ReliabilityFirst Regional Criteria 1 Disturbance Monitoring and Reporting Criteria 1 A ReliabilityFirst Board of Directors approved good utility practice document which are not reliability standards. ReliabilityFirst Regional Criteria may also address issues not within the scope of reliability standards, ReliabilityFirst Regional Criteria may include specific acceptable operating or planning parameters, guides, agreements, protocols or other documents used to enhance the reliability of the regional Bulk Electric System. ReliabilityFirst Regional Criteria will typically provide benefits by promoting more consistent implementation of the NERC reliability standards within the Region. ReliabilityFirst Regional Criteria are not NERC reliability standards, regional reliability standards, or regional variances, and therefore are not enforceable under authority delegated by NERC pursuant to delegation agreements and do not require NERC approval.
A. Introduction 1. Title: Disturbance Monitoring and Reporting Criteria 2. Number: RFC_Criteria_PRC 002 01 3. Purpose: To establish ReliabilityFirst criteria for Disturbance monitoring and reporting to support NERC Reliability Standard PRC-002. 4. Applicability: 4.1 Transmission Owners 4.2 Generator Owners 5. Effective Date: 08/2/2012 B. Criteria 2 C1 Transmission Owners and Generator Owners should ensure that equipment is installed on their respectively owned equipment as recommended below which is capable of sequence of events (SOE) recording that conforms to the following minimum criteria: C1.1 Criteria for location of SOE recording capability C1.1.1 Equipment capable of recording SOE should be installed at any substation or generating plant having any of the following attributes: Substations containing any combination of three or more Elements consisting of Transmission Lines (operated at 200 kv or above) and transformers (having primary and secondary voltage ratings of 200 kv or above). A generating unit step up transformer(s) connected at 200 kv or above to either a generating plant having a single generating unit of 250 MVA or higher nameplate rating or an aggregate plant total nameplate capacity of 750 MVA or higher.. C1.1.2 At locations requiring SOE recording per C1.1.1, the opening and closing of breaker auxiliary contacts should be recorded or the opening and closing of each circuit breaker should be derived for the change in circuit breaker position for each circuit breaker at 200 kv or above, on the following system Elements should be monitored: 2 Time synchronization requirements are specified in NERC PRC-018-1 Transmission Lines operated at 200 kv or BOD Approved: 08/2/2012 Page 2 of
Transmission buses operated at 200 kv or Transformers having primary and secondary voltage rating of 200 kv or Generating unit step up transformers connected at 200 kv or C1.2 SOE recording equipment should be capable of determining and recording the time that an input is received to within ¼ of an electrical cycle (or less) of input change of state. C1.3 SOE recording equipment should have time stamp capability to record seconds to at least three decimal places (i.e. ss.000). C2 Transmission Owners and Generator Owners should ensure that equipment is installed on their respectively owned equipment as recommended below which is capable of Fault recording that conforms to the following minimum criteria: C2.1 Criteria for location of Fault recording capability C2.1.1 Equipment capable of Fault recording should be installed at any substation or generating plant having any of the following attributes: Substations containing any combination of three or more Elements consisting of Transmission Lines (operated at 200 kv or above) and transformers (having primary and secondary voltage ratings of 200 kv or above). A generating unit step up transformer(s) connected at 200 kv or above to either a generating plant having a single generating unit of 250 MVA or higher nameplate rating or an aggregate plant total nameplate capacity of 750 MVA or higher. C2.1.2 At locations requiring Fault recording per C2.1.1, the electrical quantities on the following system Elements should be monitored: Transmission Lines operated at 200 kv or Transmission buses operated at 200 kv or Transformers having primary and secondary voltage rating of 200 kv or Generating unit step up transformers connected at 200 kv or These transformers may be monitored at either voltage level. If the generating unit step up transformer is monitored at the lower voltage level it should also record BOD Approved: 08/2/2012 Page 3 of
