system protection manual

MANUAL 33

System Protection Manual October 2009

Version: 1.0

Revision Date: 10/29/2009

Committee Acceptance: 12/10/2009

This document was prepared by: NYISO Operations Engineering Staff

New York Independent System Operator 3890 Carman Road Schenectady, NY 12303 (518) 356-6060 www.nyiso.com

Disclaimer The information contained within this manual, along with the other NYISO manuals, is intended to be used for informational purposes and is subject to change. The NYISO is not responsible for the user’s reliance on these publications or for any erroneous or misleading material.

©Copyright 1999-2009 New York Independent System Operator

http://www.nyiso.com/

N Y I S O S Y S T E M P R O T E C T I O N M A N U A L

Table of Contents

Table of Figures ......................................................................................................................... vi Table of Tables .......................................................................................................................... vi Revision History .........................................................................................................................vii

1. Reporting Transmission and Generation Protection System Operations and Protection System Performance ..........................................................................................................1-1

1.1 Scope ........................................................................................................................................1-1 1.2 Data Collection and Reporting ..................................................................................................1-1

1.2.1 Transmission Owner Collection Schedule..................................................................1-1 1.2.2 Generation Owner Collection Schedule .....................................................................1-1

1.3 Transmission of Data and Discussion of Results......................................................................1-1 1.3.1 Transmission Owners .................................................................................................1-2 1.3.2 Generation Owners.....................................................................................................1-2

1.4 Information Collected and Data Format ....................................................................................1-2 1.4.1 Transmission Owners .................................................................................................1-2 1.4.2 Generation Owners.....................................................................................................1-3

1.5 Data Collection..........................................................................................................................1-3 1.5.1 Transmission Owners .................................................................................................1-3 1.5.2 Generation Owners.....................................................................................................1-3

1.6 Follow-Up Actions .....................................................................................................................1-3 1.7 Interpretations ...........................................................................................................................1-4 1.8 Information Requested by NPCC..............................................................................................1-4 1.9 References................................................................................................................................1-4

2. Application of Disturbance Monitoring Equipment (DME) ..............................................2-1 2.1 Definitions..................................................................................................................................2-1 2.2 Specification and Settings of DME............................................................................................2-1 2.3 Time Zone .................................................................................................................................2-1 2.4 Survey of DME Equipment........................................................................................................2-2 2.5 Sharing of DME Data ................................................................................................................2-2 2.6 Other .........................................................................................................................................2-2 2.7 References................................................................................................................................2-2

3. System Protection Data......................................................................................................3-1 3.1 Relay Characteristics ................................................................................................................3-1 3.2 Pilot Protection Systems ...........................................................................................................3-1 3.3 Clearing and Reclosing Times ..................................................................................................3-2

3.3.1 Clearing Times............................................................................................................3-2 3.3.2 Reclosing Times .........................................................................................................3-2 3.3.3 Special Protection Systems ........................................................................................3-3 3.3.4 Special Protection Systems ........................................................................................3-3 3.3.5 Other Remedial Action Systems.................................................................................3-3 3.3.6 SPS Data Submission and Updating Procedures ......................................................3-4

3.3.6.1 Facility Equipment Owner Actions.....................................................................3-4 3.3.6.2 NYISO Actions...................................................................................................3-4

3.4 Power Line Carrier Frequencies ...............................................................................................3-5 3.4.1 Introduction .................................................................................................................3-5 3.4.2 UTC PLC Task Force Contacts ..................................................................................3-5

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3.4.3 UTC PLC Frequencies Database Reports .................................................................3-5 3.4.4 UTC PLC Frequency Coordination Procedures .........................................................3-5

3.4.4.1 PLC Task Force Contact Actions ......................................................................3-6 3.4.4.2 NYISO Actions...................................................................................................3-6 3.4.4.3 PLC Task Force Contact Actions ......................................................................3-6 3.4.4.4 NYISO Actions...................................................................................................3-6 3.4.4.5 PLC Task Force Contact Actions ......................................................................3-6 3.4.4.6 UTC Actions.......................................................................................................3-7

3.4.5 Procedures for Retiring PLC Frequencies..................................................................3-7 3.4.5.1 PLC Task Force Contact Action ........................................................................3-7 3.4.5.2 NYISO Action.....................................................................................................3-7

3.4.6 Annual Review of the PLC Frequencies Database ....................................................3-7 3.4.6.1 UTC Action ........................................................................................................3-7 3.4.6.2 PLC Task Force Contact Actions ......................................................................3-8 3.4.6.3 NYISO Action.....................................................................................................3-8

3.5 Short-Circuit Fault Analysis Data ..............................................................................................3-8 3.5.1 Introduction .................................................................................................................3-8 3.5.2 Annual Review of Short-Circuit Representation .........................................................3-8

3.5.2.1 Facility Equipment Owner Action.......................................................................3-8 3.5.2.2 NYISO Action.....................................................................................................3-8

4. Automatic Underfrequency Load Shedding Reporting and Compliance.......................4-1 4.1 Entities.......................................................................................................................................4-1 4.2 Schedule ...................................................................................................................................4-1 4.3 Computation of Load.................................................................................................................4-2 4.4 Format .......................................................................................................................................4-2 4.5 Notifications...............................................................................................................................4-3 4.6 References................................................................................................................................4-3

5. System Protection Maintenance Reporting ......................................................................5-1 5.1 Scope ........................................................................................................................................5-1 5.2 Compliance Reporting...............................................................................................................5-1 5.3 Maintenance Reporting .............................................................................................................5-1 5.4 Report Review...........................................................................................................................5-1 5.5 Reference..................................................................................................................................5-2

Appendix A. Guide for the Selection of Power Line Carrier Frequencies........................... A-1 A.1. Introduction............................................................................................................................... A-1 A.2. PLC Modulation Techniques .................................................................................................... A-1

A.2.1. Amplitude Modulated Keyed Systems....................................................................... A-1 A.2.2. Frequent Shift Keyed Systems .................................................................................. A-1 A.2.3. Single Side Band Systems ........................................................................................ A-2

A.3. General PLC Application Criteria ............................................................................................. A-2 A.3.1. Trapping and Coupling .............................................................................................. A-2 A.3.2. Factors Affecting Frequency Selection...................................................................... A-2

A.4. Frequency Spacing by Equipment Type .................................................................................. A-3 A.4.1. On-Off (AM) Blocking Carrier..................................................................................... A-3 A.4.2. Frequency Shift (FSK) ............................................................................................... A-4 A.4.3. Single Sideband......................................................................................................... A-4

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A.5. References............................................................................................................................... A-6 Appendix B. Protection System Performance (PSP) Reporting Instructions ..................... B-1

B.1. Introduction............................................................................................................................... B-1 B.2. Discussion................................................................................................................................ B-1 B.3. General Instructions ................................................................................................................. B-2 B.4. Coding Instructions .................................................................................................................. B-3

B.4.1. Participant .................................................................................................................. B-3 B.4.2. File Number ............................................................................................................... B-3 B.4.3. Date/Time .................................................................................................................. B-4 B.4.4. Event.......................................................................................................................... B-4

B.4.4.1. Initiating Condition ............................................................................................ B-4 B.4.4.2. Resulting Condition........................................................................................... B-4 B.4.4.3. Element/Location .............................................................................................. B-4 B.4.4.4. Circuit/Equipment ............................................................................................. B-4 B.4.4.5. Auto Restore..................................................................................................... B-4 B.4.4.6. Auto Reclose .................................................................................................... B-4 B.4.4.7. High-Side Voltage............................................................................................. B-4 B.4.4.8. Station............................................................................................................... B-4 B.4.4.9. Protection System I.D. ...................................................................................... B-5 B.4.4.10. Protection System Operations.......................................................................... B-5

B.4.5. Pilot System Packages .............................................................................................. B-6 B.4.5.1. Line Package .................................................................................................... B-6 B.4.5.2. DTT Package.................................................................................................... B-6

B.4.6. Comments.................................................................................................................. B-7 B.4.7. Submitted By.............................................................................................................. B-7

Appendix C. Forms .................................................................................................................. C-1 C.1. Relay Characteristics Form...................................................................................................... C-2 C.2. Clearing Times Form................................................................................................................ C-4 C.3. Reclosing Data Form ............................................................................................................... C-5


Table of Figures

Reserved for future use.

