Overview of PRC-002-2 - WECC JSIS PRC-002-2 Briefing.pdf · Overview of PRC-002-2. Project 2007-11 Disturbance Monitoring . June 11-13, 2013 WECC JSIS Salt Lake City

Overview of PRC-002-2 Project 2007-11 Disturbance Monitoring

June 11-13, 2013 WECC JSIS Salt Lake City

RELIABILITY | ACCOUNTABILITY 2

Administrative

• Two-hour webinar held on May 22 High-level overview of revised standard working draft Industry input and feel for proposed requirements Approx. 266 participants at peak, 170 remaining at end of 2-hr webinar

• Upcoming workshops in Eastern and Western Interconnections

July 30 from 1-5PM and July 31 8AM-Noon, Tempe, AZ August 6 from 1-5PM and August 7 from 8AM-Noon, Atlanta, GA


• Initial DT convened in Summer of 2007 • Posting of initial standard draft on February 2, 2009, for 45-day

comment periodDT changes since March, 2009 • Monitoring Value Analysis (MVA) Task Team formed in 2009 to

conduct technical analysis; work completed in 2010 • Completed Response to (2009) Comments in October 2010

• Standards Committee placed Project into informal

development status in the fall of 2010 • Standards Committee returned the Project to formal

development status in January, 2013

History of Drafting Team


Member Registered Entity • Lee Pedowicz, Chair • Frank Ashrafi • Alan Baker • Dan Hansen • Tim Kucey • Steve Myers • Ryan Quint • Jack Soehren • Vladimir Stanisic

• Northeast Power Coordinating Council • Southern California Edison • Florida Power & Light Co. • NRG Energy • PSEG Fossil LLC • ERCOT • Bonneville Power Administration • ITC Holdings Corp. • AESI Inc.

Current DMSDT Membership


• Purpose:

“to establish requirements for recording and reporting sequence of events (SOE) data, fault recording (FR) data, and dynamic disturbance recording (DDR) data to facilitate analysis of Disturbances. This standard will replace PRC-002-1 and PRC-018-1.”

PRC-002-2


• Each Transmission Owner and Generator Owner shall time synchronize all of its Sequence of Events Recordings, Fault Recordings, and Dynamic Disturbance Recordings for the BES bus locations established in Requirements R1 and R9 to within +/- 2 milliseconds of Coordinated Universal Time (UTC), time stamped with or without a local offset.

Accuracy to Universal Time (UTC)


• Each Responsible Entity shall establish a list of monitored BES bus locations for Dynamic Disturbance Recording: A minimum of one Dynamic Disturbance Recording location per 3,000

MW of the Responsible Entity’s historical peak Load.

Generating Plants with a gross plant/facility aggregate nameplate rating of 500 MVA or greater.

Locations necessary to monitor all elements of: o Major transmission interfaces and all permanent Flowgates and major

transmission interfaces in the Eastern Interconnection, o All major transfer paths within the Western Interconnection as defined by

the Regional Entity, or o Major transmission interfaces in the Québec or ERCOT Interconnections.

Dynamic Disturbance Recording (DDR)


• Each Responsible Entity shall establish a list of monitored BES bus locations for Dynamic Disturbance Recording: Both ends of HVDC terminals (back-to-back or each terminal of a DC

circuit) on the AC portion of the converter.

Locations necessary to monitor all elements of Interconnection Reliability Operating Limits.

Any one element within a major voltage sensitive area as defined by an in-service UVLS program.

• The Responsible Entity shall review the list established at least

every five years.

Dynamic Disturbance Recording (DDR)


WECC Entity Est. MW

Peak PMUs/DDRs

Needed Arizona Public Service Company 7,341 2 Nevada Power Company 6,066 2 Salt River Project 6,690 2 Tucson Electric Power Company 3,084 1 California Independent System Operator 48,887 16 Los Angeles Department of Water and Power 6,425 2 Alberta Electric System Operator 10,923 3 Balancing Authority of Northern California 4,500 1 Bonneville Power Administration 9,526 3 British Columbia Hydro and Power Authority 12,089 4 Public Utilities Light Division - IPC 3,677 1 PacifiCorp-East 8,469 2 PacifiCorp-West 3,724 1 Portland General Electric Company 3,869 1 Puget Sound Energy 5,225 1 Public Service Company of Colorado 7,988 2 WAPA Colorado-Missouri Region 4,320 1 WECC Total Peak Load 173,681 57

1 DDR/3000MW Historical Peak Load

NOTE: Location based on PC or RC 57 is minimum # locations required across WECC. WISP covers this requirement easily.


