SEL Relays New York Application Guide

APPENDIX A

CANANDAIGUA FUNCTIONAL SPECIFICATION

POINT OF INTERCONNECTION (POI) GUIDE

NEW YORK ELECTRIC SYSTEM ENGINEERING

115-230kV POINT OF INTERCONNECTION STATION GUIDE

SPECIFICATION: SPR-967 REVISION 4: NOVEMBER 14, 2006 REVIEWED BY: DATE: APPROVED BY: DATE:

Table of Contents

Introduction.................................................................................... 1

General Requirements................................................................... 1 Ring Bus.................................................................................................................................................... 1 Location of POI Station............................................................................................................................ 2 POI Station Ownership............................................................................................................................. 2 Security...................................................................................................................................................... 2 Collector Station Adjacent to POI ............................................................................................................ 2 Remote Collector Stations ........................................................................................................................ 3 Isolation Breakers...................................................................................... Error! Bookmark not defined. NPCC Bulk Power System Protection Criteria ........................................................................................ 3 Station Requirements................................................................................................................................ 4 Surge Arresters ......................................................................................................................................... 4 Metering .................................................................................................................................................... 4 POI Station SCADA.................................................................................................................................. 4 Automatic Reclosing ................................................................................................................................. 5 Station Service .......................................................................................................................................... 6 DC Systems................................................................................................................................................ 6 Monitoring ................................................................................................................................................ 6 Relay Communications............................................................................................................................. 6 Telephone Circuit Protection ................................................................................................................... 7 Current Transformers............................................................................................................................... 7 Potential Transformers............................................................................................................................. 7

Protective Relays and Devices ...................................................... 7 Protection General .................................................................................................................................... 7 SEL-351A Control, Breaker Failure (11C), Reclosing, and Metering Relay ......................................... 8 SEL-311C High Speed Phase and Ground Distance Relay (11A) .......................................................... 9 SEL-421 High Speed Phase and Ground Distance Relay (11B)............................................................. 9 SEL-587Z High Impedance Bus Differential Relay (87B1).................................................................... 9 BE1-87B High Impedance Bus Differential Relay (87B2) ..................................................................... 9 SEL-351A Directional Overcurrent Relay (67/67N).............................................................................. 10 95 Maintenance Switch .......................................................................................................................... 10 SCO Switch ............................................................................................................................................. 11

79CO Switch............................................................................................................................................ 11 94X Relay ................................................................................................................................................ 11 Switchboard Lights ................................................................................................................................. 12 Flexitest Test Switches............................................................................................................................ 13

Appendix....................................................................................... 14 SEL-421/LN1 I/O Connections (11A) .................................................................................................... 14 SEL-351A/Bkr 1 I/O Connections (11C) ............................................................................................... 15 SEL-311C/LN1 I/O Connections (11A) ................................................................................................. 16 SEL-351 BUS I/O Connections (67/67N) ............................................................................................. 17 SEL-587Z BUS I/O Connections (87B) ............................................................................................... 19 POI RELAY PREFERED PROTECTIVE RELAY LIST ..................................................................... 20 95 SWITCH LAYOUT ............................................................................................................................ 21 ALARM AND CONTROL POINT DEFINITION GUIDELINES....................................................... 22

Drawings Typical Power One Line Electrical Diagram

Typical Relay One Line Diagram

Typical Detailed Relay One-Line Sheets (under development)

Typical Logic Diagrams (under development)

Typical Panel Front Views & Bill of Material CR-7962, Sheets 1-3 (under development)

NEW YORK ELECTRIC SYSTEM ENGINEERING 115-230kV POINT OF INTERCONNECTION STATION GUIDE

SPR-967 REVISION: 4 DATE: November 14, 2006

NYSEG-RGE 115-230Kv POI Station Guide SPR-967 Rev 4 November 14 2006.doc Page 1 of 26

Introduction

NYSEG/RGE has developed a Point of Interconnect (POI) Station Guide for the addition of non-utility generating facilities. This Guide includes a typical Power One Line Diagram, Relay One Line Diagram, detailed Relay One Line Diagram, Logic Diagrams, Relay Bill of Material, Panel Front Views and Diagram. As the Guide develops further, it will include templates for relay logic and settings as well as a standard Operational Check Procedure. The IPP Developer will be responsible for the detailed design of each station. The intent is that this guide is to facilitate communications and reduce the design, review and approval time.

General Requirements Ring Bus NYSEG/RGE requires a Ring Bus for all Point of Interconnection (POI) Stations 115kV and above. The only exception is when the proposed interconnection is to a dedicated radial line into an existing NYSEG/RGE substation where a different breaker arrangement will be required. The three breaker ring is good utility practice and considers protection, operation, and maintenance. Each of these considerations is discussed below in more detail. Protection of a three terminal line is inherently more difficult than a two terminal line. This is especially true where there are unequal line segment lengths and variable sources at each terminal. This is because a strong infeed of current from one terminal can increase the apparent impedance seen by a distance relay from another terminal. Similarly, the injection of current such as from a strong ground source in the middle of a line can change the response of overcurrent relays at the end terminals. Segmenting a three terminal line into two lines with a ring bus simplifies the protection and improves the dependability and security of the transmission system. Operation of an IPP is improved with a ring bus. The IPP can remain in service following the loss of one of the line segments connecting to the utility. Maintenance is simplified with a ring bus. A ring bus configuration permits maintenance on any circuit breaker without taking lines or generators out of service. A typical POI Ring Bus Station One Line Diagram is provided. Good faith cost estimates at the feasibility stage are based upon this diagram. Results of the System Reliability Impact Study (SRIS) may dictate modifications to this typical interconnection.




