Project Generator Verification and Implementation Plan for PRC-019-2, PRC and MOD Compliance Fall Workshop October 12, 2017

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1 Project Generator Verification and Implementation Plan for PRC-019-2, PRC and MOD Compliance Fall Workshop October 12, 2017

2 Objectives Purpose for Project Generator Verification Review of existing standard revised/retired New standards as part of project Implementation Plan PRC PRC MOD Audit Approach 2

3 Purpose: Project Generator Verification Purpose/Industry Need: To ensure that generators will not trip off-line during specified voltage and frequency excursions or as a result of improper coordination between generator protective relays and generator voltage regulator controls and limit functions (such coordination will include the generating unit s capabilities) To ensure that generator models accurately reflect the generator s capabilities and operating characteristics 3

4 Project Generator Verification Revised standards MOD Verification of Real Power Capability: (Retired 6/30/2016) (GO) MOD Verification of Reactive Power Capability: (Retired 6/30/2016) (GO) MOD Verification and Data Reporting of Generator Real and Reactive Power and Synchronous Condenser Reactive Power Capability (*Effective Date 7/1/16) New standards PRC Coordination of Generator Voltage Regulator Controls with Unit Capabilities and Protection (*Effective Date 7/1/16) PRC Generator Performance During Frequency and Voltage Excursions (*Effective Date 7/1/16) MOD Verification of Models and Data for Generator Excitation System Functions (R1, and R3 through R6 Effective Date 7/1/2014) (R2 *Effective Date 7/1/18) MOD Verification of Models and Data for Unit Frequency Response (R1, and R3 through R6 Effective Date 7/1/2014) (R2 *Effective Date 7/1/18) 4

5 Project Generator Verification MOD Verification and Data Reporting Synchronous Condensers Project Generator Verification PRC PRC Coordination Performance MOD MOD Verification 5

6 PRC Background PRC was created under NERC Generator Verification The purpose is to verify coordination of generator (or plant) voltage regulator controls and limit function PRC is a minor change to address distributed generation resources due to revision of BES I4 definition Applicability to Generating Owner and Transmission Owner Regulatory Approval May 27, 2014 (Phased in over Five Years) 6

7 PRC Facilities applicable Facility shall mean any one of the following: Individual generating unit > 20 MVA (gross nameplate) directly connected to the BES Generating plant/ Facility consisting of one or more units that are connected to the Bulk Electric System at a common bus with total generation greater than 75 MVA (gross aggregate nameplate rating) Includes individual units of dispersed power resources identified in Inclusion I4 of the BES definition where voltage control is performed solely at the individual generating unit Any generator, regardless of size, that is a black start unit material to and designated as part of a TOP s restoration plan 7

8 PRC Important Dates FERC order issued: March 20, 2014 Regulatory Approval: May 27, 2014 Effective Date: By the first day of the first calendar quarter, two calendar years following regulatory approval leads to an effective date of July 1, 2016 (Phased in over 5 years) 8

9 PRC Requirements R1 and R2 At a maximum of every five calendar years (R1), and within 90 days following changes that will affect the coordination (R2), coordinate the voltage regulating system controls Verify in-service limiters are set to operate before the Protection System to avoid disconnecting the generator unnecessarily Verify Protection System devices are set to isolate equipment when operating conditions exceed equipment capability or stability limits 9

10 Examples of Coordination The evidence of coordination associated with Requirement R1 may be in the form of: P-Q Diagram (Example in Attachment 1), or R-X Diagram (Example in Attachment 2), or Inverse Time Diagram (Example in Attachment 3) or Equivalent tables or other evidence 10

11 Examples of Coordination Equipment limits, types of limiters and protection functions which could be coordinated include (but are not limited to): Field over-excitation limiter and associated protection functions Inverter over current limit and associated protection functions Field under-excitation limiter and associated protection functions Generator or synchronous condenser reactive capabilities Volts per hertz limiter and associated protection functions Stator over-voltage protection system settings Generator and transformer volts per hertz capability Time vs. field current or time vs. stator current 11