WECC Entity Est. MW

Peak PMUs/DDRs

Needed Arlington Valley LLC (598)* 0 El Paso Electric Company 1,746 0 Griffith Energy LLC (576)* 0 Harquahala L.L.C. (1030)* 0 Imperial Irrigation District 1,012 0 Panda Gila River L.P. (2108)* 0 Public Service Company of New Mexico 2,730 0 WAPA - Lower Colorado Region 1,280 0 Comision Federal de Electricidad 2,400 0 Avista Corp. 2,353 0 City of Tacoma Department of 969 0 NaturEner Power Watch LLC (255)* 0 NorthWestern Energy 1,685 0 PUD No. 1 of Chelan County 691 0 PUD No. 1 of Douglas County 362 0 PUD No. 2 of Grant County GCPD 707 707 0 Seattle Department of Lighting 1,949 0 Sierra Pacific Power Company 2,203 0 Turlock Irrigation District 641 0 Western Area Power Upper Missouri Region 150 0

1 DDR/3000MW Historical Peak Load


• Each Responsible Entity shall establish and make available to the Transmission Owners and Generator Owners the list of Dynamic Disturbance Recording BES bus locations established in Requirement R9 and Elements for which data is to be recorded.

• Each Transmission Owner and Generator Owner shall provide Dynamic Disturbance Recording functionality at the BES bus locations specified by the Responsible Entity and record data on the specified Elements.

DDR Responsibility


• Each Transmission Owner shall record electrical quantities of each Element identified by its Responsible Entity in order to determine the following Dynamic Disturbance Recording data: Single phase-to-neutral or positive sequence voltages where any normal

system configurations do not remove all voltage sources from service simultaneously.

The phase current on the same phase at the same voltage or positive sequence current.

Real Power and Reactive Power (MW and MVAR) flows expressed on a three-phase basis corresponding to all circuits where current measurements are required.

Frequency calculated from all voltages measured at the location.

DDR Recordings - 1


• Each Generator Owner shall record electrical quantities of each Element identified by its Responsible Entity in order to determine the following Dynamic Disturbance Recording data: Any one phase-to-neutral, phase-to-phase, or positive sequence voltage

at either the GSU’s high side or low side voltage level. The voltage can be the high side connecting bus voltage or the generator bus voltage.

The phase current on the same phase at the same, two phase currents for phase-to-phase voltages, or positive sequence current.

Real Power and Reactive Power (MW and MVAR) flows expressed on a three-phase basis corresponding to all circuits where current measurements are required.

Frequency calculated from all voltages measured at the location.

DDR Recordings - 2


• Each Transmission Owner and Generator Owner shall ensure its Dynamic Disturbance Recording data, for the BES bus locations and Elements specified by the Responsible Entity, conforms to the following technical specifications: Input sampling rate of at least 960 samples per second. Output reporting rate of electrical quantities of at least 30 times per

second.

• Continuous DDR and storage capability required unless DDR equipment used was installed prior to the effective date of this Standard.

DDR Recordings - 3


• Each Transmission Owner and Generator Owner that is responsible for Dynamic Disturbance Recording shall have continuous recording and storage capability for the BES bus locations established in Requirement R9:

• Exception: If the equipment was installed prior to the effective date of this standard, triggered record data lengths of at least three minutes are required.