Isolation Breakers NYSEG/RGE requires a breaker owned and operated by the IPP to isolate the IPP facilities (line or transformer) from the POI Station. NYSEG/RGE must have the ability to trip and lockout this breaker. Assess to this breaker shall not be via the POI station. NYSEG will have the ability to open this breaker from the POI station or remotely via SCADA. Any Maintenance control switches that could defeat this operability by NYSEG shall have their position indicated to NYSEG’s SCADA and POI station. Location of POI Station The POI Station may not be located on a NYSEG/RGE Right of Way. The transmission line taps to the POI Station must be designed such that if the Station is no longer used and useful, it may be disconnected with minimal effort and the transmission line restored to its original position. POI Station /Collector Station Seperation The line of separation between the POI Station and the Collector is normally the point where the revenue meter is located. The Collector Station and the POI Station shall be separated by a chain link fence. The IPP developer will not be allowed unescorted access to the POI station. It is expected that NYSEG will operate and maintain the POI substation. Actual ownership will be a point for discussion in the operating agreement or other contract documents. Security All NYSEG/RGE station documents provided to developers and contractors are considered protected and critical infrastructure information and access shall be limited. Contractors working on NYSEG/RGE facilities are required to have security checks. Security related design criteria that must be followed includes:

• A clear space of at least 10 feet must be maintained on the exterior of all fences. • Station buildings may be no closer than 10 feet from the fence. • Direct road access must be limited. If a long access road is required there shall be

a road gate. • A long access road shall not terminate directly at the station fence or gate. • Intrusion detection is required and will be specified. Some intrusion devices may

be installed by NYSEG personnel after the station is completed. Collector Station Adjacent to POI The Collector Station is owned, operated, and maintained by the IPP developer. Equipment within the Collector Station typically includes the main step up transformer and its associated high side breaker, a low side feeder bus, three lowside potential




transformers, a house service transformer, feeder breakers, and feeder circuits each with a potential transformer. The main transformer is typically configured as a wye-delta-wye, solidly grounded on both sides. The ground grid must be continuous between the Collector Station and the POI Station. If the Collector Station is remote from the POI Station, the interconnecting transmission line is typically owned, operated, and maintained by the IPP developer. Remote Collector Stations If the collector station is remote from the POI station, it will be necessary to install high speed protection on the line connecting the two stations. Since this will be new line construction, an optical ground wire (OPGW) could provide the communications media for this high speed protection. Typically, current differential relaying would be provided for the “A” relay package. The piloted step distance or directional ovwercurrents with transfer trip may be required for the “B” relay package NPCC Bulk Power System Protection Criteria All NYSEG/RGE substations classified as bulk power by the NPCC shall be designed and constructed according to NPCC Bulk Power Protection Criteria. NPCC references may be found at www.npcc.org. The protection criteria is the A-5 document. Other related documents include A-2 and A-4. All other substations, 115kV and above shall be designed such that they could be made to meet NPCC Bulk Power System (BPS) Protection Criteria. This means that each element of the station is to be protected by two independent protection groups, the groups must be physically separated, and no common failure can disable both systems. The full NPCC BPS Protection Criteria should be considered during the station design. Specifically, the following criteria must be met.

1. There will be two independent high speed groups covering each zone of protection. These groups may be of the same manufacturer but should not utilize the same technology. The schemes shall be physically separated.

2. Generally, the line protection requires at least one piloted trip scheme. The second scheme should be designed such that it could be made into a piloted scheme.

3. There may be only one station battery at 115Kv; however, it should be possible to add a second battery in the future with minimal effort. 230Kv & above stations shall have two batteries each capable of supplying the complete emergency load of the station (reference NPCC A-4). DC for the A and B protection schemes shall be fed from physically separate DC panels.

4. Each 115kV (or 230kV) breaker shall have two trip coils. 5. Instrument transformer and control cables associated with A and B protection

schemes should be physically separate. 6. There shall be two independent house service supplies with an Automatic

Transfer Switch (ATS). No single contingency should be able to disable the house service.

7. Means shall be provided to trip local and remote backup breakers for a failed breaker.




8. Although the NPCC BPS protection criterion does not require redundant breaker backup schemes, NYSEG/RGE requires redundant breaker backup schemes to allow for relay maintenance. This guide provides space for future second breaker backup schemes should they be required.

Station Requirements Surge Arresters NYSEG/RGE uses two ratings for 115kV surge arresters depending upon whether or not the system is effectively grounded. If the system is effectively grounded for all single contingencies, i.e. the system R0/X1 < 1 and X0/X1 < 3; then use a 96kV rated arrester with a 76kV MCOV. If the system is not effectively grounded use a full voltage 120kV arrester with a 96kV MCOV. Arresters are typically applied on each line terminal and on each side of a transformer. Arresters are not typically required on buses unless the station is unshielded. The 230Kv system is effectively grounded and uses arresters with a duty cycle of 72Kv and a 140Kv MCOV. Metering NYSEG/RGE will furnish, install, and commission the revenue metering including the instrument transformers. Revenue metering includes megawatts, megavars, megawatt hours, volts, amperes, and frequency. The revenue metering is tied to the Supervisory Control and Data Acquisition (SCADA) Remote Terminal Unit (RTU) through a DNP 3.0 connection. If a merchant generator wishes to receive instantaneous base points for dispatch from the NYISO, the megawatt and megawatt hour quantities must come from the revenue billing meter. The revenue meter must have a dedicated standard dial up line for data collection purposes or a dedicated port of a phone switch. POI Station SCADA NYSEG/RGE requires a Remote Terminal Unit (RTU) for SCADA. NYSEG/RGE will specify and commission the RTU. POI Station breaker, status, and metering is contained in an SEL-351 relay dedicated to each breaker. The RTU must be powered from the substation battery. A 4-wire leased telephone facility will need to be ordered and procured by the developer. The telephone equipment msut be powered independent of the station AC power. Copies of the orders must be supplied to NYSEG/RGE. The RTU control output contacts are normally open contacts. When a control sequence is initiated, the normally open contact will close momentarily for 250 milliseconds and than reopen. This applies to both trip and close controls for the circuit breakers. Status points use an "a" contact to indicate the normal state of an alarm and the open state of a circuit breaker.