Table of Tables

Table A.1 ON – OFF Carrier Frequency Spacing ....................................................................... A-4 Table A.2 FSK Carrier Frequency Spacing................................................................................. A-4 Table A.3 Single-Sideband Equipment Operating Parameters................................................... A-6 Table B.1 Event Table ................................................................................................................ B-7 Table B.2 Incorrect Personnel Table .......................................................................................... B-8 Table B.3 Incorrect Relay Table ................................................................................................. B-9

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Revision History

Version Date Revisions

1.0 10/29/2009 Initial Release

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1. REPORTING TRANSMISSION AND GENERATION PROTECTION SYSTEM OPERATIONS AND PROTECTION SYSTEM PERFORMANCE

The processes outlined below are intended to fulfill the requirements for reporting and analyzing Bulk Power System (BPS) protection system operations as assigned to the New York Independent System Operator (NYISO) System Protection Advisory Subcommittee (SPAS). These processes are in compliance with applicable NPCC Procedures and NERC Standards, which are listed as references

1.1 Scope The NYISO SPAS has been assigned the responsibility of analyzing BPS Protection System Performance (PSP) and maintaining a record of all BPS protection system operations. This function was initiated mainly so that the benefits of these experiences would be shared among SPAS members.

1.2 Data Collection and Reporting NYISO staff facilitates the data collection and analysis of the results with the New York Control Area (NYCA) Transmission and Generation Owners on a quarterly basis.

On or about the 20th day of the last month of each quarter, NYISO staff shall initiate a reminder via e-mail to those individuals identified by each BPS Transmission Owner and Generation Owner as their Protection System Performance (PSP) contact. The reminder shall set forth the collection schedule. The collection schedule is normally as outlined in the following two subsections.

1.2.1 Transmission Owner Collection Schedule Protection System Performance (PSP) data for each quarter shall be transmitted to NYISO staff by e-mail on or before the 20th of the month that follows each quarter.

1.2.2 Generation Owner Collection Schedule Generation Operations data for each quarter shall be transmitted to NYISO staff by e-mail on or before the 20th of the month that follows each quarter.

1.3 Transmission of Data and Discussion of Results The quarterly data is then discussed and analyzed at the next regularly scheduled SPAS meeting. For this reason, SPAS meetings are normally scheduled shortly after the PSP data

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is due. This schedule may be adjusted in some quarters due to constraints such as conflicting meetings.

1.3.1 Transmission Owners Each Transmission owner representative shall have transmitted a PSP system (.xls) file containing reports on all reportable operations for the previous quarter, and .pdf files for each of the incorrect operations during that quarter, as outlined in section 1.2.1. At the SPAS meeting, each Transmission owner representative shall review for the sub-committee each of the incorrect operations during that quarter. Each review shall include electronic projection of the report file by NYISO staff. In cases where the determination of correct or incorrect is in doubt, the SPAS will review the report and make a determination.

1.3.2 Generation Owners Generation Owner representatives are encouraged to attend the SPAS meetings to discuss their operations; however, due to the relatively few generation-related protective system operations, it is acceptable for the Generation Owners to simply submit a written report and be available by phone to discuss the operations, if deemed necessary by NYISO staff and/or the SPAS. NYISO staff shall summarize the results from the previous quarter and provide a verbal report on any operation judged to be incorrect. In cases where the determination of correct or incorrect is in doubt, the SPAS will review the report and make a determination.

1.4 Information Collected and Data Format

1.4.1 Transmission Owners Software for reporting events, called the NYISO PSP System, shall be distributed by NYISO staff. As a minimum, the following information shall be reported:

Transmission Owner Name File Number Date and Time of Event Initiating Condition Resulting Condition Element/Location Auto Restored (Y or N) and Auto Reclosed (Y or N) High Side Voltage Station Protection System ID Protection System Operation, Number, and Code Pilot System Line Code Pilot System DTT Code Comments

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Name of Individual Making Report

NYISO PSP data includes data on operations of both conventional protections systems and Special Protection Systems (SPS).

Collection methods are subject to updates and revisions as required.

1.4.2 Generation Owners A format for reporting events will be distributed by NYISO staff. As a minimum, the following information shall be reported on this form.

Date of Report Date of Operation Time of Operation Time Synchronization Source Equipment Removed from Service Root Cause Protection Function Correct or Incorrect Explanation and Corrective Action Plan for Incorrect Operations Name of Individual Making Report Plant Name and Unit Number


1.5 Data Collection

1.5.1 Transmission Owners New York State Transmission Owners shall use a Microsoft® Access database to collect and transmit the PSP data to the NYISO. In addition, those operations that receive an “incorrect” code shall be transmitted to NYISO staff in the form of .pdf files.


1.5.2 Generation Owners New York State Generation Owners shall use the Microsoft Word format provided each quarter by NYISO staff.


1.6 Follow-Up Actions NYISO staff will archive the incorrect report .pdf files as they are received in advance of each SPAS meeting. These are subject to NPCC or NERC audit.




Any items that are incomplete or remaining under investigation should be documented in the SPAS meeting minutes and action items list and addressed at subsequent SPAS meetings until the items are closed.

Any mitigation plans should be presented to SPAS and documented in the SPAS meeting minutes and action items list and addressed at subsequent SPAS meetings until the items are closed.

1.7 Interpretations Questions of interpretation should be brought for discussion at the SPAS meeting immediately following the quarter during which the event occurred. Such discussions may result in rules or interpretations being added to this manual or subsequent Technical Bulletins.

1.8 Information Requested by NPCC NPCC B-21 requires that analysis of misoperations shall be initiated by Generation Owners and Transmission Owners, and that the required information shall be supplied to the Area (NYISO) in accordance with policies established in each Area. Generation Owners and Transmission Owners are also required, under certain circumstances, to supply results of their analysis to NPCC. Please see the most recent version of NPCC B-21 for details.

1.9 References NPCC B-21, “Guide for Monitoring of Protection System Misoperations,” July 14,

2004, or most recent version, available at the following address: http://www.npcc.org/

NERC PRC-003-1, “Regional Procedure for Analysis of Misoperations of Transmission and Generation Protection Systems,” or most recent version, available at the following address:

http://www.nerc.com/

NERC PRC-004-1, “Analysis and Mitigation of Transmission and Generation Protection System Misoperations,” or most recent version, available at the following address:


NERC PRC-016-0, “Special Protection System Misoperations,” or most recent version, available at the following address:


http://www.npcc.org/





2. APPLICATION OF DISTURBANCE MONITORING EQUIPMENT (DME)

Disturbance Monitoring Equipment (DME) as used in this document includes, but is not necessarily limited to, dynamic disturbance recorders, digital fault recorders, and phasor measurement units.

The NYCA has long been a pioneer in the effective application of DME and continues to be exemplary in its ability to effectively use DME to accomplish the three main purposes: (1) model validation, (2) disturbance investigation, and (3) assessment of system protection performance.

The NYCA has also been an active participant in preparation of the various DME-related documents of the IEEE, North American Electric Reliability Corporation (NERC), the Northeast Power Coordinating Council, Inc. (NPCC), and the New York State Reliability Council (NYSRC); several of the most important documents are listed in the section 2.7, “References,” below. This Manual addresses only those items that are not already covered in the applicable documents of NERC, NPCC, and NYSRC.

2.1 Definitions DME – Disturbance Monitoring Equipment

DDR – Dynamic Disturbance Recorder

DFR – Digital Fault Recorder

PMU – Phasor Measurement Unit

NYISO – The New York Independent System Operator, an Area Reliability Coordinator

TO – Transmission Owner

GO – Generation Owner

2.2 Specification and Settings of DME This subject is well covered in NPCC and NERC documents. The following are additional items not covered in these documents:

DDRs and DFRs should automatically extend records when a re-trigger occurs while a recording is in progress.

Any new DME shall have PMU-capability.

2.3 Time Zone The NYISO prefers that DDRs and DFRs be set to Universal Time Zone (UTZ).

In the event DDRs and/or DFRs are set to local time, records transmitted to the NYISO shall contain the hours offset from UTC in the file name consistent with the IEEE C37.232 Standard.



2.4 Survey of DME Equipment NYISO staff shall survey the status of DME in the NYCA approximately every two years. This activity shall be coincident with a NPCC survey if a NPCC survey is undertaken.

2.5 Sharing of DME Data Through applicable NYISO Tariffs and Market Participant agreements, the NYISO has the right to ask for any DME data needed to fulfill its functions as Reliability Coordinator. When necessary, the NYISO will request individual DME records or files from TOs and GOs.

Individual records/files furnished as part of a disturbance investigation shall be in IEEE COMTRADE format, and file names shall be in accordance with IEEE C37.232-2007 convention, except by agreement among the parties involved. Depending on the volume of data, the NYISO may request individual records be forwarded electronically, or that a group of files or records be placed on a CD or DVD and shipped to the NYISO by express delivery service.