Non-Continuous DDR


• Each Responsible Entity shall set each non-continuous, trigger type, Dynamic Disturbance Recorder to trigger for at least one of the following (based on manufacturer’s equipment capabilities): Delta Frequency trigger TBD

o Eastern & Western Interconnections, ERCOT, Hydro-Quebec Off nominal Frequency trigger TBD Rate of change of Frequency trigger at a minimum TBD Under-voltage set no lower than 0.85 pu for a duration of 5 seconds

Non-Continuous DDR


• Each Transmission Owner and Generator Owner shall have all Sequence of Event Recording, Fault Recording, and Dynamic Disturbance Recording data available, for the BES bus locations established in Requirements R1 and R9, for at least 10 calendar days after a Disturbance. All Sequence of Event Recording, Fault Recording, and Dynamic

Disturbance Recording data shall be provided to the Regional Entity, Reliability Coordinator, or NERC within 30 calendar days of a request.

All Fault Recording and Dynamic Disturbance Recording data shall be in a format such that any software system capable of viewing and analyzing COMTRADE (IEEE Std. C37.111- update to current year or successor) files may be used to process and evaluate the data.

All data files shall be named in conformance with IEEE C37.232-2007, or its successor, Recommended Practice for Naming Time Sequence Data Files.

Data Availability, Retention & Reporting


• Each Transmission Owner and Generator Owner shall ensure that the equipment used for Sequence of Events Recording, Fault Recording, and Dynamic Disturbance Recording, for the BES bus locations established in Requirements R1 and R9, is returned to service within 90 days from the start of maintenance, upgrades, or discovery of a failure. If a DME device will be out of service for greater than 90 days the owner shall keep a record of efforts and the plan for restoring the DME to service.

• Maintenance and Implementation requirements still being reviewed and revised.

Data Availability, Retention & Reporting


• NERC Standards Developer, Barb Nutter Email: [email protected] Tel: 404.446.9692 To receive project announcements and updates, request to be

added to DMSDT_Plus list

mailto:[email protected]


Thoughts and Questions for the JSIS

Presenter

Presentation Notes

Tim


FIDVR Events

http://www.nerc.com/docs/pc/tis/FIDVR_Tech_Ref%20V1-2_PC_Approved.pdf

“Modeling and Studying FIDVR Events,” WECC MVWG White Paper, Oct 20 2011

Less than 0.85 pu for greater than 5 seconds?


Other Issues

• 10 calendar day retention policy (currently for SOE, FR, DDR alike)

• What do we do and how do we handle the quality of the data? Clock bad when data is required… What happens?

• Any input on Implementation Plan? What is expected for DDR


ADDITIONAL SOE & FR REQUIREMENTS

• R1. Each TO shall establish a list of monitored bus locations for Sequence of Events Recordings and Fault Recordings. The list shall be established through following the selection procedure contained in PRC-002-2 Attachment 1 – SOE and FR Locations Selection Procedure.

• R2. The TO shall review the list established in Requirement R1 at least every five years.

• R3. Each TO and GO shall have Sequence of Events Recording for changes in circuit breaker position (open/close) for each of the circuit breakers it owns connected to the bus locations established in Requirement R1.



• R4. Each TO and GO shall have Fault Recording at the bus locations established in Requirement R1.

• R5. Each TO and GO shall record electrical quantities in order to determine phase-to-neutral voltages for each phase of a line or common bus they own at the bus locations established in Requirement R1.

• R6. Each TO and GO shall record electrical quantities in order to determine phase currents for each phase and the residual or neutral currents at the bus locations established in Requirement R1 for the following BES Elements it owns: 6.1 Transformers that have a low-side operating voltage of 100 kV or

above. 6.2 Transmission lines.



• R7. Each TO and GO shall have Fault Recording as specified in Requirement R4 that meets the following: 7.1 A single record or multiple records that include either:

o A pre-trigger record length of at least two cycles and a post-trigger record length of at least 50 cycles for the same trigger point

o A pre-trigger record of at least two cycles; the first three cycles of the fault; and the final cycle of the fault

7.2 A minimum recording rate of 16 samples per cycle.

• R8. Each TO and GO shall trigger each Fault Recording for at least the following: 8.1 Neutral (residual) overcurrent set at 0.4 pu or less of rated CT

secondary current. 8.2 Monitored phase under-voltage set no lower than 0.85 pu.

Documents

Overview of PRC-002-2 - WECC JSIS PRC-002-2 Briefing.pdf · Overview of PRC-002-2. Project 2007-11 Disturbance Monitoring . June 11-13, 2013 WECC JSIS Salt Lake City