PRC-002-4 – Disturbance Monitoring and Reporting Requirements
PRC-002-4 – Disturbance Monitoring and Reporting Requirements
Purpose
To have adequate data available to facilitate analysis of Bulk Electric System (BES) Disturbances.
Applicability
4.1. Functional Entities:
4.1.1. Reliability Coordinator
4.1.2. Transmission Owner
4.1.3. Generator Owner
Effective Date
See Implementation Plan
Requirements and Measures
R1. Each Transmission Owner shall: [Violation Risk Factor: Lower] [Time Horizon: Longterm Planning]
1.1. Identify BES buses for which sequence of events recording (SER) and fault recording (FR) data is required by using the methodology in PRC-002-4, Attachment 1.
1.2. Notify the other owners of BES Elements directly connected1 to those BES buses, that SER or FR data is required for those BES Elements, only if the Transmission Owner who identified the BES buses in Part 1.1 does not have SER or FR data. This notification is required within 90 calendar days of completion of Part 1.1.
1.3. Re-evaluate all BES buses at least once every five calendar years in accordance with Part 1.1 and notify other owners in accordance with Part 1.2.
M1. The Transmission Owner for Requirement R1, Part 1.1 has a dated (electronic or hard copy) list of BES buses for which SER and FR data is required, identified in accordance with PRC-002-4, Attachment 1; has dated (electronic or hard copy) evidence that it notified other owners in accordance with Requirement R1, Part 1.2; and evidence that all BES buses have been re-evaluated within the required intervals under Requirement R1, Part 1.3.
R2. Each Transmission Owner and Generator Owner shall have SER data for circuit breaker position (open/close) for each circuit breaker it owns directly connected to the BES buses identified in Requirement R1 and associated with the BES Elements at those BES buses. [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
1 For the purposes of this standard, “directly connected” BES Elements are BES Elements connected at the same voltage level within the same physical location sharing a common ground grid with the BES bus identified under Attachment 1. Transformers that have a low-side operating voltage of less than 100 kV are excluded.
M2. The Transmission Owner or Generator Owner has evidence (electronic or hard copy) of SER data for circuit breaker position as specified in Requirement R2. Evidence may include, but is not limited to: (1) documents describing the device interconnections and configurations which may include a single design standard as representative for common installations; or (2) actual data recordings; or (3) station drawings.
R3. Each Transmission Owner and Generator Owner shall have FR data to determine the following electrical quantities for each triggered FR for the BES Elements it owns directly connected to the BES buses identified in Requirement R1: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
3.1. Phase-to-neutral voltage for each phase of each specified BES bus.
3.2. Each phase current and the residual or neutral current for the following BES Elements:
3.2.1. Transformers that have a low-side operating voltage of 100 kV or above.
3.2.2. Transmission Lines.
M3. The Transmission Owner or Generator Owner has evidence (electronic or hard copy) of FR data that is sufficient to determine electrical quantities as specified in Requirement R3. Evidence may include, but is not limited to: (1) documents describing the device specifications and configurations which may include a single design standard as representative for common installations; or (2) actual data recordings or derivations; or (3) station drawings.
R4. Each Transmission Owner and Generator Owner shall have FR data as specified in Requirement R3 that meets the following: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
4.1. A single record or multiple records that include:
• A pre-trigger record length of at least two cycles and a total record length of at least 30 cycles for the same trigger point, or
• At least two cycles of the pre-trigger data, the first three cycles of the post trigger data, and the final cycle of the fault as seen by the fault recorder.
4.2. A minimum recording rate of 16 samples per cycle.
4.3. Trigger settings for at least the following:
4.3.1. Neutral (residual) overcurrent.
4.3.2. Phase under voltage or overcurrent.
M4. The Transmission Owner or Generator Owner has evidence (electronic or hard copy) that FR data meets Requirement R4. Evidence may include, but is not limited to: (1) documents describing the device specification (R4, Part 4.2) and device configuration or settings (R4, Parts 4.1 and 4.3), or (2) actual data recordings or derivations.
R5. Each Reliability Coordinator shall: [Violation Risk Factor: Lower] [Time Horizon: Longterm Planning]
5.1. Identify BES Elements for which dynamic Disturbance recording (DDR) data is required, including the following:
5.1.1. Generating resource(s) with:
5.1.1.1. Gross individual nameplate rating greater than or equal to 500 MVA.
5.1.1.2. Gross individual nameplate rating greater than or equal to 300 MVA where the gross plant/facility aggregate nameplate rating is greater than or equal to 1,000 MVA.