2.6 Other DME installed by New York TOs and GOs shall be operated and maintained in accordance with the requirements of NPCC Criteria A-15 and NERC Standard PRC-018-1. Consideration should be given to consultation with NYISO staff in regard to DME locations and configuration.

2.7 References NYSRC Rule C-R5, “Disturbance Recording” NPCC Criteria A-15, “Disturbance Monitoring Equipment Criteria” NERC Standard PRC-002-1, “Define and Document Disturbance Monitoring

Equipment Requirements” NERC Standard PRC-018-1, “Disturbance Monitoring Equipment Installation and

Data Reporting” NPCC Guideline B-25, “Guide to Time Synchronization of Substation Equipment” NPCC Guideline B-26, “Guide for Application of Disturbance Recording

Equipment” IEEE C37.111-1999, “IEEE Standard for Common Format for Transient Data

Exchange (COMTRADE) for Power Systems” IEEE C37.232-2007, “IEEE Recommended Practice for Naming Time Sequence

Data Files”



3. SYSTEM PROTECTION DATA Transmission system protection data is required to develop and maintain functional models of the transmission and generation BPS protection devices that can be used for dynamic simulation and for the coordination of protection facilities with the existing and proposed system reinforcements. Some of the data is also required for other aspects of power system operation and operating studies, such as thermal and voltage contingency analysis. This section describes the requirements and procedures for reporting this data to the NYISO.

Facility Equipment owners’ system protection engineering staff shall provide data to the NYISO System Protection Coordinator upon request. In general, the time period allowed for such data request is 30 days; however, in special circumstances, a shorter time period may be necessary. Characteristics of protection equipment associated with NYISO-secured Transmission System facilities are important for dynamic simulation and other aspects of NYISO operations.

3.1 Relay Characteristics Protection systems may be specifically (rather than generically) modeled when they could operate within the scope of system dynamic simulations (power system stability analyses). When the actual relay system characteristics are not available, a generic relay model may be used. When appropriate, over-current or out-of-step protection may also be modeled. A simplified data submission form is included in this manual as the Relay Characteristics Form, found on page C-2.

Relay characteristics are required only for relays that could trip for an apparent three-phase fault (e.g., a power swing) to evaluate the possibility of additional trips during the post-transient swing following the clearing of the fault.

Relay characteristics are not used for the purpose of determining clearing times or for the primary clearing of a fault, in the dynamic simulation. Appropriate clearing times are determined by the design of the protection groups on each transmission facility and are reported separately. Please see the Clearing Times Form, included in this manual on page C-4.

Margins should not be applied to the relay characteristic data. In the course of the study analyses, margins may be applied to the relay characteristics when relay actions are evaluated as part of a stability simulation.

3.2 Pilot Protection Systems Pilot protection systems are defined as those systems that utilize a communications channel in comparing fault conditions at the line terminals of a transmission line to determine whether the fault is internal or external to that particular line section.

The procedures described in this manual shall be used by the Transmission Owners to prepare and submit the protection systems relay characteristics data to the NYISO. The relay data should be furnished on the Relay Characteristics Form, found on page C-2. If the relay schemes do not lend themselves to this form (only Mho-distance or reactance-distance



relays), separate pages shall be attached. If the Facility Equipment owner is using the Power Technologies, Inc. PSS/E program, then PSS/E input forms may be attached to the Relay Characteristics Form.

3.3 Clearing and Reclosing Times Estimated protection system clearing times are required for all ISO-secured facilities. Data on automatic closing of circuit breakers without operator initiation (known as reclosing) is required for the transmission facilities that have high-speed reclosing and/or hot-bus/dead-line reclosing.

3.3.1 Clearing Times Facility Equipment owners shall use the following assumptions when calculating the fault clearing times to be submitted to the NYISO:

Maximum system short-circuit capacity. Faults are solid, three-phase faults. Use both near-end and far-end line faults. Do not consider bus faults when computing transmission-line clearing times. All relays operate correctly, that is, the operating time used is that of the faster of

two redundant protection groups. Speed of operation of circuit breakers and relay equipment is the nominal speed

quoted by the manufacturer. Clearing time is a single value, from fault inception until breaker clearing. For pilot systems, communication time is included for far-end faults. No margin shall be added to the clearing times. Clearing times for single phase to ground faults may be requested by NYISO staff

when needed.

3.3.2 Reclosing Times The following information is required by the NYISO for reclosing relay protection data:

High speed reclosing times Relay reclosing time in seconds Breaker reclosing time in cycles Delayed reclosing times in seconds First Shot: Hot-bus/dead-line reclosing time in seconds Second Shot: Hot-bus/dead-line reclosing time in seconds Third Shot: Hot-bus/dead-line reclosing time in seconds

A data submission form is included in this manual as the Reclosing Data Form, found on page C-5. Reclosing terms are used as defined in the NPCC document, “Guide for the Application of Auto Reclosing to the Bulk Power Systems,” Document B-1.



3.3.3 Special Protection Systems Protection-based systems that are designed to monitor special system conditions can have an impact on system operation. The NYISO requires that the following protection systems be described and reported to the NYISO according to the guidelines of this section:

Special Protection Systems (NPCC definition) Other Remedial Action Systems (NYISO definition)

3.3.4 Special Protection Systems An SPS is defined by NPCC as a protection system designed to detect abnormal system conditions and take corrective action other than the isolation of faulted elements.

Facility Equipment owners are required to prepare and submit to the NYISO an SPS description that includes but is not limited to the following information about the SPS:

Initiating incident (SPS trigger or triggers) Resulting action Total clearing time Reason for use Percent of time in service NPCC classification

This information shall be provided by the Facility Equipment owner’s System Protection Advisory Subcommittee (SPAS) member to the NYISO System Protection Coordinator in accordance with NPCC Criteria.

An SPS description shall be prepared for any SPS that is located within the NYCA or involves any ISO-secured facility or tie line between the NYCA and a neighboring control area.

The NPCC Task Force on System Protection maintains an SPS list that is updated and posted annually by NPCC.

3.3.5 Other Remedial Action Systems In addition to NPCC SPSs, NYISO TOs, GOs, Load-Serving Entities (LSEs), or other participants may operate other remedial action systems that are similar in concept to SPSs and that may have an effect on NYCA operations, even though the scheme does not fit the NPCC definition of an SPS. These systems must also be described and reported to the NYISO. Some examples of protection systems could have an effect on NYCA operations are:

A protection system included in transient stability simulations that effects the results of the simulation

A protection system that causes a change in operating limits A protection system used by a Facility Equipment owner that allows the

Transmission Provider to mitigate a transmission security limitation



A protection system that limits the ability to load a facility to rated Short-Term Emergency (STE) capability

The NYISO System Protection Coordinator notifies the Facility Equipment owner SPAS Member when one of the above situations is detected and a NYISO System Impacting Protection Memo System report is required.

3.3.6 SPS Data Submission and Updating Procedures The following procedures apply to all data described in the sections 3.4.1 and 3.4.2 unless otherwise indicated.

3.3.6.1 Facility Equipment Owner Actions

1. Submit to the NYISO System Protection Coordinator updates to the following data for all facilities found to be Bulk Power system facilities by NPCC criteria A-10, upon the implementation of a new System Impacting Protection System, or upon

YISO request: N a. Relay characteristics using the Relay Characteristics Form found on page C-2 of

this manual. b. Clearing times using the Clearing Times Form, found on page C-4 of this

manual. c. Reclosing times using the Reclosing Data Form, found on page C-5 of this

manual.

2. Submit to the NYISO System Protection Coordinator the SPS report at least three months before placing the SPS in service.

3. Submit SPS data for all new or modified transmission facilities not later than three months prior to the scheduled in-service date of the protection system. If setting changes are made, the data shall be furnished upon implementation.

4. In the case of transmission lines which are interconnections with neighboring control areas, the TO SPAS representative shall submit data for all terminals of the line.

3.3.6.2 NYISO Actions

1. Once each year the NYISO System Protection Coordinator will transmit all data back to each TO SPAS Representative for confirmation or revision.

2. Use the SPS data in the dynamic simulation, thermal, and voltage contingency analysis studies.

3. Inform the Facility Equipment owner SPAS member when SPS conditions are present and a new report is needed.

4. When the review is complete, the NYISO shall issue updates to the NYISO Protection Memo document and distribute to appropriate Facility Equipment owner and NYISO personnel.



3.4 Power Line Carrier Frequencies This section describes the procedure for coordination of Power Line Carrier (PLC) Frequencies among Facility Equipment owners of NYISO and neighboring systems. As part of the coordination process, information is provided for updating PLC databases maintained by the Utilities Telecommunications Council (UTC).