The Developer, as a Merchant Generator, needs to determine if they wish to receive instantaneous base points for dispatch from the NYISO, these can be supplied through the RTU in DNP 3.0 protocol. This decision affects both the RTU specification and the RTU cabinet size. Being a Merchant Generator requires that NYSEG/RGE send instantaneous megawatt and megawatt hour output of the plant to the NYISO. These quantities are used for both NYISO billing and operational purposes at the NYISO. Both the megawatt and megawatt hour quantities must come from the revenue billing meter. This is accomplished by using an RS485 connection between the revenue meter and the NYSEG/RGE RTU. DNP 3.0 protocol is to communicate megawatts, megavars, volts, frequency, amps and megawatt hours. Amperes, watts, vars and volts for each line are derived from the SEL-311C and/or SEL-421 protective relays. The relays are connected to the RTU through an RS485 connection using DNP 3.0 protocol. The interconnection metering (amps, watts, vars, volts, frequency) is derived from the revenue meter. The NYSEG/RGE RTU will be specified and commissioned by NYSEG/RGE. At present NYSEG uses QEI RTU’s and RG&E uses Telvent 3030 RTU’s. The RTU will typically require two (2) 16 point status panels and one control panel. The cabinet size may be either the 36"x30"x16" wall mount or the 60"x36"x18" free standing type cabinet (if instantaneous base points from the NYISO are needed). Automatic Reclosing Note diagram below. Breaker 1 is the tie breaker in the ring bus. Breakers 2 and 3 are the line breakers in the ring bus. Breaker 4 is the IPP isolation breaker. Typical initiation and supervision of the automatic reclosing is listed below: Breaker No. Automatic Reclose

Initiation Supervision

1 Line 1 or Line 2 trip Sync. Check 2 Line 2 trip Dead Line/live bus or Sync. Check 3 Line 1 trip Dead Line/live bus or Sync. Check 4 IPP System Trip Dead Line/Live Bus

Breaker 4 will be allowed to close once after fault initiated trip, if that reclose fails the IPP must patrol the line / inspect the station before a second close is attempted. Consider the following hypothetical system. There are two wind farms with ring buses connected to the same 115kV transmission line between Breakers A and D. Each line segment will receive one dead line shot from each terminal at either 10 or 20 seconds.




The B2, B3, C2, and C3 on the ring bus will perform the dead line shots. If successful, the remote terminal will then reclose with synchronism check. Finally, B1 or C1 will close the ring on synchronism check.

A DC1B1

B3B2

B4

C3C2

C4

10 DL OR SC40 SC 30 SC 30 SC 20 DL OR SC

40 SC

20 DLORSC

10 DLORSC

NO RECL 60 DL

20 DLORSC

10 DLORSC

Station Service The POI Station requires two independent sources of single phase AC power. One source may be from the Collector Station. Other possible sources are local distribution , station service transformer, or local diesel. The Collector Station does not require two independent sources of AC power. DC Systems If the interconnection is not part of the Bulk Power System only one station battery and one battery charger is required. However, two DC distribution panels are required. One DC distribution panel will supply the “A” relays and one distribution panel will supply the “B” relays. Monitoring Reference alarm and control point definition guidelines attached. NYSEG/RGE requires that all major POI Station equipment be monitored. This includes breaker trouble Station Service, Station Service Transfer, Battery Trouble, Loss of DC, Loss of Relay Potential, Relay Trouble, Communication Alarms, Control Switches in abnormal positions, building alarms, and other alarms as may be required by the NYSEG/RGE Alarm Guideline. In addition all numerical relays are to be monitored through a communications processor with a modem accessible to the NYSEG/RGE System Protection Engineer. Relay monitoring for the POI Station is not accessible to the IPP developer. Relay Communications




Relay communications requirements cannot be specified until the completion of the SRIS; however, the IPP Developer should anticipate that a least one piloted relay scheme is required at 115kV and two piloted schemes are required at 230kV. If the transmission line presently is equipped with Power Line Carrier (PLC), then PLC will be the first choice of communications if frequencies are available. The customer should anticipate that new PLC wave traps, tuners, transmitters, and receivers will be required at the existing remote terminals. If a completely new communication system is required, fiber optics is the first choice and leased telephone lines are the second choice. The leased telephone line option will require two-frequency audio tone equipment. Where power line carrier is applied, the coupling is done through a single phase capacitor coupling device on the line side of a single phase trap. If availability of power line carrier frequencies is an issue, three phase line traps may be required. Telephone Circuit Protection All leased telephone lines entering an electric station require circuit protection. This protection, generically referred to as a Positron, is specified by the local telephone company. Current Transformers The performance of the current transformers in the POI station must be verified by calculation considering the total burden and fault duty. This is especially important in differential protections. Generally, ANSI C800 relay accuracy CTs are used for protective relays on 115kV systems and above. Meter accuracy current transformers may not be used for protective relays. Voltage Transformers Voltage transformers are to be used at 115kV and 230kV. Each potential transformer is to have an A and B secondary winding. Each winding is to have a 115 volt phase to phase connection for protective relays (A & B systems respectively) and a 115 volt phase to ground connection for metering and synchronizing. If the POI is determined to be part of BPS, a separate set of potential devices, typically CCVT’s are required on each line.

Protective Relays and Devices Protection General




Specific protection requirements are identified during the facility study. The SRIS will determine the critical switching times and hence the need for piloted protection group (communications). NYSEG/RGE has developed a typical protection package that covers most 230kV and 115kV Point of Interconnection Stations. Any good faith cost estimates are based upon these diagrams. Below is a description of the protective relays and devices shown on the typical POI Station One Line. SEL-351 Control, Breaker Failure (11C), Reclosing, and Metering Relay This is a Schweitzer Engineering Laboratory numerical overcurrent relay that provides automatic reclosing and breaker backup logic for one breaker. The breaker backup function in this relay will detect if the breaker fails to open or fails to clear a fault. If the breaker backup function operates, an output from this relay operates a hand reset lockout relay (86BF) which will send trip commands to all necessary local breakers, block automatic reclosing, and initiate appropriate direct transfer trips to remote breakers. The breaker failure function requires Breaker Failure Initiation (BFI) from all the adjacent “A” and “B” scheme protective and lock out relays. Note if “A” & “B” breaker failure schemes are provided the “A” scheme is initiated by “A” protective devices and follows through and trips the “A” trip coils of adjacent breakers and the “B” breaker failure scheme likewise is initiated and operates “B” protection & control devices. If the breaker is called upon to trip, the BFI through a low set current Fault Detector (50FD) starts a Breaker Backup Timer (62BF). At the same time an additional trip (re-trip) signal is sent to Trip Coil 2 (TC2) to give the breaker a final chance to open. If the timer times out, an output operates the 86BF lockout relay. The 86BF relay trips the appropriate local breakers and initiates transfer trips to the appropriate remote terminals. In the breaker backup for Breakers 2 and 3, the 50FD fault detector is paralleled with an auxiliary switch in the breaker (52a) which indicates the status or position of the breaker. This is required when the fault current could be low such as a high impedance fault in a transformer. The Maintenance Test Switch (95) must be in the NORMAL position in order for the 52a switch to arm the breaker failure scheme. Refer to the logic diagrams for more detail on the operation of each breaker failure scheme. The reclosing function in this relay will automatically close the breaker following a typical line fault. Reclosing is initiated by inputs (RI) from the line protection. Breaker failure initiation and reclose initiation are sometimes the same inputs. When this occurs, the reclose initiation inputs are used for both functions (IN102) in the SEL-351 and any additional breaker failure initiation uses another input (IN104). Automatic reclosing must be blocked in instances such as for third zone line faults and Line Energization (50LE). IN103 is reserved for these inputs from the line protection relays. Separate close and reclose outputs are required from this relay to accommodate manual blocking of reclosing with the reclosing cutoff switch (79CO) and to provide synchronism or voltage checks with a supervisory close operation. The 94XA and 94XB relays discussed in a later section will stop automatic reclosing if a there is a manual trip or a SCADA trip. Refer to the logic diagrams for more detail on the reclosing schemes.