5.1.2. Any one BES Element that is part of a stability (angular or voltage) related System Operating Limit (SOL).
5.1.3. Each terminal of a high voltage direct current (HVDC) circuit with a nameplate rating greater than or equal to 300 MVA, on the alternating current (AC) portion of the converter.
5.1.4. One or more BES Elements that are part of an Interconnection Reliability Operating Limit (IROL).
5.1.5. Any one BES Element within a major voltage sensitive area as defined by an area with an in-service undervoltage load shedding (UVLS) program.
5.2. Identify a minimum DDR coverage, inclusive of those BES Elements identified in Part 5.1, of at least:
5.2.2. One BES Element per 3,000 MW of the Reliability Coordinator’s historical simultaneous peak System Demand.
5.3. Notify all owners of identified BES Elements, within 90 calendar days of completion of Part 5.1, that their respective BES Elements require DDR data.
5.4. Re-evaluate all BES Elements within its Reliability Coordinator Area at least once every five calendar years in accordance with Parts 5.1 and 5.2, and notify owners in accordance with Part 5.3.
M5. The Reliability Coordinator has a dated (electronic or hard copy) list of BES Elements for which DDR data is required, developed in accordance with Requirement R5, Part 5.1 and Part 5.2; and re-evaluated in accordance with Part 5.4. The Reliability Coordinator has dated evidence (electronic or hard copy) that each Transmission Owner or Generator Owner has been notified in accordance with Requirement 5, Part 5.3. Evidence may include, but is not limited to: letters, emails, electronic files, or hard copy records demonstrating transmittal of information.
R6. Each Transmission Owner shall have DDR data to determine the following electrical quantities for each BES Element it owns for which it received notification as identified in Requirement R5: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
6.1. One phase-to-neutral or positive sequence voltage.
6.2. The phase current for the same phase at the same voltage corresponding to the voltage in Requirement R6, Part 6.1, or the positive sequence current.
6.3. Real Power and Reactive Power flows expressed on a three phase basis corresponding to all circuits where current measurements are required.
6.4. Frequency of any one of the voltage(s) in Requirement R6, Part 6.1.
M6. The Transmission Owner has evidence (electronic or hard copy) of DDR data to determine electrical quantities as specified in Requirement R6. Evidence may include, but is not limited to: (1) documents describing the device specifications and configurations, which may include a single design standard as representative for common installations; or (2) actual data recordings or derivations; or (3) station drawings.
R7. Each Generator Owner shall have DDR data to determine the following electrical quantities for each BES Element it owns for which it received notification as identified in Requirement R5: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
7.1. One phase-to-neutral, phase-to-phase, or positive sequence voltage at either the generator step-up transformer (GSU) high-side or low-side voltage level.
7.2. The phase current for the same phase at the same voltage corresponding to the voltage in Requirement R7, Part 7.1, phase current(s) for any phase-to-phase voltages, or positive sequence current.
7.3. Real Power and Reactive Power flows expressed on a three phase basis corresponding to all circuits where current measurements are required.
7.4. Frequency of at least one of the voltages in Requirement R7, Part 7.1.
M7. The Generator Owner has evidence (electronic or hard copy) of DDR data to determine electrical quantities as specified in Requirement R7. Evidence may include, but is not limited to: (1) documents describing the device specifications and configurations, which may include a single design standard as representative for common installations; or (2) actual data recordings or derivations; or (3) station drawings.
R8. Each Transmission Owner and Generator Owner responsible for DDR data for the BES Elements identified in Requirement R5 shall have continuous data recording and storage. If the equipment was installed prior to the effective date of the Reliability Standard PRC-002-22 and is not capable of continuous recording, triggered records must meet the following: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
8.1. Triggered record lengths of at least three minutes.
8.2. At least one of the following three triggers:
2 The effective date of the Reliability Standard PRC-002-2 in the U.S. was July 1, 2016. The effective date may be different for other jurisdictions.
M8. Each Transmission Owner and Generator Owner has dated evidence (electronic or hard copy) of data recordings and storage in accordance with Requirement R8. Evidence may include, but is not limited to: (1) documents describing the device specifications and configurations, which may include a single design standard as representative for common installations; or (2) actual data recordings.
R9. Each Transmission Owner and Generator Owner responsible for DDR data for the BES Elements identified in Requirement R5 shall have DDR data that meet the following: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
9.1. Input sampling rate of at least 960 samples per second.
9.2. Output recording rate of electrical quantities of at least 30 times per second.
M9. The Transmission Owner or Generator Owner has evidence (electronic or hard copy) that DDR data meets Requirement R9. Evidence may include, but is not limited to: (1) documents describing the device specification, device configuration, or settings (R9, Part 9.1; R9, Part 9.2); or (2) actual data recordings (R9, Part 9.2).