3.4.1 Introduction Coordination of PLC frequencies within New York State is the responsibility of the NYISO successor group to the System Protection Advisory Subcommittee (SPAS).

In order to carry out these coordination responsibilities, the NYISO participates as part of a working group known as the Power Line Carrier Task Force, or PLC Task Force. This task force comprises designated UTC PLC Data Base Contacts and the NYISO System Protection Coordinator.

The PLC Task force originally collected and supplied information on New York PLC facilities to NERC, which later turned over to UTC the responsibility of maintaining the PLC Database.

3.4.2 UTC PLC Task Force Contacts Each Facility Equipment owner designates a PLC Task Force contact to represent it. A list of the New York PLC Task Force contacts is maintained by the NYISO.

This list is distributed annually to all PLC Task Force contacts and to SPAS. Changes to this list must be reported by the Equipment owner contact to the NYISO contact and System Protection Coordinator as soon as possible. The NYISO will report such changes to the SPAS and all PLC Task Force contacts.

3.4.3 UTC PLC Frequencies Database Reports Two UTC PLC Frequencies Database reports are available by contacting the UTC. Turn around time for receipt of any of the reports is approximately three working days.

Individual Organization Report — Details an individual organization’s PLC frequencies. The PLC Frequency data is sorted by substation, transmitter and associated receiver(s), and frequencies.

Interference Report — Details any PLC or licensed user frequencies that are within potential interference distance or frequency range of a proposed or in-use PLC frequency. The criteria used for interference distance is 50 miles.

3.4.4 UTC PLC Frequency Coordination Procedures The PLC frequency coordination procedure applies in the following cases:

To request addition of a new PLC frequency for immediate or future use To request a current frequency change



In all these cases, the PLC Frequency Data Report form is completed and sent to the NYISO. The instructions for forms PLC1 and PLC2, and the forms themselves, are available on the UTC Web site at this address:

http://www.utc.org/utc/plc-forms-instructions

All the information on Form PLC2 form must be completed, and the applicable UTC Transaction Code for this form must be specified. All transmitter information entered for the first time shall be designated as transaction code A or P.

Add in service A

Add in proposed P

Correction C

Delete D

3.4.4.1 PLC Task Force Contact Actions The Facility Equipment owner PLC Task Force contact shall initiate the process by submitting a completed PLC Frequency Data Report and forwarding such report to the NYISO. The form shall be completed to indicate each new frequency or change.

3.4.4.2 NYISO Actions Upon receiving a completed PLC Frequency Data Report, the NYISO shall send copies of the report to the PLC Task Force Contacts.

3.4.4.3 PLC Task Force Contact Actions

1. Within 31 days of receipt of a new PLC Frequency Data Report, each PLC Task Force contact shall advise the NYISO by written memorandum of the concurrence or objection with the proposed PLC frequency or frequencies.

2. If there is a conflict, the involved parties shall attempt to work out the difficulty by holding meetings, where necessary, to negotiate solutions to PLC frequency coordination problems.

3. If the approved frequencies resulting from these discussions are different than those originally submitted, the appropriate PLC Task Force contact shall resubmit a revised PLC Frequency Data Report to the NYISO for redistribution to the PLC Task Force Contacts.

3.4.4.4 NYISO Actions When frequencies are found satisfactory by all PLC Task Force contacts, the NYISO shall notify the Facility Equipment owner of this result.

3.4.4.5 PLC Task Force Contact Actions The Facility Equipment owner PLC Task Force contact that originated the Frequency Report shall send it to the current designated contact at the UTC. At this time the address is as follows:


http://www.utc.org/utc/plc-forms-instructions


Kathleen Fitzpatrick United Telecom Council 1901 Pennsylvania Ave NW #500 Washington, DC 20006 [email protected]

3.4.4.6 UTC Actions Upon receiving the PLC Frequency Data Report, the UTC will report other potential conflicts to the affected Facility Equipment owner PLC Task Force contacts.

If the transaction code was to add a proposed new frequency (P), UTC will report on potential conflicts to the affected TP Contact only and not to other users of the low-frequency radio spectrum.

If the transaction code was to add a frequency already in service, UTC will report the potential conflict to all the PLC Task Force contacts and users of the low-frequency radio spectrum.

3.4.5 Procedures for Retiring PLC Frequencies When Facility Equipment owners decide to retire a PLC frequency from the UTC PLC database, the same PLC Frequency Data Report is submitted to the NYISO. In this case the applicable UTC Transaction Code is:

Code D, standing for “deletion of an existing PLC frequency.”

It is not necessary for the Facility Equipment owner’s PLC Task Force contact to respond to the NYISO in the case of f retired requencies.

3.4.5.1 PLC Task Force Contact Action Initiate the process by submitting a completed PLC Frequency Data Report to the NYISO. This form shall be completed to indicate each frequency retired. A copy of this form shall be sent to the UTC at the address above.

3.4.5.2 NYISO Action Upon receiving a completed PLC Frequency Data Report, the NYISO shall send copies of the report to the PLC Task Force contacts.

3.4.6 Annual Review of the PLC Frequencies Database In addition to the coordination and database update procedures defined, an annual review is required of the UTC database for accuracy.

3.4.6.1 UTC Action Annually, UTC initiates the review of the PLC Frequencies Database by sending to each PLC Task Force contact a copy of their respective UTC data for review.


mailto:[email protected]


3.4.6.2 PLC Task Force Contact Actions

1. Review and revise the UTC database and send it directly to the UTC.

2. Send copies of the PLC Database revisions to the NYISO.

3.4.6.3 NYISO Action Send copies of received PLC Frequencies Database updates to all of the other PLC Task Force contacts.

3.5 Short-Circuit Fault Analysis Data This section describes the procedure for maintaining the NYISO Short-Circuit representation.

3.5.1 Introduction The NYISO System and Resource Planning department Protection Coordinator shall maintain a uniform short-circuit representation for fault analysis. The Equipment owners shall periodically review and update their respective portions of the representation. It is necessary for the NYISO to maintain a current short-circuit representation to ensure availability of this data for any necessary analyses required in a system impact study in accordance with the NYISO Transmission Expansion and Interconnection Manual (http://www.nyiso.com/public/documents/manuals/planning.jsp?maxDisplay=20) and other industry Standards. Voltage and dynamic stability studies for either system reliability or operating security also need accurate fault analysis data.

The NYISO uses the ASPEN One-Liner program; however, new data or modifications to existing data may be submitted in any of the standard data formats used by the industry (e.g., PSS/e, CAPE, etc.).

3.5.2 Annual Review of Short-Circuit Representation Annually, the NYISO System and Resource Planning department Protection Coordinator initiates the review of the NYISO Short-Circuit Representation by sending to each Facility Equipment owner’s SPAS representative a copy of their respective current data for review.

3.5.2.1 Facility Equipment Owner Action Review and revise the short-circuit database as appropriate and return it to the person defined by the NYISO System and Resource Planning department Protection Coordinator. This will include changes to existing data or additions or deletions to the representation based on system changes that have recently occurred or are planned for installation within the next capability period.

3.5.2.2 NYISO Action The NYISO System and Resource Planning department Protection Coordinator shall update the NYISO short-circuit representation as indicated.


http://www.nyiso.com/public/documents/manuals/planning.jsp?maxDisplay=20


The NYISO System and Resource Planning department Protection Coordinator shall make the representation available to all Facility Equipment owners, other NYISO staff, or to such contractors and consultants or regulatory agencies for purposes of conducting system studies associated with transmission system reliability assessment.



4. AUTOMATIC UNDERFREQUENCY LOAD SHEDDING REPORTING AND COMPLIANCE

The NYISO SPAS has been assigned the responsibility of collecting Under Frequency Load Shedding (UFLS) data and monitoring compliance with NPCC Criteria document D-12, Section 5.2, “Automatic Underfrequency Load Shedding.” In addition to monitoring compliance with D-2, the data is also used in supporting compliance with the NYSRC Rule F-R8, “Load Shedding Allocation,” and for simulations involving action of UFLS. This section describes how the data collection and compliance monitoring will be carried out.

4.1 Entities NYISO (as Area Reliability Coordinator) – NYISO staff will initiate the request and collect the data and compliance statements.

UFLS Entity – Generally, the New York Area UFLS Entities are the same as the New York Area TOs; however, this term may also apply to a Transmission Operator, Distribution Provider, and/or LSE that is required to own or operate a UFLS program.