SEL-311C High Speed Phase and Ground Distance Relay (11A) This is a Schweitzer Engineering Laboratory numerical relay that provides high speed piloted distance line protection, Line Energization (50LEA), Fault Location (FL), and line metering. This relay is used in all cases for the “A” Scheme, regardless of whether there is a need for a piloted trip. When a piloted scheme is required, this relay may be used with audio tones, power line carrier, or direct fiber using the internal “SEL Mirror Bits”. It is typically used in either a POTT Scheme or a directional comparison blocking scheme (DCB) using power line carrier. This will provide high speed protection for the entire length of the line with backup or slower protection for end of line faults or faults beyond the end of the protected line in case there is a remote relay or breaker failure. SEL-421 High Speed Phase and Ground Distance Relay (11B) This is a Schweitzer Engineering Laboratory numerical relay that provides high speed piloted distance line protection, Line Energization (50LEB), Fault Location (FL), and line metering. This relay is used in all cases for the “B” Scheme, regardless of whether there is a need for a piloted trip. When a piloted scheme is required, this relay may be used with audio tones, power line carrier, or direct fiber using the internal “SEL Mirror Bits”. It would typically be used in a Permissive Overreaching Transfer Trip (POTT) Scheme. This will provide high speed protection for the entire length of the line with backup or slower protection for end of line faults or faults beyond the end of the protected line in case there is a remote relay or breaker failure. If the POI Station is determined to be part of the Bulk Power System, the SEL-421 will provide a second set of breaker backup protection. SEL-587Z High Impedance Bus Differential Relay (87B1) This is a Schweitzer Engineering Laboratory numerical relay used for high speed bus protection. The zone of protection includes Breakers 2, 3, and 4 and all the structure enclosed by these breakers. This relay operates an auxiliary lockout relay (86B1) which trips Breaker 2, 3, and 4, initiates breaker failure in 11C/Breaker 2 , 11C/Breaker 3 and Breaker 4. and shorts the thyrites internal to the 87B1 relay. If the Collector Station is immediately adjacent to the POI Station, dry trip and block contacts of the 86B1 relay are handed off to the Collector Station. If the Collector Station is farther than 500 feet from the POI Station, a fiber optic interface (SEL-2505) is required. Bus 1 is not automatically reclosed for a bus fault. BE1-87B High Impedance Bus Differential Relay (87B2) This is a Basler, high speed bus differential relay applied as the second bus protection. The zone of protection includes breakers 2, 3, and 4 and all the structures enclosed by




these breakers. This relay operates a hand reset lockout relay 86B2 which trips breakers 2, 3, and 4 and initiates breaker failure in 11C/Breaker2, 11C/Breaker 3 and Breaker 4 and shorts the thyrites internal to the 87B2 relay. SEL-351 Directional Overcurrent Relay (67/67N) This is a Schweitzer Engineering Laboratory numerical relay that provides backup bus protection. The zone of protection includes the portion of the bus between breakers 2 and 3 as well as the line between the bus and the Isolation Breaker. This backup overcurrent relay operates an auxiliary relay (86BU) hand reset lockout relay. The 86BU relay trips Breaker 2 and 3 and initiates breaker failure in 11C/Breaker 2 and 11C/Breaker 3. The 86BU trips and blocks reclosing of Breaker 4. 95 (43MTS at RGE) Maintenance Switch The purpose of this two position switch is to turn off closing and tripping to a breaker during maintenance. In the TEST position, separate contacts open the circuit to both trip coils and block the close circuit. A Blue indicating lamp on the switchboard is illuminated to indicate the switch in the “Test” position. An indication is also sent to SCADA, indicating the switch is in the “Test” position. Contacts of the 95/TEST switches from each breaker are required inputs to the “A” and “B” line protection relays where they are used in the line energerization logic (50LEA and 50LEB). Line energization protection is required when line protection derives potential from a line source rather than bus source, as is the case with the POI Station. For a brief time directly following a close, the line is protected solely by overcurrent relays. A simplified electromechanical equivalent logic for line energization is shown below. This logic says that if both breakers are open and the line is not energized, enable the instantaneous overcurrent. If one of the breakers is out for maintenance, a 95/TEST contact is required because the breaker 52b switch could be open.




52bBKR 1

52bBKR 2

95TESTBRK 1

95TESTBRK 2

27ALINE27BLINE

27CLINE

ENABLE 50LERELAY FORXX CYCLES

SCO (43LR at RGE) Switch This is a Supervisory Cutoff Switch. In the OFF (“Local” at RGE) position, this switch prevents opening and closing of the breaker by supervisory control. In the ON (“Remote” at RGE) position it allows opening and closing by supervisory control. A Blue indicating lamp on the switchboard is illuminated to indicate the switch in the “OFF” position (no blue light at RGE). An indication is also sent to SCADA, indicating the switch is in the “Off” position. 79CO Switch This is a Reclosing Cutoff Switch. In the OFF (“Cutout” at RGE) position, this switch prevents automatic closing of the breaker. In the ON (“Normal” at RGE) position, it allows automatic reclosing. Automatic reclosing is prevented during line maintenance. A Blue indicating lamp on the switchboard is illuminated to indicate the switch in the “OFF” position (no blue light at RGE). An indication is also sent to SCADA, indicating the switch is in the “Off”(“Cutout”) position. 94X (79LR at RGE) Relay The purpose of the 94X relay is to block automatic reclosing following a manual trip (52CS), supervisory trip, or a trip any where an automatic reclose is undesirable (94TTR, 86BU, 94BF). The 94X operate coil in the trip circuit picks up and blocks reclosing. A simplified schematic is shown below.