the transformer neutral current in addition to quantities specified in C2.2. C2.2 Electrical quantities to be recorded for each monitored Element should be sufficient to determine the following: C2.2.1 The three phase to neutral voltages on a grounded system or the three phase to phase voltages on an ungrounded system (e.g. if a Generation Owner opts to monitor the generating unit step up transformer on the delta side) on: C2.2.1.1 C2.2.1.2 C2.2.1.3 The monitored line or outer buses for breaker-anda-half bus arrangements, or The monitored line for ring bus arrangement, or The monitored bus for other bus arrangements. C2.2.2 The three phase currents and the residual or neutral currents of each monitored line and transformer C2.2.3 Polarizing currents, if used. C2.2.4 Frequency. C2.2.5 Megawatts and megavars. C2.3 Technical criteria, include the following: C2.3.1 Fault recording equipment should record at least two-cycles of pre-trigger data. C2.3.2 Fault recording equipment should record any one of the following: A post trigger record length of at least 50 cycles, or The first three cycles of an event and the final cycle of an event, using either a single continuous record or multiple triggered records. C2.3.3 Fault recording equipment should have a minimum recording rate of 16 samples per cycle. C2.3.4 Fault recording equipment triggering parameters should include one or more of following analog values: Negative sequence voltage. Negative sequence current. Zero sequence current (tertiary or residual). Under voltage. BOD Approved: 08/2/2012 Page 4 of
Over voltage. Over current. and also one or more of the following digital values: DC trip buses. Circuit breaker contact opening. Protective relay operation. C3 Transmission Owners and Generator Owners should ensure that equipment is installed on their respectively owned equipment as recommended below which is capable of dynamic disturbance recording and conforms to the following minimum criteria: C3.1 Transmission Owners should ensure C3.1.1 Equipment capable of dynamic disturbance recording should be located at Transmission Substations as follows. However, a Dynamic Disturbance Recorder (DDR) which is recommended at a Transmission Substation per criteria C3.1.1.1 through C3.1.1.5 should be considered optional if a DDR (meeting all criteria of C3.3 through C3.4) is found to be located one or two Transmission Substations away at a common voltage level. C3.1.1.1 C3.1.1.2 C3.1.1.3 C3.1.1.4 C3.1.1.5 Transmission Substations having a total of seven or more Transmission Lines (excluding transformers) connected at 200 kv or Transmission Substations connecting to another Balancing Authority or Reliability Coordinator at 345 kv or At least one DDR within a major metro area having a total maximum load of 2,500 MW or higher. All Elements at 345 kv or above associated with Interconnection Reliability Operating Limits (IROLs). At least one DDR within an area that has an Under- Voltage Load Shedding program installed to which NERC PRC-021 applies. C3.1.2 DDRs should record at least one phase of the following system Elements connected to the Transmission Substations referenced in C3.1.1. Voltage and/or current recordings should be from the same phase(s). C3.1.2.1 All Transmission Lines connected at 200 kv or BOD Approved: 08/2/2012 Page 5 of
C3.1.2.2 Transformers with both primary and secondary windings connected at 200 kv or C3.2 Generator Owners should ensure that: C3.2.1 Equipment capable of dynamic disturbance recording should record at least one phase of the high or low side of each generating unit step up transformer(s) greater than 250 MVA nameplate rating connected at 200 kv and above for at least the following: C3.2.1.1 C3.2.1.2 A single generating unit of 1,000 MVA or higher nameplate rating or Multiple generating units in a plant having a total nameplate capacity of 2,000 MVA or higher. C3.3 Electrical quantities to be recorded for each monitored Element should be sufficient to determine the following: C3.3.1 Bus Voltage (at least one per voltage level of 200 kv or above at each DDR location). C3.3.2 Frequency (at least one per DDR location). C3.3.3 Line Current. C3.3.4 MW and MVAR flows expressed on a three-phase basis (per each monitored line or transformer). C3.4 DDRs should have the following technical criteria: C3.4.1 Any new DDRs should have the capability of continuous recording. C3.4.2 Existing DDRs which do not have continuous recording capability should be triggered according to the following: C3.4.2.1 C3.4.2.2 C3.4.2.3 DDRs should be capable of rate-of-change of frequency and rate-of-change of voltage triggers. Oscillation triggers, if available, should be set to trigger for low frequency oscillations in 0.1 to 4.0 Hz range. DDRs should be capable of recording minimum record lengths of not less than three minutes. BOD Approved: 08/2/2012 Page 6 of