4.2 Schedule In order to support collection of the NPCC D-12 compliance data, NYISO staff will send an inquiry by e-mail on or about April 1 of each year to the SPAS Participants and representatives designated by the UFLS Entity for this purpose. This e-mail inquiry will request data sufficient to perform analysis of compliance with the following table from D-12:

Table 1 - UFLS Parameters for the Eastern interconnection Portion of the NPCC

Threshold Setting Block Size Total Operating Time (1) (2)

Stage 1 59.5 Hz 7 percent 300 ms




Stage 5 (anti-stall) 59.5 Hz 2 percent 10 s

Notes: (1) Total operating time is the load-weighted average for all load to be shed within a Balancing Authority area,

with maximum deviation for any load limited to ±50 ms.

(2) Minimum UFLS relay operating time=100ms.

The e-mail inquiry will request data sufficient to perform analysis with the following statement in D-12:



D-12, 5.4 “Generators shall not be tripped for under-frequency conditions in the area above the curve in Figure 1, except as provided for in Sections 5.4.1 and 5.4.2.” (Figure 1 is included in D-12 following section 7.)

The e-mail inquiry will specify the UFLS Entity response time, which shall be at least 30 days.

In parallel with the activity described herein, the NYISO will also be collecting data directly from GOs.

4.3 Computation of Load The intent of D-12, section 5.2, is for an Area to stabilize the frequency during an underfrequency condition, by automatically shedding approximately ten and fifteen percent of its load at the time of the event.

The intent of D-12, section 5.4, is to preserve the stability of an island, if formed, by providing compensatory load shedding for generators that do not conform to Figure 1, and thus could interfere with the operation of the underfrequency load-shedding program.

For these purposes, the amounts of load shedding shall be reported coincident with the individual UFLS Entity’s integrated hourly peak from the previous summer. That is, the individual UFLS Entity shall total its UFLS circuit loads at the time of the Entity's previous year’s integrated hourly summer peak, and report the amount of load that would have been shed at each UFLS step, in both megawatts and as a percentage of the peak.

The load-shedding amounts reported for 5.2.1 must not include load shedding provided as compensation for non-conforming generators, in 5.4. That is, the same loading shedding may not be reported for purposes of both 5.2 and 5.4.

Additional background material in NPCC D-12 should be consulted before certifying compliance.

The calculations shall be retained for a period of two years after making this report.

4.4 Format A format for reporting compliance will be distributed with the e-mail inquiry. The following information will be reported on this form:

Name of UFLS Entity Date of report Name of the individual making the report on behalf of the Entity

For Section 5.2.1 of D-12: Previous year’s summer integrated hourly peak load UFLS at each step, expressed as both megawatts and percentage of Entity’s peak,

including those steps provided that are beyond the NPCC-mandated steps

For Section 5.4 of D-12: List of generators that do not conform with NPCC D-12.



For each such non-conforming generator, the generator megawatt rating, trip setting in Hertz, and time delay in seconds.

Compensatory load shedding for each such non-conforming generator, with the megawatts load shedding and trip setting in Hertz.

Non-conforming generators with a rating below 20 MW may be reported in groups with other generators of the same settings.

Compensatory load shedding for generators that have been reported in groups may also be grouped.

Overall Compliance: A statement of compliance with NPCC D-12

4.5 Notifications At the completion of the data collection, the NYISO will prepare an Area Compliance Report. This report will be completed within 60 days of the initial data request, and copies will be sent to the appropriate NPCC entity or group and the NYCA UFLS Entities. (This is necessary as PRC-007 places the obligation on each UFLS entity to “ensure that its UFLS program is consistent with its RRO TFLS program requirement.”)

4.6 References NPCC D-12, “UFLS Program Requirements,” June 29, 2009, or most recent version,

available at: http://www.npcc.org/documents/regStandards/Directories.aspx

“UFLS Implementation Plan,” June 29, 2009, available at: http://www.npcc.org/documents/regStandards/Directories.aspx

NPCC B-7, “Automatic Underfrequency Load Shedding Program,” September 4 2008, or most recent version, available at

http://www.npcc.org/documents/regStandards/Guide.aspx

NERC Standard PRC-007-0, “Assuring Consistency with Regional UFLS Program Requirements,” Requirement R1, available at:

http://www.nerc.com.

NYSRC Rule F-R8, “Load Shedding Allocation,” available at: http://www.nysrc.org.


http://www.nysrc.org/


5. SYSTEM PROTECTION MAINTENANCE REPORTING

The NYISO SPAS has been assigned to monitor compliance with NPCC directory D-3 “Maintenance Criteria for Bulk Power System Protection.” As part of this process, TOs and GOs report their ability to comply with the NPCC D-3 requirements on a quarterly basis. This document describes how this process is carried out by SPAS including functions of the reporting of TOs and GO and of NYISO staff.

5.1 Scope The NYISO SPAS has been assigned the responsibility of monitoring compliance with the relay maintenance criteria set forth in NPCC directory D-3.

5.2 Compliance Reporting Prior to January 1 of each year, NYISO staff will send an e-mail to the TOs and GOs reminding them their annual compliance statement for January 1 is due by January 20. The TOs and GOs shall respond to the Reliability Compliance Mailbox at [email protected] with a statement of full compliance or compliance with exceptions as of January 1. Reports shall list the BPS elements that exist at each BPS station. Exceptions are individual BPS elements with any system protection component capable of tripping that element that has not been maintained in accordance with D-3 as of the end of the 4th quarter. In the case of transmission line elements, each terminal shall be reported as a separate item. Along with their statement, TOs and GOs shall provide a revised test date for each exception.

5.3 Maintenance Reporting Prior to April 1, July 1, and October 1 of each year, NYISO staff will send an e-mail to the TOs and GOs reminding them their quarterly maintenance report is due on April 20, July 20, and October 20, respectively. The TOs and GOs shall respond to the Reliability Compliance Mailbox at [email protected]. On these dates, TOs and GOs shall report on maintenance backlog items, which are BPS elements that have not been maintained within the applicable time period described in D-3, as of the end of the previous quarter. In the case of transmission line elements, each terminal shall be reported as a separate item.

5.4 Report Review A summary of these reports shall be reviewed at the SPAS meeting immediately following the due date. Subsequent to the SPAS meeting, the SPAS Chair shall send a summary report to the NYISO Operating Committee Chair.






5.5 Reference NPCC Regional Reliability Reference Directory 3, “Maintenance Criteria for Bulk

Power System Protection,” July 11, 2008


A.

Appendix A. Guide for the Selection of Power Line Carrier Frequencies

A.

A.1. Introduction This appendix establishes minimum guidelines to provide a uniform method of selecting power line carrier (PLC) frequencies within the New York Control Area (NYCA). Procedures used by the Transmission owners to notify necessary parties of PLC frequency changes and additions and to keep the Utilities Telecommunications Council (UTC) PLC database current can be found in the section 3.4.4 of this manual.

PLC spectrum conservation has been a major concern within the power utility business for many years. These guidelines have been developed to conserve spectrum while staying within industry-established frequency separation limits to minimize interference between channels.

It is assumed that the user of this manual is familiar with the application of power line carrier systems.

A periodic review of these guidelines may be necessary, however, as dictated by changes in equipment technology.

A.2. PLC Modulation Techniques Three types of modulation techniques that utilize the PLC frequency spectrum of 10 to 490 kHz are in general use, namely Amplitude Modulated Keyed Systems, Frequent Shift Keyed Systems, and Single Side Band Systems, described in further detail in the following three subsections.

A.2.1. Amplitude Modulated Keyed Systems On-Off amplitude modulated (AM) keyed PLC systems are usually used for blocking relay schemes. This type of system may also serve a second function of transmitting voice over the power lines via AM. The PLC frequency is usually off (no PLC signal transmitted).

A.2.2. Frequent Shift Keyed Systems Frequency shift keyed (FSK) power line carrier systems are used for unblocking and transfer-tripping relay schemes. This type of PLC system always transmits at least one signal, sometimes at reduced levels to avoid possible interference. During tripping operations, full transmitter power (exalted signal level) is used. FSK – PLC systems are generally preferred over AM – PLC systems, as they allow the system to be continuously monitored.

NYISO Operations Engineering Staff A-1 Version 1.0 10/29/2009


A.2.3. Single Side Band Systems Single side band (SSB) suppressed AM carrier is used for multi-function PLC communications. SSB systems are typically four-channel systems (4-kHz Bandwidth channels). This is done by the “upshifting” of audio tone and/or baseband frequencies to line frequencies. The channels can be used for various functions including relaying (audio tone and/or baseband), voice, telemetry, and SCADA communications.

When considering frequency separation guidelines, the requirements of both the SSB – PLC system as well as the specific needs of the communications systems utilizing SSB – PLC should be considered.