94BB PR

52a

95NORM

94XO

94X

TC CC

52CST R

94X

52CSC

25

SCO

201

94X

79/CO

79

94XR

95NORM

94X

94X

Note: SUPV/T not shown & is 201 widely understood to be SUPV/C? The 94X relay is generally a GE model HFA auxiliary relay. This relay has two stable conditions, operate and reset. Contacts of the 94X are shown on elementary diagrams in their reset condition. When the 94X/O coil is momentarily energized, the relay contacts change state and mechanically latch until they are reset by momentarily energizing the 94X/R coil. A 94X “a” contact in series with the 94X/R coil blocks energizing the 94X/R coil unless the relay is latched in the operate condition. Protective relays trip the breaker directly without operating the 94X. The 94X “b” contracts in series with the reclose output contact remain closed allowing the breaker to automatically reclose. When the breaker is opened by the control switch or supervisory control, the 94X/O coil is energized and blocks automatic reclosing. A 94X “b” contact in series with the red indicating lamp blocks the indicating light current from sealing-in the 94X/O, since hinged-armature type relays will remain energized with a much lower coil current than the pick-up value. When the breaker is closed by the control switch or supervisory, the 94X/R coil is energized through the latched 94X “a” contact. This resets all the 94X contacts and allows the breaker to close and enables automatic reclosing. Automatic reclosing may be stopped mid cycle by a supervisory trip or a manual trip. Switchboard Lights NYSEG requires each winding of each potential transformer to be monitored with a white light (amber at RGE). NYSEG uses amber lights to indicate a lockout relay operations.. RG&E uses blue lights to monitor the continuity lockout relay coils, no light to indicate operation of the lockout relay. It is preferred that all bulbs be LED lamps. NYSEG uses white lights to monitor the dc supply to trip circuits, RGE does not.




Flexitest Test Switches NYSEG/RGE requires the use of Westinghouse Flexi-Test (FT) Style Test Switches on all protective relays, auxiliary tripping relays, and lockout relays to facilitate testing. The test switch fingers layouts are specified in the Appendix for each relay. In general, all relay inputs use one test finger on the positive side and a single common finger for all the inputs on the negative side. In general, all auxiliary and lockout relays have test fingers on each side of the coil and one test finger on the negative side of the contact.




Appendix SEL-421/LN1 I/O Connections (11A) INPUT/OUTPUT TEST SWITCH FUNCTION OUT 101 OUT 102 OUT 103 TS2-3, TS2-4 RECLOSE INITIATE BKR 1 OUT 104 TS2-5, TS2-6 RECLOSE BLOCK BKR 1 OUT 105 TS5-3, TS5-4 RECLOSE INITIATE BKR 2 OUT 106 TS5-5, TS5-6 RECLOSE BLOCK BKR 2 OUT 107 OUT 108 TS2-7, TS2-8 RELAY TROUBLE OUT 201 TS2-1, TS2-2 TRIP BKR 1 OUT 202 TS5-1, TS5-2 TRIP BKR 2 OUT 203 OUT 204 TS3-9, TS3-10 KEY POTT OUT 205 OUT 206 TS2-9, TS2-10 BREAKER FAIL BKR 1 OUT 207 TS5-9, TS5-10 BREAKER FAIL BKR 2 OUT 208 TS3-5 COMMON BREAKER 1 TS6-5 COMMON BREAKER 2 TS6-9, TS6-10 POWER IN 101 TS3-1 TCM BKR 1 IN 102 TS3-2 MTS (95) BKR 1 IN 103 TS3-3 52a BKR 1 IN 104 TS3-4 SPARE IN 105 TS6-1 TCM BKR 2 IN 106 TS6-2 MTS (95) BKR 2 IN 107 TS6-3 52a BKR 2 IN 201 TS3-7, TS3-8 RECEIVE SIGNAL IN 202 IN 203 IN 204 IN 205 IN 206 IN 207 IN 208




SEL-351A/Bkr 1 I/O Connections (11C)

INPUT/OUTPUT TEST SWITCH FUNCTION OUT 101 TS2-1, TS2-2 95 (MAINT TEST SWITCH) OUT 102 TS5-1, TS5-2 RE-TRIP BREAKER, TC-2 OUT 103 TS2-3, TS2-4 SUPERVISORY CLOSE BREAKER 1 OUT 104 TS5-3, TS5-4 RECLOSE BREAKER 1 OUT 105 OUT 106 OUT 107 TS2-5, TS2-6 BREAKER FAILURE TRIP (86BB) ALARM TS2-7, TS2-8 RELAY TROUBLE TS2-9, TS2-10 RELAY POWER SUPPLY IN 101 TS3-1 95 (MAINT TEST SWITCH) IN 102 TS3-2 RECLOSE & BFI INITIATE IN 103 TS3-3 79CO & BLOCK RECLOSE IN 104 TS3-4 BREAKER FAILURE INITIATE IN 105 TS3-5 52A, BREAKER IN 106 TS3-6 95 (MAINT TEST SWITCH) TS3-7 95 (MAINT TEST SWITCH)1 TS3-8 95 (MAINT TEST SWITCH)11 TS3-10 INPUT COMMON TS5-7 ISOLATE 63AX CONTACT TS6-1 ISOLATE 94BB COIL POS TS6-2 ISOLATE 94BB COIL NEG TS6-3 ISOLATE 94BB TRIP BREAKER 1 TS6-4 ISOLATE 94BB TRIP BREAKER 2 TS6-5 ISOLATE 94BB KEY DTT TONE TS6-6 ISOLATE 94BB KEY DTT CARRIER TS6-7 ISOLATE 94BB KEY DTT TONE 2 TS6-8 ISOLATE 94BB KEY DTT CARRIER3 TS6-9 ISOLATE 94BB OPERATE 86B TS6-10