C3.4.3 Sample data at a rate of at least 60 samples per second and should record the RMS value of electrical quantities at a rate of at least 6 records per second. C4 Transmission Owners and Generator Owners should ensure that the DME data from the DME on their respectively owned equipment is retrieved and reported as follows: C. Measures C4.1 For power system Faults, Protection System operations, and operating switching errors that causes Disturbances, the Disturbance Monitoring Equipment (DME) owner (Transmission Owner or Generator Owner) should collect Fault recording and sequence-of-events recording which directly monitors the affected power system Element. C4.2 When requested by ReliabilityFirst Corporation, the DME owner should collect all relevant dynamic disturbance recordings. C4.3 The DME owner should retain all data retrieved in accordance with C4.1 and C4.2 at least until the end of the third calendar year following the event. C4.4 The DME owner should provide all DME data to ReliabilityFirst Corporation within 30 calendar days of a request. C4.5 The data recorded by DME may be recorded in any format, including the device manufacturer s proprietary format. However, the equipment owner should, upon request, furnish the data to ReliabilityFirst Corporation in a format such that any software system capable of viewing and analyzing COMTRADE (IEEE Std. C37.111-17 or successor) files may be used to process and evaluate the data. C4.5.1 Known delays in interposing relays should be reported with the SOE data. C4.6 Data files reported to ReliabilityFirst Corporation should be named in conformance with IEEE C37.232, Recommended Practice for Naming Time Sequence Data Files. M1 M2 M3 The Transmission Owner and Generator Owner should each have evidence that equipment capable of SOE recording is installed at all recommended locations and conforms to the minimum criteria. (C1) The Transmission Owner and Generator Owner should each have evidence that equipment capable of Fault recording is installed at all recommended locations and conforms to the minimum criteria. (C2) The Transmission Owner and Generation Owner should each have evidence that equipment capable of dynamic disturbance recording is installed at all recommended locations and conforms to the minimum criteria. (C3) BOD Approved: 08/2/2012 Page 7 of
M4 The Transmission Owner and Generator Owner should each have evidence that they retained and provided Disturbance data in accordance with the reporting criteria. (C4) D. Definitions The following definition has been extracted from IEEE standards. Substation - As defined by the IEEE C2-2002, (National Electric Safety Code) An enclosed assemblage of equipment, e.g. switches, circuit breakers, buses and transformers, under control of qualified persons, through which electric energy is passed for the purpose of switching or modifying its characteristics. D. IntraRegional Differences None E. Notes Version History Version Date Action Change Tracking 1 st Draft 2 nd Draft 3 rd Draft 4 th Draft 4 th Draft 5 th Draft 6 th Draft 7 th Draft 8 th Draft th Draft th Draft /28/06 Through 10/26/06 11/13/06 Through 12/11/06 01/24/07 Through 02/21/07 05/16/07 Through 05/30/07 06/06/07 Through 06/20/07 0/13/07 Through 10/12/07 11/05/07 Through 12/04/07 01/15/08 Through 02/13/08 03/13/08 Through 04/11/08 06/11/08 Through 06/25/08 06/26/08 Through 07/11/08 Posted for 1 st Comment Period Posted for 2 nd Comment Period Posted for 3 rd Comment Period Posted for 15-Days Prior to Membership Ballot Posted for 15-Day Membership Ballot Posted for 4 th Comment Period Posted for 5 th Comment Period Posted for 6 th Comment Period Posted for 7 th Comment Period Posted for 15-Days Prior to Category Ballot Posted for 15-Day Category Ballot BOD Approved: 08/2/2012 Page 8 of
10 th Draft 11 th Draft 11 th Draft 11 th Draft 11 th Draft RFC_Criteria_PR C-002-RFC-01 10/27/08 Through 11/25/08 02/03/0 Through 02/17/0 02/18/0 Through 03/04/0 Posted for 8 th Comment Period Posted for 15-Days Prior to Category Ballot Posted for 15-Day Category Ballot 05/14/0 ReliabilityFirst Board Approved 07/10/0 Removed (Proposed) from Effective Date section 08/2/12 ReliabilityFirst Board converted to Regional Criterion New naming convention,, removed mandatory language, removed VRFs, VSLs and compliance section BOD Approved: 08/2/2012 Page of