A.3. General PLC Application Criteria

A.3.1. Trapping and Coupling If a single frequency is to be used, a single-frequency high Q trap is recommended,

as wideband traps do not provide as much isolation. When using a two-frequency line trap, maintain a minimum frequency separation of

25 kHz or 25% of the higher frequency, whichever is greater. If two or more closely spaced frequencies are employed, locate the entire group on

the upper (higher-frequency) trap skirt of a single-frequency trap if a high Q trap is used. As an alternate, use a low Q single frequency trap (Q ≈ 10) or a wideband trap of 1,000 ohms, minimum.

In general, use the center phase for single-phase coupling when there are no transpositions and modal analysis permits.

When trapping a relatively long line, the use of three traps is recommended at the tap point if the trapped line is ¼ wavelength of the operating frequency or if the tap is a transformer bank resulting in high PLC attenuation.

Line traps in all three phases may be treated as the equivalent of one line section of PLC separation within the operating frequency range of the traps.

Use of multiple series and parallel L/C tuner combinations (via line tuning units or high power filters) is recommended to provide isolation between widely separated transmitter/receiver groups and also to reduce bandwidth of outgoing and incoming RF energy.

Use reactive/skewed hybrids to isolate closely spaced transmitter/receiver combinations. Use resistive hybrids to isolate two closely spaced transmitters.

A.3.2. Factors Affecting Frequency Selection A tap point of a line should not be considered as a bus when determining the number

of line sections. An auto-transformer may be treated as the equivalent of one line section. Avoid second harmonic frequencies on the same bus and for at least two line

sections.

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Use lower frequencies on longer lines and higher frequencies on shorter lines. A “short line” is one with an attenuation (line and coupling losses) less than 10 dB or a physical length of approximately 20 miles or less. A “long line” is one with an attenuation more than 10 dB or a physical length in excess of 20 miles. Use the highest frequency possible while maintaining adequate operating margins to save the lower frequency spectrum for use on long lines.

Avoid PLC frequencies that correspond to low multiples of λ /2 or λ /4 (half or quarter wavelength of PLC frequencies, respectively) on short overhead lines.

Use frequencies that correspond to an odd multiple of λ /8 on overhead lines with low attenuation.

Use narrow band equipment where speed is not a constraint. Use power below 10 W where possible (i.e., 1-W guard, 10-W trip) to minimize

interference taking into account “bad” weather requirements (i.e., increasing noise and attenuation) of the PLC system.

Unless otherwise noted, parallel lines not terminating on the same bus will be treated as though they were, for PLC frequency selection purposes.

When PLC frequencies are to be applied to power cables, great care should be taken to minimize PLC losses due to the low characteristic impedance of the cable, series impedance mismatch at the coupling point, and standing wave reflections. This can often be done by using lower PLC frequencies, using PLC frequencies at λ /2 or multiples thereof, and by using extra-hi C coupling capacitors.

Although this guide identifies guidelines for PLC frequency selection, the following additional points require consideration to ensure proper PLC system operations:

Receiver Sensitivity Signal-to-Noise Ratio Requirements Receiver Selectivity Operating Margin, Including Transposition and Other Modal Loses Bad Weather Conditions Coordination with Adjacent Utilities Use of Voice Channels Line Tuners and Other Auxiliary Coupling Equipment Losses

A.4. Frequency Spacing by Equipment Type

A. .1. O4 n-Off (AM) Blocking Carrier

1. In general, minimum frequency separations for all lines terminating at the same bus in the Table A.1, below:



Table A.1 ON – OFF Carrier Frequency Spacing

Solid State Synthesized

Tube Type Crystal Controlled Wide Band Narrow Band

Without Voice Channel

10 Hz 4 kHz 4 Hz 2 kHz

With Voice Channel 6 kHz 4 Hz 4 kHz

The equipment manufacturers' instruction books should be consulted for more detailed information.

2. Repeat frequency no sooner than two buses away.

3. When ON-OFF and frequency-shift equipment is applied on the same bus, the greater minimum separation shall prevail.

A.4.2. Frequency Shift (FSK)

1. In general, minimum frequency separations for non-voice applications are indicated in the Table A.2, below:

Table A.2 FSK Carrier Frequency Spacing

Extra Wide Band Wide Band Narrow Band

Typical Band-Width 1000 Hz 500 Hz 200 Hz

One-Way Channel Spacing

2000 Hz 1000 Hz 500 Hz

Two-Way Channel Spacing

4000 Hz 2000 Hz 1000 Hz

The equipment manufacturers' instruction books should be consulted for more detailed information. F q re uency separations apply between:

a. All lines terminating on the same bus and one bus away; b. Transmitters and receivers located on lines parallel to the subject line; and c. Transmitters and receivers one bus away from lines parallel to the subject line.

2. Repeated frequency no sooner than two buses away. A received signal should be at least 40 dB above an interfering signal of the same frequency.

A.4.3. Single Sideband

1. e eral (SSB) Frequency Selection Guidelines G n



a. Transmitters connected to different lines on the same bus, using adjacent frequency bands and transmitting signals of equal power, should have 15 dB of isolation between them to minimize inter-modulation products. If the transmitters have different output power then 15 dB plus the difference in power should be used as the isolation guideline.

b. Receivers connected to different lines on the same bus, using adjacent frequency bands, and receiving signals of equal power should have at least 3 dB of isolation between them. If receiver levels are different, 3 dB plus the difference in power should be used as the isolation guideline [Adjacent SSB (receivers) channels typically have an inherent 50 dB of isolation due to the SSB modulation / demodulation process.]

c. Transceiver systems using the same frequency band should have 50 dB of isolation between a transmitter of one system and the receiver of the second system. Typically, a line section and two buses will offer this degree of isolation.

d. Transceiver systems on different lines on the same bus and using adjacent frequencies should have 25 dB of isolation between the transmitter of one system and the receiver of the second system. In addition, the transmitted level(s) should be 3 dB below the intended receive levels at the input to the local receiver.

e. A 4-kHz “guard band” between transmitter and/or receiver frequency bands offers approximately 10 dB of isolation.

f. If two SSB – PLC systems are to be placed on the same line(s), they should be interconnected with high-pass/low-pass filter networks with the crossover occurring at approximately 30 dB below the transmitter signal levels.

g. In general, it is assumed that there is 10 – 15 dB of isolation across a bus. h. Traps with a minimum impedance of 1,000 ohms should be used whenever

possible as a frequency conservation measure.

2. SSB – PLC Frequency Selection Guidelines for Various Typical Functions are overed in Table A.3, following. These functions include: c

a. Baseband Relaying • Directional Comparison Blocking and Unblocking – AM and FSK • Phase Comparison – AM and FSK • Transfer Trip – FSK

b. Audio Tone Functions • Relaying • SCADA • Voice • Telemetry




Table A.3 Single-Sideband Equipment Operating Parameters

Equipment Type Channel Speed

Signal to Noise Ratio

Required Operating

Margin Nominal Spacing

(See Note)

Nominal Bandwidth Freq. Shift

Max. Rec. Sens.

On/Off

(Baseband) 3 ms 15-20 dB 15 dB

FSK Transmitter Trip (Baseband)

25-30 ms 7 ms 4 ms

0 dB 5 dB 7 dB

25 dB 25 dB 25 dB

500 Hz 1500 Hz 3000 Hz

200 Hz 500 Hz

1000 Hz

5 mV 15 mV 15 mV

FSK Transmitter Trip

(Audio Tones)

6 ms 9 ms

16 ms

5 dB 0 dB -3 dB

10 dB 10 dB 10 dB

1000 Hz 340 Hz 170 Hz

480 Hz 170 Hz 85 Hz

Tones for Data 15 ms

Voice w/o Comp. 30 ms

Voice w/ Comp. 15 ms

SSB 4.5 dBm

Note: Function of Rec. Bandwidth (Typically 55 dB)

A.5. References Dowty RFL Industries, Communications Division. The PLC Handbook (PLC-79-1).

Boonton, NJ: Dowty RFL Industries, Inc., 1979. General Electric Company, Power Systems Management Business Dept. PLC

Applications Guide – Protective Relaying Channels (GET-6920). Malvern, PA: General Electric Company, 1985.

General Electric Company, Technology Center. Application Guide Relaying Communications Channels (GET-8034). Malvern, PA: General Electric Company, 1993

IEEE: Power Systems Communications Committee. IEEE Guide for Power-Line Carrier Applications (ANSI/IEEE Std 643-2004). New York: IEEE, 2005.

Ray, Roger E. “Channel Considerations for Power Line Carrier (RPL 83-3).” Coral Springs, FL: Westinghouse Electric Corporation, 1983.