1 Not required on Breakers 2 or 3 2 Not required on Breakers 2 or 3 3 Not required on Breakers 2 or 3




Comment: Breaker failure and reclose initiation sometimes are the same inputs. When this occurs, IN102 is used for the common inputs and additional BFI inputs use IN104. The maintenance test switch (95) is used in the breaker failure logic where a 52a switch is used. In some cases the 95/TEST switch is not a required input. SEL-311C/LN1 I/O Connections (11A)

INPUT/OUTPUT TEST SWITCH FUNCTION OUT 101 OUT 102 OUT 103 TS2-3, TS2-4 RECLOSE INITIATE BKR 1 OUT 104 TS2-5, TS2-6 RECLOSE BLOCK BKR 1 OUT 105 TS5-3, TS5-4 RECLOSE INITIATE BKR 2 OUT 106 TS5-5, TS5-6 RECLOSE BLOCK BKR 2 OUT 107 ALARM TS2-7, TS2-8 RELAY FAILURE OUT 201 TS2-1, TS2-2 TRIP BKR 1 OUT 202 TS5-1, TS5-2 TRIP BKR 2 OUT 203 OUT 204 TS3-9, TS3-10 KEY POTT OUT 205 OUT 206 TS2-9, TS2-10 BREAKER FAIL BKR 1 OUT 207 TS5-9, TS5-10 BREAKER FAIL BKR 2 OUT 208 OUT 209 OUT210 OUT211 OUT212 TS3-5 COMMON TS6-5 COMMON TS6-9, TS6-10 POWER IN 101 TS3-1 TCM BKR 1 IN 102 TS3-2 MTS (95) BKR 1 IN 103 TS3-3 52a BKR 1 IN 104 TS3-7, TS3-8 RECEIVE SIGNAL IN 105 IN 106




IN 201 TS6-1 TCM BKR 2 IN 202 TS6-2 MTS (95) BKR 2 IN 203 TS6-3 52a BKR 2 IN 204 IN 205 IN 206 IN 207 IN 208 SEL-351 BUS I/O Connections (67/67N)

INPUT/OUTPUT TEST SWITCH FUNCTION OUT 101 TS2-1, TS2-2 OPERATE 94BU AND 86BU OUT 102 OUT 103 OUT 104 OUT 105 OUT 106 OUT 107 ALARM TS2-7, TS2-8 RELAY TROUBLE TS2-9, TS2-10 RELAY POWER SUPPLY IN 101 IN 102 IN 103 IN 104 IN 105 TS2-5 52a BREAKER 2 IN 106 TS2-6 52a BREAKER 3 IN 107 TS2-4 COMMON TS2-3 SPARE TS3-1 ISOLATE 94BU COIL POS TS3-2 ISOLATE 94BU COIL NEG TS3-3 ISOLATE 86BU COIL POS TS3-4 ISOLATE 86BU COIL NEG TS3-5 ISOLATE 94BU TRIP BREAKER 2 TS3-6 ISOLATE 94BU TRIP BREAKER 3 TS3-7 BKR BU 11C/BKR 2 IN104 TS3-8 BKR BU 11C/BKR 3 IN104 TS3-9 BLOCK RECL 11C/BKR 2 IN103




TS3-10 BLOCK RECL 11C/BKR 2 IN103




SEL-587Z BUS I/O Connections (87B)

INPUT/OUTPUT TEST SWITCH FUNCTION OUT 1 TS2-1, TS2-2 OPERATE 94B OUT 2 TS2-3, TS2-4 OPERATE 86B OUT 3 OUT 4 ALARM TS2-7, TS2-8 RELAY TROUBLE IN 1 TS2-6 STATUS 86B IN 2 TS2-5 INPUT COMMON TS2-9, TS2-10 RELAY POWER SUPPLY 87A NONE SHORT THYRITE A WITH 94B 87B NONE SHORT THYRITE B WITH 94B 87C NONE SHORT THYRITE C WITH 94B TS3-1 ISOLATE 94B COIL POS TS3-2 ISOLATE 94B COIL NEG TS3-3 ISOLATE 86B COIL POS TS3-4 ISOLATE 86B COIL NEG TS3-5 ISOLATE 94B TRIP BREAKER 2 TS3-6 ISOLATE 94B TRIP BREAKER 3 TS3-7 BKR BU 11C/BKR 2 IN104 TS3-8 BKR BU 11C/BKR 3 IN104 TS3-9 BLOCK RECL 11C/BKR 2 IN103 TS3-10 BLOCK RECL 11C/BKR 2 IN103




