the SunSpec Alliance

9 ADVICE 3647-E (U 338-E) August 18, 2017 communication protocol certification test standard or the release of another industry-recognized communication protocol certification test standard. 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 Facility 8 ; or (iii) other communication options as mutually agreed to by Applicant and Distribution Provider. ; (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 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: Section Hh. 6 Inserted the new Scheduling Capability Requirements as follows: 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 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 standard. Each event is composed of modifications to each, selected group of, or all of the following Smart Inverter function: Modifications to the voltage and reactive set-points of the Dynamic volt/var function. Modification to the normal ramp-up rate and reconnect ramp-up rate setpoints. Modifications to the reactive power set-points for the fixed power factor function. 8 Communication utilizing this aggregator option is not permitted at this time.

10 ADVICE 3647-E (U 338-E) August 18, 2017 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 with no intentional delay. 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. Section Hh. 7 Inserted the new Monitor and Telemetry Requirements as follows: The capability for this requirement will 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 standard. The Smart Inverter shall have the capability to communicate its performance information including: a. Smart Inverter production or consumption of active power (watts).

11 ADVICE 3647-E (U 338-E) August 18, 2017 b. Smart Inverter consumption or production of reactive power (vars) c. Phase currents measure at the AC terminal of the Smart Inverter (amps) d. Phase measured at the AC terminals of the Smart Inverter (volts) e. 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 energy-storage. Available kwh 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. 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: 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:

12 ADVICE 3647-E (U 338-E) August 18, 2017 o The production or consumption of active and reactive power shall be communicated in aggregate of all Smart Inverters within the Generating Facility. o 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 kwh energy should be communicated as an aggregate of all the energy storage systems. Section Hh. 8 Inserted the new Control through communications capabilities requirement as follows: The capability for this requirement will become mandatory for Generating Facilities utilizing inverter-based technologies for which an Interconnection Request is submitted on or after the approval of IEEE standard revisions. Smart Inverters shall have the capabilities of accepting an operational controls through communications in accordance to the following: 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. d. Suspension of Active Power restriction When the Smart Inverter receives a command to suspend the command for active power reduction, the Smart Inverter may return to normal

13 ADVICE 3647-E (U 338-E) August 18, 2017 operation as required by Generating Facility operator or as required by the scheduling control system as required by section H.6 No cost information is required for this advice filing. This advice filing will not increase any rate or charge, cause the withdrawal of service, or conflict with any other schedule or rule. TIER DESIGNATION Pursuant to OP 9 of the Decision, this advice letter is submitted with a Tier 3 designation. EFFECTIVE DATE This Advice Letter will be effective upon Commission approval. NOTICE Anyone wishing to protest this advice filing 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 filing. Protests should be submitted to: CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, California 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: Russell G. Worden Managing Director, State Regulatory Operations Southern California Edison Company 8631 Rush Street Rosemead, California Telephone: (626) Facsimile: (626) AdviceTariffManager@sce.com

14 ADVICE 3647-E (U 338-E) August 18, 2017 Laura Genao Managing Director, State Regulatory Affairs c/o Karyn Gansecki Southern California Edison Company 601 Van Ness Avenue, Suite 2030 San Francisco, California Facsimile: (415) 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 must be received by the deadline shown above. In accordance with General Rule 4 of GO 96-B, SCE is serving copies of this advice filing to the interested parties shown on the attached GO 96-B and R 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) For changes to all other service lists, please contact the Commission s Process Office at (415) or by electronic mail at Process_Office@cpuc.ca.gov. Further, in accordance with Public Utilities Code Section 491, notice to the public is hereby given by filing and keeping the advice filing at SCE s corporate headquarters. To view other SCE advice letters filed with the Commission, log on to SCE s web site at For questions, please contact Mary Brown at (626) or by electronic mail at Mary.Brown@sce.com. Southern California Edison Company RGW:mb:cm Enclosures /s/ Russell G. Worden Russell G. Worden

15 CALIFORNIA PUBLIC UTILITIES COMMISSION ADVICE LETTER FILING 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 Phone #: (626) PLC HEAT WATER Disposition Notice to: EXPLANATION OF UTILITY TYPE ELC = Electric GAS = Gas PLC = Pipeline HEAT = Heat WATER = Water (Date Filed/ Received Stamp by CPUC) Advice Letter (AL) #: 3647-E Tier Designation: 3 Subject of AL: Modifications to Electric Tariff Rule 21 to Incorporate Communication Requirements for Smart Inverters (Phase 3) Keywords (choose from CPUC listing): Compliance; Rules AL filing type: Monthly Quarterly Annual One-Time Other If AL filed in compliance with a Commission order, indicate relevant Decision/Resolution #: Decision 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: Upon Commission Approval Estimated system annual revenue effect: (%): Estimated system average rate effect (%): No. of tariff sheets: -52- 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: Service affected and changes proposed 1 : See Attachment A Pending advice letters that revise the same tariff sheets: None 1 Discuss in AL if more space is needed.