IEEE: PSRC H9, “Special Considerations in Applying Power Line Carrier for Protective Relaying,” available at:

www.pes-psrc.org/

http://www.pes-psrc.org/


B.

Appendix B. Protection System Performance (PSP) Reporting Instructions

Protection System Performance (PSP) Working Group, November 1994

DRAFT – Edited and Reformatted by JWI, April 28, 2008

Changes made and “Notes” added to Page 11, JWI, July 9, 2008

Updated items in introduction and in “Notes” on page 11, JWI, October 21, 2008 B.

B.1. Introduction The System Protection Advisory Subcommittee (SPAS) has been collecting protection system performance data for the Bulk Power System (BPS) for many years. In late 1988, the Protection System Performance (PSP) Working Group was established to evaluate this data and to evaluated the established procedure. This report format and procedure is the result of the efforts of the working group to improve the reporting process.

B.2. Discussion The protection system has been categorized into three areas to better define the reporting procedure. A protection group consists of individual relays and communication packages and their associated instrument transformers, d.c., and trip coil equipments. The protection system is composed of a combination of protection groups, i.e., the primary and secondary protection groups. The entire system, from the instrument transformer to the breakers, will be referenced as a protection system. For the purpose of the PSP reporting system, a two terminal transmission line has two protection systems, one at each end. Protection System Performance reporting is on a per-terminal basis. Each terminal, should be reported separately. For example, a two-terminal transmission line fault that is cleared correctly normally will be counted as two “correct” protection system operations. Redundant protection groups are considered to be one protection system; if any or all of the protection groups operate correctly to clear a fault, the PSP will be recorded as one “correct” operation.

If there is a known misoperation of a protection group that did not compromise the performance of the protection system as a whole, then the misoperation should result in an incorrect code.

Protection System Performance data records are necessary only for automatic operations involving BPS facilities. A separate PSP record should be completed for each event. An event is defined as any set of conditions, resulting in the unscheduled operation of the protection system. Operations that occur during commissioning, before the protection system is turned over to System Operations, should not be reported. A single PSP record should be used to record from the initiating condition to the auto reclosing. Subsequent relay operations should receive individual PSP records. Operations resulting from manual

NYISO Operations Engineering Staff B-1 Version 1.0 10/29/2009


or supervisory close will be considered a separate event, whether the manual or supervisory close occurs during or after the auto reclose cycle. Additional comments describing the event should be listed at the bottom of each report. It is important that all reports that contain incorrect operations have sufficient comments to facilitate analysis and assessment of preventative strategies.

A single event could cascade into additional events, such as a transformer failure due to a through fault or a breaker failure. A new PSP report should be filed for each additional event. A breaker failure is the failure of a breaker to open correctly. For this condition, the PSP should be coded as incorrect because the intended breaker failed to clear the fault (Code IBR in section B.4). The first event cascades into a second event, which is entered on an additional report with an initiating condition entered an equipment failure. If a line terminal trips, automatically recloses, and trips again, count two operations, but consider the sequence to be all part of the same event.

In tabulating the year's operations, it was decided to categorize the Disturbance- and Non-Disturbance–Initiated events separately. For this purpose, a disturbance is defined as an unplanned event that causes an abnormal system condition or any perturbation to the electric system.

B.3. General Instructions Each member system will report on operations of their own relays/circuit breakers. It is the responsibility of each member to coordinate multiple PSP reports that have a common initiating event. Operations at a “foreign terminal” are not to be reported. For this purpose, a foreign terminal is defined to be the tie line terminal outside New York.

Each member should evaluate their own operations that are coded “incorrect” to determine the underlying cause of the error. The cause of personnel-initiated operations should be reviewed closely by the individual members. Operations that result from an incorrect application, setting, or equipment failure should not be credited to field personnel. If a condition exists that causes an operation when correct work practices are being followed, then the operation should be coded “incorrect” due to the ultimate cause of the event. If the work practice or procedure is incorrect, then the error should be charged to whatever group is responsible for establishing the procedure. If a technician causes a misoperation as a result of not following proper work practices, it should be coded as a personnel error.

Personnel: Personnel-initiated events are generally to be coded N (non-disturbance), except in the case of an error that actually results in a power system disturbance. A primary circuit switching error that causes a disturbance may still result in the correct operation of the protection system. An operation initiated by errors made by personnel while working on a protection system would be coded “incorrect.” Personnel listings in section B.4 refer to the functions being performed at the time of the misoperation. These listings are not necessarily job titles.

Controls: Operations originating with power plant, static VAr compensator, and HVdc control systems will not be reported. This includes reverse power sequential tripping schemes. Also, operations initiated by the loss of oil pressure in a cable or a water pump within a cooling system will not require a PSP report. Reclosing information has been

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included on the PSP report strictly for the purpose of gathering data on automatic restoration. Although it is normally considered part of the protection system, the reclosing relay is not necessary for clearing faults. Failure of a reclosing relay to operate shall not be considered an incorrect operation for the purposes of filling out a PSP report. Also, breaker trips caused by low gas or low air-pressure controls will not be reported. Breaker pole disagreements that initiate breaker failure protection system tripping of adjacent/remote breakers should be reported.

An entry of “U.I. ” (Under Investigation) in section B.4 indicates an event that is unresolved. This event will not be counted until a finalized record has been submitted.

Pilot: If a line fault is cleared by a time-delayed backup relay, and this line has pilot protection, it should be considered that the pilot group failed to operate correctly and the protection system failed to operate in its design time. Thus, the protection system operation should be coded “incorrect” at the slow-tripping terminal. Likewise a pilot group overtrip will also be recorded as a single protection system “incorrect” at the tripping terminal. These “incorrects” will be coded “ICO, ” for Incorrect Communications.

Direct Transfer Trip: If, during routine testing, an erroneous direct transfer trip signal is sent and trips a breaker(s) at a remote station, the PSP procedure will be initiated by the receiving end utility in conjunction with the sending end utility. Two reports will result: The receiving end utility reports a correct protection system operation at its terminal, and the sending end utility reports the personnel incorrect at its terminal. A transmission line terminal that trips or fails to trip due to direct transfer trip channel noise (no fault detection devices participating at the receiving terminal, no sending terminal participation) is to be coded as incorrect "I-CO," at the receiving terminal.

B.4. Coding Instructions

B.4.1. Participant CE – Consolidated Edison Company of New York, Inc.

CH – Central Hudson Gas and Electric Corporation

LI – Long Island Power Authority

NG – National Grid

NY – New York State Electric and Gas Corporation

OR – Orange and Rockland Utilities, Inc.

PA – New York Power Authority

RG – Rochester Gas and Electric Corporation

B.4.2. File Number Each participant will use consecutive numbers beginning with |_._.1|.



B.4.3. Date/Time Date |M.M| |D.D| |Y.Y|

Time |H.H| |M.M|

Time should be stated in twenty-four hour format local time, i.e., EDT or EST, whichever is in effect.

(Seconds and milliseconds will be added in the future.)

B.4.4. Event

B.4.4.1. Initiating Condition The root cause regardless of whether the operation being described involves a power system fault. The prefix on the field designates whether it was a power system disturbance (D) or not (N). A full listing of the required inputs for this field can be found in the Event Table, on page B-7.

B.4.4.2. Resulting Condition This condition can include a specific fault or power swing. The prefix on the field designates whether it was transient (T) or permanent (P). A full listing of the required inputs for this field can be found in the Event Table, on page B-7.

B.4.4.3. Element/Location The element at or on which the initiating event occurred. A full listing of the required inputs for this field can be found in the Event Table, on page B-7. The identification/location of this element can be included in the comments.

B.4.4.4. Circuit/Equipment Affected BPS element or failed breaker.

B.4.4.5. Auto Restore Auto Restore records whether the affected circuit/equipment on both ends, if appropriate, was successfully restored to service without an operator taking action. (Y/N)

B.4.4.6. Auto Reclose Auto Reclose indicates whether an auto reclose was attempted. This item with the previous item will confirm the success of the auto-reclose attempt. (Y/N)

B.4.4.7. High-Side Voltage Voltage level of circuit/equipment above. For a transformer use high-side voltage.

B.4.4.8. Station Location of the protection system listed in the following item.



B.4.4.9. Protection System I.D. Identification of the BPS Protection System that operated for the given event. This is not used for statistical purposes but is mainly for the NYPP member to describe what operated. Enter the breaker or breakers that operated or some other description that, to you, most closely identifies what operated.

B.4.4.10. Protection System Operations This is a three-part entry:

No (abbreviation for number) Count one (1) in this column for each protection system operation at each line terminal. The entry should always be one (1) or greater.