POI RELAY PREFERRED PROTECTIVE RELAY LIST All relays are specified with conventional terminal blocks, 125VDC power supplies and control voltage, Horizontal Rack Mount, and DNP 3.0 protocol. Specific installations may require changes to the model numbers listed below. SEL-311C Model No. 0311C00H23254X1 FOUR ZONE PILOT PROTECTION RELAY, STANDARD WITH 8 OUTPUTS AND 6 INPUTS, HORIZONTAL RACK MOUNT, LCD AND TARGETS, 48/125VDC POWER SUPPLY, VA, VB &VC, 5 AMP PH., 125VDC CONTROL INPUT VOLTAGE, ALL PROTOCOL LISTED ABOVE PLUS DNP 3.00 LEVEL 2 SLAVE. SEL-421 Model No. 0421166665X2 _ _ _ _ HX HIGH SPEED LINE PROTECTION CONTROL AND INTEGRATION SYSTEM STANDARD WITH 8 OUTPUTS, 7 INPUTS, STANDARD FIRMWARE, 125/250Vdc POWER SUPPLY, SCREW TERMINAL BLOCKS, 300V PHASE-NEUTRAL MAXIMUM, 5 AMPERE PHASE, NO CARD OPTIONS, ALL PROTOCOLS PLUS DNP 3.0, SPECIFY CONTACTS, HORIZONTAL RACK MOUNT 5 RACK UNITS. (need output contact numbers) SEL-587Z Model No. 0587Z0X325H12XX HIGH-IMPEDANCE DIFFERENTIAL PROTECITON STANDARD WITH 5 OUTPUTS, 2 INPUTS, STANDARD FIRMWARE, 48/125VDC POWER SUPPLY, 125VDC CONTROL VOLTAGE, HIGH ENERGY (2 MOVs), 5 AMPERE SECONDARY, HORIZONTAL RACK MOUNT, RS-232 COMMUNICATIONS PORTS FRONT AND REAR, STANDARD COMMUNICATIONS PROTOCOL. SEL-351A Model No. 0351A00H24554X1 DISTRIBUTION PROTECTION SYSTEM, 8 OUTPUS, 6 INPUTS, CONVENTIONAL TERMINAL BLOCKS, STANDARD FIRMWARE, 2 RACK UNITS, HORIZONTAL RACK MOUNT, 125/250V POWER SUPPLY, 5 AMPERES PHASE AND NEUTRAL, 125VDC CONTROL VOLTAGE, STANDARD PLUS DNP 3.0 COMMUNICATIONS PROTOCOL. SEL-311L Model No. 0311L03BO4254X1 CURRENT DIFFERENTIAL RELAY, STANDARD, 3U HORIZONTAL PANEL MOUNTING, CHANNEL X; ISOLATED G.703 CO-DIRECTIONAL, CHANNEL Y; NONE, 125/250VDC, WYE CONNECTED; VA, VB &VC, 5 AMP PH., 125VDC CONTROL INPUT VOLTAGE, ALL PROTOCOL LISTED ABOVE PLUS DNP 3.00 LEVEL 2 SLAVE . If this relay is used, it must be determined if 850nm or 1300nm fiber is available




95 SWITCH LAYOUT Contacts Handle

End

Test Norm Function in the Test Position

1 - 1C X Blue Light 2 - 2C X Enables Test Close (PB at Breaker) 3 - 3C X Blocks Close from Control & Protective Relay 4 - 4C X Enables Test 1 Trip (PB at Breaker) 5 - 5C X Blocks Trip 1 from Control & Protective Relay 6 - 6C X Mimics 52b contacts in "A" line (1) energization ckt. 7 - 7C X Blocks all Inputs to BFA 8 - 8C X Mimics 52b contacts in "A" line (2) energization ckt. 9 - 9C X Blocks Air/Gas Monitoring "A"

10 - 10C X Operates 94XA 11 - 11C X Mimics 52b contacts in "A" Relaying line (1). Keys Permissive

12 - 12C X Breaker Disconnect. Prevents MOAB from being operated when switch in "Test".

13 - 13C X Mimics 52b contacts in "A" Relaying line (2). Keys Permissive

14 - 14C X Breaker Disconnect. Prevents MOAB from being operated when switch in "Test".

15 - 15C X Spare 16 - 16C X Spare 17 - 17 C X Enables Test 2 Trip (PB at Breaker) 18 - 18C X Blocks Trip 2 from Control & Protective Relay 19 - 19C X Mimics 52b contacts in "B" line (1) energization ckt. 20 - -20C X Blocks all Inputs to BFB 21 - 21C X Mimics 52b contacts in "B" line (2) energization ckt. 22 - 22C X Blocks Air/Gas Monitoring "B" 23 - 23C X Operates 94XB 24 - 24C X Mimics 52b contacts in "B" Relaying line (1). Keys Permissive 25 - 25C X Mimics 52b contacts in "B" Relaying line (2). Keys Permissive 26 - 26C X SCADA




ALARM AND CONTROL POINT DEFINITION GUIDELINES

** = Change Detect points Annun. Point

SCADA Point

Control Indic. Analog1. Transformer Banks status alarms (one per transformer bank with low side voltage greater than or equal to 34.5 KV) 11 2 8 5

A. Transformer trouble – annunciate each separately but 1 alarm point to SCADA 7 0 1 0

i. Loss of AC for fans 1 ii. Low oil (LTC and main tank) 1 iii. Winding temperature 1 iv. Transformer high oil temperature 1 v. High nitrogen pressure 1 vi. Loss of LTC potential 1 vii. LTC backup 1 viii. Others as required (oil flow, LTC loss of vacuum, etc.)

B. Transformer fault – annunciate each separately but 1 alarm point to

SCADA (change detect status) 2 0 1 0 i. Sudden pressure 1 ii. Pressure relief (LTC and main tank) 1

C. Transformer differential (from protective bank relays) – not annunciated 1

D. Transformer low nitrogen - annunciate each separately but 1 alarm

point to SCADA 2 0 1 0 i. Low nitrogen pressure 1 ii. Low nitrogen cylinder pressure 1

E. LTC Harley monitor - not annunciated, paralleled in monitor and 1 alarm

point to SCADA 1 i. LTC main tank temperature differential ii. LTC main tank differential index iii. LTC motor current index iv. LTC operations exceed daily maximum

F. LTC oil filter - not annunciated, paralleled in monitor and 1 alarm point

to SCADA 1 i. Low Pressure ii. High pressure iii. Oil sump

G. LTC Control and Status 0 2 2 0

i. Raise/lower LTC control 1 ii. Automatic/manual LTC control 1






SCADA Point

Control Indic. Analogiii. Status for automatic/manual LTC (not annunciated) 1 iv. Status for incomplete tap change 1

H. Transformer analog points (reading taken from low side of bank) with

power flow out of bank into bus considered positive flow (+) ) 0 0 0 5 i. Amps 1 ii. Watts 1 iii. Vars 1 iv. Bus KV 1 v. LTC tap position 1

2. Capacitor banks – transmission and subtransmission 0 3 4 2

A. Control points 3 0 0 i. Automatic/manual capacitor operation 1 ii. Trip/close capacitor breaker 2

B. Status Points – not annunciated 0 0 4 0

i. Open/close status 1 ii. Trouble 1 iii. Automatic/manual 1 iv. Lockout 1

C. Analog points – voltage of 115 KV and above will require monitoring of

VARS. All others will be evaluated on an individual basis. 2 3. Controllable devices 0 10 0 0

A. Circuit breakers (control for all substation breakers 34.5 KV and above and use change detect point if breaker can reclose between status scans) 2