12 PRC Implementation Plan (Five Years) 1st day of first calendar quarter 2 years following regulatory approval July 1, percent of applicable Facilities July 1, percent of applicable Facilities July 1, percent of applicable Facilities July 1, percent of applicable Facilities 12

13 PRC Audit Approach List of applicable Facilities Demonstrate percentages verified are in accordance with the implementation plan Provide dated documents which applicable Facilities were verified 13

14 PRC Background PRC was created under NERC Generator Verification The purpose is to ensure that generators remain connected during defined frequency and voltage excursions PRC is a minor change to address distributed generation resources due to revision of BES I4 definition Applicability to Generating Owner Regulatory Approval May 27, 2014 (Phased in over Five Years) 14

15 PRC R1 and Measure R1: Set overfrequency and underfrequency trip relays such that the relaying does not trip the generator within the no trip zone of PRC-024 Attachment 1, subject to the following exceptions: Loss of synchronism (out-of-step) Needed to clear a system fault Equipment limitations (within the no trip zone ) documented and communicated in accordance with R3 M1: Each GO shall have evidence that generator frequency protective relays have been set in accordance with R1 such as: Setting and calibration sheets 15

16 PRC R2 and Measure R2: Set overvoltage and undervoltage trip relays such that the relaying does not trip the generator within the no trip zone of PRC-024 Attachment 2, subject to the following exceptions: loss of synchronism (out-of-step) Needed to clear a system fault Equipment limitations (within the no trip zone ) documented and communicated in accordance with R3 In accordance with a Special Protection System (SPS) or Remedial Action Scheme (RAS) M2: Each Generator Owner shall have evidence that generator voltage protective relays have been set in accordance with Requirement R2 such as dated setting sheets, voltage-time curves, calibration sheets, coordination plots, dynamic simulation studies or other documentation 16

17 PRC R3 and R4 R3: Document and communicate limitations to the Planning Coordinator (PC) and Transmission Planner (TP) within 30 days following any change in limitations (including removal of previous limitations) R4: Provide trip settings to the PC or TP within 60 days upon request (and within 60 days of any change if previously submitted to PC or TP) 17

18 PRC Implementation Plan 1st day of first calendar quarter 2 years following regulatory approval July 1, percent of applicable Facilities July 1, percent of applicable Facilities July 1, percent of applicable Facilities July 1, percent of applicable Facilities 18

19 PRC Audit Approach List of applicable Facilities Demonstrate percentages verified are in accordance with the implementation plan Provide documents demonstrating which Facilities were verified Dated setting sheets, voltage-time curves, calibration sheets, coordination plots, dynamic simulation studies or other documentation 19

20 MOD Implementation Plan Purpose To ensure that accurate information on generator gross and net Real and Reactive Power capability and synchronous condenser Reactive Power capability is available for planning models used to assess Bulk Electric System (BES) reliability Applicability Generator Owner Transmission Owner that owns synchronous condenser(s) 20

21 MOD Requirements R1 and R2 Verification of the Real Power capability accordance with Attachment 1 and submit a completed Attachment 2 to its Transmission Planner within 90 calendar days Verification of the Reactive Power capability accordance with Attachment 1 and submit a completed Attachment 2 to its Transmission Planner within 90 calendar days 21

22 MOD Measures M1 and M2 Generator Owner will have evidence that it performed the verification, such as a completed Attachment 2, and submitted the information within 90 days to its Transmission Planner Dated electronic mail messages, or Mail receipts 22

23 Audit Approach List of applicable Facilities Demonstrate percentages verified are in accordance with the implementation plan Provide evidence that it performed the verification, such as a completed Attachment 2 and submitted the information to its Transmission Planner 23

24 MOD Implementation Plan 1st day of first calendar quarter 2 years following regulatory approval July 1, percent of applicable Facilities July 1, percent of applicable Facilities July 1, percent of applicable Facilities July 1, percent of applicable Facilities 24

25 Summary 25

26 Questions? Sonny Patel P.E. (813)