R10. Each Transmission Owner and Generator Owner shall time synchronize all SER and FR data for the BES buses identified in Requirement R1 and DDR data for the BES Elements identified in Requirement R5 to meet the following: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
10.1. Synchronization to Coordinated Universal Time (UTC) with or without a local time offset.
10.2. Synchronized device clock accuracy within ± 2 milliseconds of UTC.
M10. The Transmission Owner or Generator Owner has evidence (electronic or hard copy) of time synchronization described in Requirement R10. Evidence may include, but is not limited to: (1) documents describing the device specification, configuration, or setting; (2) time synchronization indication or status; or 3) station drawings.
R11. Each Transmission Owner and Generator Owner shall provide, upon request, all SER and FR data for the BES buses identified in Requirement R1 and DDR data for the BES Elements identified in Requirement R5 to the Reliability Coordinator, Regional Entity, or NERC in accordance with the following: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
11.1. Data will be retrievable for the period of 10 calendar days, inclusive of the day the data was recorded.
11.2. Data subject to Part 11.1 will be provided within 30 calendar days of a request unless an extension is granted by the requestor.
11.3. SER data will be provided in ASCII Comma Separated Value (CSV) format following Attachment 2.
11.4. FR and DDR data will be provided in electronic files that are formatted in conformance with C37.111, (IEEE Standard Common Format for Transient Data Exchange (COMTRADE), revision C37.111-1999 or later.
11.5. Data files will be named in conformance with C37.232, IEEE Standard for Common Format for Naming Time Sequence Data Files (COMNAME), revision C37.232-2011 or later.
M11. The Transmission Owner or Generator Owner has evidence (electronic or hard copy) that data was submitted upon request in accordance with Requirement R11. Evidence may include, but is not limited to: (1) dated transmittals to the requesting entity with formatted records; (2) documents describing data storage capability, device specification, configuration or settings; or (3) actual data recordings.
R12. Each Transmission Owner and Generator Owner shall, within 90 calendar days of the discovery of a failure of the recording capability for the SER, FR or DDR data, either: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
• Restore the recording capability, or
• Submit a Corrective Action Plan (CAP) to the Regional Entity and implement it.
M12.The Transmission Owner or Generator Owner has dated evidence (electronic or hard copy) that meets Requirement R12. Evidence may include, but is not limited to: (1) dated reports of discovery of a failure, (2) documentation noting the date the data recording was restored, (3) SCADA records, or (4) dated CAP transmittals to the Regional Entity and evidence that it implemented the CAP.
R13. Each Transmission Owner and Generator Ownershall: [Violation Risk Factor: Lower] [Time Horizon: Long-term Planning]
13.1. Within three (3) calendar years of completing a re-evaluation or receiving notification under Requirement R1, Part 1.3, have SER or FR data as applicable for BES Elements directly connected to the identified BES buses.
13.2. Within three (3) calendar years of receiving notification under Requirement R5, Part 5.4, have DDR data for BES Elements identified during the re-evaluation.
M13. The Transmission Owner or Generator Owner has dated evidence (electronic or hard copy) that meets Requirement R13. Evidence may include, but is not limited to: letters, emails, drawings, or settings files.
Compliance
1. Compliance Monitoring Process
1.1. Compliance Enforcement Authority:
1.2. As defined in the NERC Rules of Procedure, “Compliance Enforcement Authority” means NERC or the Regional Entity in their respective roles of monitoring and enforcing compliance with the NERC Reliability Standards. Data Retention: The following evidence retention periods identify the period of time an entity is required to retain specific evidence to demonstrate compliance. For instances where the evidence retention period specified below is shorter than the time since the last audit, the Compliance Enforcement Authority may ask an entity to provide other evidence to show that it was compliant for the full time period since the last audit.
The Transmission Owner, Generator Owner, and Reliability Coordinator shall keep data or evidence to show compliance as identified below unless directed by its Compliance Enforcement Authority to retain specific evidence for a longer period of time as part of an investigation:
The Transmission Owner shall retain evidence of Requirement R1, Measure M1 for five calendar years.
The Reliability Coordinator shall retain evidence of Requirement R5, Measure M5 for five calendar years.
The Transmission Ownershall retain evidence of Requirement R6, Measure M6 for three calendar years.