16 Protests and all other correspondence regarding this AL are due no later than 20 days after the date of this filing, unless otherwise authorized by the Commission, and shall be sent to: CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, California Russell G. Worden Managing Director, State Regulatory Operations Southern California Edison Company 8631 Rush Street Rosemead, California Telephone: (626) Facsimile: (626) Laura Genao Managing Director, State Regulatory Affairs c/o Karyn Gansecki Southern California Edison Company 601 Van Ness Avenue, Suite 2030 San Francisco, California Facsimile: (415)

17 Public Utilities Commission 3647-E Attachment A Cal. P.U.C. Sheet No. Title of Sheet Cancelling Cal. P.U.C. Sheet No. Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E* Rule 21 Original E Original E Rule 21 Original E Original E Rule 21 Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Original E Rule 21 Original E Rule 21 Original E Rule 21 Original E Rule 21 Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Rule 21 Revised E Revised E Table of Contents Revised E Revised E Table of Contents Revised E 1

18 Southern California Edison Revised Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No E Rule 21 Sheet 148 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 2. Prevention of Interference i. Fixed Power Factor (T) 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 +/ (0.85 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 +/ (0.90 Lagging to 0.90 Leading) down to 20% rated power based on available reactive power j. Dynamic Volt/Var Operations The Smart Inverter shall be capable of operating dynamically within a power factor range of +/ 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 Distribution Provider. The Smart Inverter shall be capable of providing dynamic reactive power compensation (dynamic Volt/Var operation) within the following constraints: 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. 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. 148C12 Resolution E-4898

19 Southern California Edison Revised Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No E Rule 21 Sheet 150 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 2. Prevention of Interference 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. 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. l. Frequency-Watt Requirements 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. Smart inverters shall reduce their real power production as a function of system frequency in accordance with the following: (T) (N) (N) 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) 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. 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. 150C15 Resolution E-4898

20 Southern California Edison Revised Cal. PUC Sheet No E** Rosemead, California (U 338-E) Cancelling Original Cal. PUC Sheet No E Rule 21 Sheet 151 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 2. Prevention of Interference Figure Hh-2 illustrated this requirement for three levels of output power. Figure Hh-2 is for illustration purpose only. (N) (N) Open loop response time for Frequency-Watt shall be 5 seconds Figure Hh-2: Active power as a function of system frequency (T) m. Voltage-Watt Default Settings Requirements 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 Phase 3 Smart Inverter Function Advice Letter (AL 3647-E) was made effective by the Commission. 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: volts on a 120 volts nominal), the active power output produced by the Smart Inverter shall be reduced at a rate of 50% of real power nameplate rating per one percent of nominal voltage. Figure Hh-3 Volt-Watt Requirements illustrate the required rate of reduction. When the measured voltage is greater than 108% of nominal voltage (Example: volts on a 120 volts nominal), the active power output produced by the Smart Inverter shall be reduced to 0 watts. (T) (N) (N) 151C23 Resolution E-4898

21 Southern California Edison Original Cal. PUC Sheet No E* Rosemead, California (U 338-E) Cancelling Cal. PUC Sheet No. Rule 21 Sheet 152 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 2. Prevention of Interference Figure Hh-3: Volt-Watt Requirements n. Set Active Power Level Mode Function The utilization of this function is optional and allowed upon mutual agreement with the Distribution Provider and the Applicant. o. Dynamic Reactive Power Support Function The utilization of this function is optional and allowed upon mutual agreement with the Distribution Provider and the Applicant. (N) (N) 152C22 Resolution E-4898

22 Southern California Edison Original Cal. PUC Sheet No E* Rosemead, California (U 338-E) Cancelling Cal. PUC Sheet No. Rule 21 Sheet 153 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 2. Prevention of Interference p. 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: Table Hh-4: Default Activation States for Phase 1 Functions Anti-islanding Function State Activated Low/High Voltage Ride Through Low/High Frequency Ride Through Dynamic Volt/Var operations Ramp rates Fixed power factor Reconnect by soft-start methods Frequency/Watt Volt/Watt Set Active Power Function Mode(Optional) Dynamic Reactive Power Support Mode (Optional) Activated Activated Activated Activated Deactivated Activated Activated Activated Activated under mutual agreement Activated under mutual agreement 153C21 Resolution E-4898

23 Southern California Edison Revised Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No E Rule 21 Sheet 154 (T) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 2. Prevention of Interference These default activation states may be modified by mutual agreement between Distribution Provider and Producer. q. Load Shedding or Transfer (T) 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 Generation 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 predisturbance 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 gridinteractive 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. 154C15 Resolution E-4898

24 Southern California Edison Revised Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No E Rule 21 Sheet 155 (T) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 4. Supplemental Generating Facility Requirements 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 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 standard. 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 Facility i ; or (iii) other communication options as mutually agreed to by Applicant and Distribution Provider. 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 (i.e., Smart Energy Profile 2.0 (SEP 2)) as defined in the California IEEE 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 (T) (N) (N) (N) (N) i Communication utilizing this aggregator action is not permitted at this time. 155C18 Resolution E-4898

25 Southern California Edison Revised Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No E Rule 21 Sheet 156 (T) Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 5. Communication Requirements 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 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 industryrecognized communication protocol certification test standard. Each event is composed of modifications to each, selected group of, or all of the following Smart Inverter function: (N) (N) 156C17 Resolution E-4898

26 Southern California Edison Original Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Cal. PUC Sheet No. Rule 21 Sheet 157 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 6. Scheduling Capability Requirements Modifications to the voltage and reactive set-points of the Dynamic volt/var function. Modification to the normal ramp-up rate and reconnect ramp-up rate set-points. 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 with no unreasonable delay. 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. 157C9 Resolution E-4898

27 Southern California Edison Original Cal. PUC Sheet No E Rosemead, California (U 338-E) Cancelling Cal. PUC Sheet No. Rule 21 Sheet 158 Hh. SMART INVERTER GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS 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 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 standard. The Smart Inverter shall have the capability to communicate its performance information including: 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. Phase measured at the AC terminals of the Smart Inverter (volts) e. 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 energystorage. Available kwh 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. 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: 158C9 Resolution E-4898