B. Motor operated disconnects, circuit switchers, transruptors (trip only) 1

C. Auto/manual motor operated disconnects 1

D. Bus differential reset (old stations with electric reset lockout relays) 1

E. Voltage selector switches (bulk power) 1

F. Carrier check back 1

G. Transfer trip lockout reset (old stations) 1

H. Gas regulators 1






SCADA Point

Control Indic. Analog

I. LTC, auto/manual, and tap change controls (noted on page 1) 1

4. Typical status alarms 28 1 52 0 A. Breakers 12 7

i. Breaker trouble – annunciate each separately but 1 alarm point to SCADA for each breaker 1

a. low air 1 b. low SF6 1 c. SF6 cutoff 1 d. loss AC 1 e. spring discharge 1 f. excessive run time 1 g. compressor trouble 1

ii. High/low pressure (by breaker) for older bulk system bkrs 1 1 iii. **Air/gas differential (by breaker) for older bulk system bkrs 1 1 iv. Gas temperature (by breaker) for older SF6 bkrs 1 1 v. **Breaker failure by brkr for bulk system bkrs, for non-bulk breakers

are annunciated separately and grouped by voltage for SCADA alarm. 1 1 vi. **Pole disagreement by breaker 1 vii. **Breaker status (“a” contact from breaker) 1 viii. Distribution breaker lockout (older breakers) – “a” contact for

status is preferred for new breakers 1

B. Loss of station service (not annunciated) 1

C. Station service transfer (not annunciated) 1

D. Battery – not annunciated 2 i. Urgent battery alarm – high/low battery voltage, loss of charger AC 1 ii. Nonurgent battery alarm – battery ground 1

E. Loss of relay DC – all paralleled into 1 SCADA alarm (not annunciated).

For large stations group the alarms by switchboard row with separate annunciator alarms paralleled into 1 SCADA alarm 1

F. Loss of annunciator DC 1

G. Loss of relay potential – annunciated separately and grouped by voltage, line, and sets (A and B) for SCADA alarms 1 1






SCADA Point

Control Indic. AnalogH. Relay trouble – annunciated separately per relay and grouped by

voltage for SCADA alarm 1 1

I. **Hot line indication (not annunciated) 1

J. **Bus differential – A and B (not annunciated) 1

K. Under-frequency relay reset control and indication (not annunciated) 1 1

L. Communications alarms (separate alarms for A and B systems) 11 6 i. Pilot wire failure 1 1 ii. DTT/POTT loss of channel/loss of guard –annunciated separately

and paralleled for SCADA alarm by line number 1 a. Loss of channel/guard 1 b. Power supply failure 1 c. Hardware failure 1 d. DTT channel failure 1 e. Permissive channel failure 1

iii. DTT/POTT received – by line number – ANNUNCIATED ONLY – NO SCADA ALARM 1

iv. Audio, carrier, or carrier (AM systems) received - by line number – ANNUNCIATED ONLY – NO SCADA ALARM 1

v. Carrier check back failure - annunciated separately and paralleled for SCADA alarm by line number 1

a. High power failure 1 b. Low power failure 1 c. Checkback test failed 1

vi. DTT/ POTT transmitter/receiver cutoff switch 1 vii. DTT/POTT alarm disable 1 viii. Carrier checkback cutoff switch 1

M. Fiber Optics Alarms (not annunciated) 3

i. Major trouble 1 ii. Minor trouble 1 iii. Transmitter/receiver cutoff switch 1

N. Supervisory Cutoff (SCO) switch – all paralled into one SCADA alarm

(not annunciated) 1

O. Voltage selector switch On/Off 1

P. 95 Maintenance Switch On/Off 1






SCADA Point

Control Indic. Analog

Q. Sequence of Events Recorders (SOER) 4 i. SOER cutoff switch 1 ii. SOER low paper 1 iii. SOER operation 1 iv. SOER fail 1

R. Fault Recorder/Oscillograph 4

i. Low paper 1 ii. Disk almost full 1 iii. Fault recorder/oscillograph operated 1 iv. Fault recorder/oscillograph failure (power failure) 1

S. Generators 2 6

i. generator operated 1 ii. generator failed to start 1 iii. Diesel cold startup 1 iv. Fuel low temperature 1 v. Low fuel 1 vi. Generator trouble – annunciated separately with 1 alarm point to

SCADA for each generator 1 a. low battery 1 b. low charger 1

T. Building Alarm (access) 1 U. Building fire alarm 1 V. Fence alarm 1 W. Sump pump 1 X. RTU Local/remote 1 Y. Cable Alarms – separate alarms to SCADA for each cable 3

i. Ground fault 1 ii. High/low pressure 1 iii. Low oil 1

Z. Oil containment – loss of AC (annunciate alarm) 1

5. Analog Points 4






SCADA Point

Control Indic. AnalogA. 34.5 KV distribution, Subtransmission, 34.5 KV and up line terminals

where breakers are the termination point of a line section 3 i. Amps (for breaker and a half and ring bus schemes breaker amps

are required) 1 ii. Watts 1 iii. Vars 1

B. Bus voltages 1

i. KV for 34.5 KV and up bus volts 1 ii. Ring bus – line volts (KV) will be used instead of bus volts

C. Generation – all generators above 1 MW will be reviewed by Power

Supply to determine if analog and/or status is required i. Steam 5

a. Generator MW 1 b. Generator MVAR 1 c. Plant net generation MWH 1 d. Frequency (wide band) Hz 1 e. Frequency (narrow band) Hz 1

ii. Hydro 3 a. Generator KW 1 b. Generator KVAR 1 c. Water level inches 1

iii. IPPs/Cogeneration 3 a. Generator KW 1 b. Generator KVAR 1 c. Line KV 1

D. Gas Pressure – PSI 1 E. Calibration points - +/- 90% reference 1

F. Weather data 3

i. Wind speed 1 ii. Wind direction 1 iii. Temperature 1

G. Typical Accumulator points 3

i. KWH in (MWH in) *** 1 ii. KWH out (MWH out) *** 1 iii. Generation (unit, gross, or net MWH) 1






SCADA Point

Control Indic. Analog*** (for interchange pts only as required by Power Supply) If the billing point is in our substation, we will monitor W, VA, KWH In and Out.

Documents

SEL Relays New York Application Guide