The Generator Owner shall retain evidence of Requirement R7, Measure M7 for three calendar years.
The Transmission Owner and Generator Owner shall retain evidence of requested data provided as per Requirements R2, R3, R4, R8, R9, R10, R11, and R12, Measures M2, M3, M4, M8, M9, M10, M11, and M12 for three calendar years.
The Transmission Owner and Generator Owner as applicable shall retain evidence of Requirement R13, Measure 13 for five calendar years.
If a Transmission Owner, Generator Owner, or Reliability Coordinator is found non- compliant, it shall keep information related to the non-compliance until mitigation is completed and approved or for the time specified above, whichever is longer.
The Compliance Enforcement Authority shall keep the last audit records and all requested and submitted subsequent audit records.
1.3. Compliance Monitoring and Enforcement Program:
• Compliance Audit
• Self-Certification
• Spot Checking
• Compliance Violation Investigation
• Self-Reporting
• Complaints
1.4. Additional Compliance Information
None.
Attachment 1
Methodology for Selecting Buses for Capturing Sequence of Events Recording (SER) and Fault Recording (FR) Data
(Requirement R1)
To identify monitored BES buses for sequence of events recording (SER) and Fault recording (FR) data required by Requirement 1, each Transmission Owner shall follow sequentially, unless otherwise noted, the steps listed below:
Step 1. Determine a complete list of BES buses that it owns.
For the purposes of this standard, a single BES bus includes physical buses with breakers connected at the same voltage level within the same physical location sharing a common ground grid. These buses may be modeled or represented by a single node in fault studies. For example, ring bus or breaker-and-a-half bus configurations are considered to be a single bus.
Step 2. Reduce the list to those BES buses that have a maximum available calculated three phase short circuit MVA of 1,500 MVA or greater. If there are no buses on the resulting list, proceed to Step 7.
Step 3. Determine the 11 BES buses on the list with the highest maximum available calculated three phase short circuit MVA level. If the list has 11 or fewer buses, proceed to Step 7.
Step 4. Calculate the median MVA level of the 11 BES buses determined in Step 3.
Step 5. Multiply the median MVA level determined in Step 4 by 20 percent.
Step 6. Reduce the BES buses on the list to only those that have a maximum available calculated three phase short circuit MVA higher than the greater of:
• 1,500 MVA or
• 20 percent of median MVA level determined in Step 5.
Step 7. If there are no BES buses on the list: the procedure is complete and no FRand SER data will be required. Proceed to Step 9.
If the list has 1 or more but less than or equal to 11 BES buses: FR and SER data is required at the BES bus with the highest maximum available calculated three phase short circuit MVA as determined in Step 3.
During re-evaluation per Requirement R1, Part 1.3, if the three phase short circuit MVA of the newly identified BES bus is within 15% of the three phase short circuit MVA of the currently applicable BES bus with SER and FR data then it is not necessary to change the applicable BES bus. Proceed to Step 9.
If the list has more than 11 BES buses: SER and FR data is required on at least the 10 percent of the BES buses determined in Step 6 with the highest maximum available calculated three phase short circuit MVA. Proceed to Step 8.
Step 8. SER and FR data is required at additional BES buses on the list determined in Step 6. The aggregate of the number of BES buses determined in Step 7 and this Step will be at least 20 percent of the BES buses determined in Step 6.
The additional BES buses are selected, at the Transmission Owner’s discretion,to provide maximum wide-area coverage for SER and FR data. The following BES bus locations are recommended:
• Electrically distant buses or electrically distant from other DME devices.
• Voltage sensitive areas.
• Cohesive load and generation zones.
• BES buses with a relatively high number of incident Transmission circuits.
• BES buses with reactive power devices.
• Major Facilities interconnecting outside the Transmission Owner’s area.
Step 9. The list of monitored BES buses for SER and FR data for Requirement R1 is the aggregate of the BES buses determined in Steps 7 and 8.
Attachment 2
Sequence of Events Recording (SER) Data Format
(Requirement R11, Part 11.3)
Date, Time, Local Time Code, Substation, Device, State3
08/27/13, 23:58:57.110, -5, Sub 1, Breaker 1, Close
08/27/13, 23:58:57.082, -5, Sub 2, Breaker 2, Close
08/27/13, 23:58:47.217, -5, Sub 1, Breaker 1, Open
08/27/13, 23:58:47.214, -5, Sub 2, Breaker 2, Open
3 “OPEN” and “CLOSE” are used as examples. Other terminology such as TRIP, TRIP TO LOCKOUT, RECLOSE, etc. is also acceptable.