Code as follows:

|C._._| Correct

|I.A.P| Incorrect – APplication

|I.S.S| Incorrect – Setting Specification

|I.S.A| Incorrect – Setting Applied

|I.E.N| Incorrect –- ENvironment at protection system

|I.C.T| Incorrect – Current Transformer

|I.V.T| Incorrect – Voltage Transformer, including fuses

|I.C.W| Incorrect – Cable and Wiring

|I.B.A| Incorrect – BAttery/Charger/DC fuses

|I.R.#| Incorrect – Relay

The incorrect relay entries to replace the #’s are listed in Table B.3. Incorrect includes failure of protection system to operate in design time.

|I.C.O| Incorrect – COmmunication (Complete Line Package and/or DTT Package)

|I.N.L| Incorrect – Not Listed

|I.U.N| Incorrect – UNknown

|I.B.R| Incorrect – BReaker

|I.U.I| Incorrect – Under Investigation

|I.T.P| Incorrect – Test: Plan, hardware, software

|I.P.#| Incorrect – Personnel

The incorrect personnel entries to replace the #’s are listed in the Incorrect-Personnel Table which follows.



B.4.5. Pilot System Packages This section is to be used to evaluate the pilot systems associated with Bulk Power protection schemes only when there is an incorrect protection system operation due to communications. Use a separate line to report each communications package operation.

B.4.5.1. Line Package This is used to evaluate “line pilot” schemes, i.e., whether communication signals were sent and/or received.

This is a three-part entry, consisting of:

|I._._._| Incorrect (There is no reporting for corrects. Incorrect includes failure to operate.)

Communications Medium

|_.C._._| power line Carrier

|_.T._._| Telephone type circuit

|_.M._._| Microwave

|_.F._._| Fiber optic

Pilot Protective System

|_._.B.C| Blocking Carrier

|_._.P.C| Phase Comparison

|_._.U.B| UnBlocking

|_._.D.U| Direct Underreaching

|_._.P.U| Permissive Underreaching

|_._.P.O| Permissive Overreaching

|_._.P.W| Pilot Wire (Current Differential)

B.4.5.2. DTT Package This is used to evaluate “direct transfer trip” schemes, such as transformer, bus, breaker failure protection, or SPSs.

This is a two-part entry, the same as the first two parts of the Line entry:

|I._| Incorrect (There is no reporting for corrects. Incorrect includes failure to operate.)

Communications Medium

|_.C| power line Carrier

|_.T| Telephone type circuit

|_.M| Microwave

|_.F| Fiber optic



B.4.6. Comments Comments should be entered to describe the event.

B.4.7. Submitted By Person responsible for submitting the record and the date completed.

Table B.1 Event Table

EVENT TABLE

INITIATING CONDITION RESULTING CONDITION ELEMENT

(D) DISTURBANCE (N) NON-DISTURBANCE

(T) TRANSIENT (P) PERMANENT

ANIMALS 3 PHASE BREAKER

COMMUNICATIONS DOUBLE PH-GND BUS

CONST. EQUIPMENT NO-FAULT CABLE

CONTROLS OPEN PHASE CAPACITOR

EQUIPMENT FAILURE PHASE TO GND CONDUCTOR

EXTERNAL EVENT (REMOTE)

PHASE TO PHASE CONVERTER VALVES

FIRE POWER SWING CT

LIGHTNING UNKNOWN FUSE

OTHER GENERATOR

PERSONNEL OVER EXCITATION INSULATOR

PROCEDURE NONE

RELAY PHASE-SHIFTER

SWITCHING POTHEAD

TREE PT

UNKNOWN REACTOR

VEHICLE STRUCTURE

VIBRATION SURGE ARRESTOR

WEATHER SWITCH

TRANSFORMER

UNKNOWN

Note: Add initiating condition “tower construction.”



Table B.2 Incorrect Personnel Table

INCORRECT-PERSONNEL TABLE

P1 WIRING INVOLVED IN WIRING IN OR AROUND THE SUBSTATION

P2 RELAY CALIBRATION INVOLVED WITH RELAY CALIBRATION See NOTE

P3 RELAY TRIP TESTING PERFORMING TRIP TEST See NOTE

P4 CONSTRUCTION UTILITY WORKER

P5 CONSTRUCTION NON-UTILITY WORKER

P6 COMMUNICATIONS UTILITY WORKER

P7 COMMUNICATIONS NON-UTILITY WORKER

P8 OPERATING/SWITCHING INVOLVED WITH SWITCHING PROCEDURES

P9 OTHER OR UNKNOWN

Note: Codes IP2 and IP3 are not misoperations as defined by NPCC and NERC. The NPCC definition is contained in document B-21, revised 09/04/2008, and the current NERC definition is contained in the NERC “Glossary of Terms Used in Reliability Documents,” dated February 12, 2008. The NERC definition is under revision.

Note: Add P Code for Commissioning Testing In-Service Checks.



Table B.3 Incorrect Relay Table

INCORRECT-RELAY TABLE IR1 MISSING PART

IR2 VENDOR DOCUMENTATION

IR9 OTHER

IRA ELECTROMECHANICAL RELAY ALIGNMENT DRIFT (ALIGNMENT IS OTHER THAN SETTING)

IRB ELECTROMECHANICAL RELAY COMPONENT FAILURE NOT COVERED BY SERVICE LETTER

IRC ELECTROMECHANICAL RELAY COMPONENT FAILURE COVERED BY SERVICE LETTER

IRD ELECTROMECHANICAL RELAY CALIBRATION DRIFT

IRF ELECTROMECHANICAL RELAY INTERNAL CONNECTION

IRG ELECTROMECHANICAL RELAY CONTAMINATION

IRH ELECTROMECHANICAL RELAY UNKNOWN

IRJ SOLID STATE RELAY COMPONENT FAILURE NOT COVERED BY SERVICE LETTER

IRK SOLID STATE RELAY COMPONENT FAILURE COVERED BY SERVICE LETTER

IRL SOLID STATE RELAY CALIBRATION DRIFT

IRM SOLID STATE RELAY INTERNAL CONNECTION

IRN SOLID STATE RELAY CONTAMINATION

IRO SOLID STATE RELAY UNKNOWN

IRQ MICROPROCESSOR RELAY COMPONENT FAILURE NOT COVERED BY SERVICE LETTER

IRR MICROPROCESSOR RELAY COMPONENT COVERED BY SERVICE LETTER

IRS MICROPROCESSOR RELAY CALIBRATION DRIFT

IRT MICROPROCESSOR RELAY INTERNAL CONNECTION

IRU MICROPROCESSOR RELAY CONTAMINATION

IRV MICROPROCESSOR RELAY SOFTWARE PROBLEM DUE TO CODING/ALGORITHM ERROR

IRW MICROPROCESSOR RELAY SOFTWARE PROBLEM DUE TO FIRMWARE OR SOFTWARE COMPATIBILITY PROBLEM

IRX MICROPROCESSOR RELAY UNKNOWN

Note: Add IR Code for CCVT Transient.



C.

Appendix C. Forms

Relay Characteristics Form

Clearing Times Form

Reclosing Data Form C.

NYISO Operations Engineering Staff C-1 Version 1.0 10/29/2009


C.1. Relay Characteristics Form

Line No.

Line Name

Terminal

Base Voltage

Submitted by Date

Protection System 1 Protection System 2

Type of Relay Scheme

CT Ratio

PT Ratio

Which Zone initiates Pilot Scheme?


Zone 1

Angle of Max Torque (Enter 0 for reactance relay)

Setting in Secondary Ohms

Offset in Secondary Ohms

Setting in Primary per unit (100 MVA base)


Zone 2





C-2 NYISO Operations Engineering Staff Version 1.0 10/29/2009



Zone 3





Please attach RX plot with notations, or any other information necessary to describe protection systems for modeling.

Number of pages attached



C.2. Clearing Times Form

Line No.

Line Name

Terminal

Base Voltage

Submitted by Date

Clearing Times Viewed from the Terminal

Near End Fault (in cycles)

Far End Fault (in cycles)



C.3. Reclosing Data Form

Line No.

Line Name

Terminal

Base Voltage

Submitted by Date

NO YES IF YES, BREAKER RECLOSING TIME*

HIGH SPEED RECLOSING*

DELAYED RECLOSING*

FIRST SHOT – Hot bus dead line

If there is no hot bus dead line reclosing at this end, i.e., reclosing is by sync check only, or not at all, choose NO.

SECOND SHOT – Hot bus dead line

If there is no second shot, choose NO.

THIRD SHOT – Hot bus dead line

If there is no third shot, choose NO.

* Definitions of terms are in the NPCC Bulk Power System Reclosing Guide, Document B-1, dated 03/11/2009.
