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Schweitzer Engineering Laboratories SEL-421-4, Instruction Manual

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3.38

SEL-400 Series Relays

Instruction Manual

Date Code 20171006

Basic Relay Operations

Examining Metering Quantities

Step 7. Turn the relay on.

Step 8. View metering.

a. Type 

ACC <Enter>

 to log in to the relay at Access Level 1.

b. Type the password and press 

<Enter>

.

c. Type 

MET <Enter>

.

The relay displays the fundamental frequency (50 Hz or 60 Hz) 
metering information in a manner similar to that shown in 

Figure 3.29

.

                    

The metering quantities of 

View Metering Using the Terminal on page 3.35

 are 

the fundamental line quantities. Other variants of the 

MET

 command give differ-

ent relay metering quantities. See 

Section 8: Metering, Monitoring, and Report-

ing

 of the product-specific instruction manual for more information on the 

specific metering options available in a specific relay.

View Metering Using QuickSet

Use the procedures in the following steps to examine the relay metering with the 
QuickSet HMI.

This example assumes that you have successfully established communication 
with the relay (see 

Making an EIA-232 Serial Port Connection on page 3.4

). In 

addition, you must be familiar with relay access levels and passwords (see 

Changing the Default Passwords in the Terminal on page 3.10

 to change the 

default access level passwords). You should also be familiar with QuickSet (see 

Checking Relay Status in QuickSet on page 3.12

 and 

Section 2: PC Software

).

Step 1. Start QuickSet and establish a connection with the relay. See Step 1 

and Step 2 of 

Checking Relay Status in QuickSet on page 3.12

 for 

details on how to do this.

Step 2. Set the relay to a nominal operation mode. Perform the initial Global 

settings relay setup of 

Making Initial Global Settings in QuickSet on 

page 3.28

 to set the relay for 60-Hz operation, ABC phase rotation.

=>>

MET <Enter>

 

                                                                                                                                                                   
Relay 1                                    Date: 02/26/2015  Time: 01:35:05.221
Station A                                  Serial Number: 0000000000
                                                                                                                                                                   
                      Phase Currents
                 IA        IB        IC
I MAG (A)       398.882   399.041   398.784
I ANG (DEG)      -1.18   -120.97    119.21

                      Phase Voltages                Phase-Phase Voltages
                 VA        VB        VC           VAB       VBC       VCA
V MAG (kV)      133.994   133.986   133.953      231.903   231.815   232.450
V ANG (DEG)      -0.17   -120.02    120.18        29.91    -89.92    150.01

                    Sequence Currents (A)          Sequence Voltages (kV)
                  I1        3I2       3I0         V1        3V2       3V0
MAG             398.901     2.159     2.588     133.977     0.692     0.713
ANG (DEG)        -0.98    -62.68   -115.80        0.00    -53.25   -120.79

                   A           B           C             3P
P (MW)            53.44       53.46       53.41         160.31
Q (MVAR)           0.95        0.89        0.91           2.75
S (MVA)           53.45       53.47       53.42         160.33
POWER FACTOR       1.00        1.00        1.00           1.00
                    LAG         LAG         LAG            LAG
                                                                                                                                                                   
FREQ (Hz)       60.00       VDC1(V)   125.00   VDC2(V)    48.00
                                                                                                                                                                   
=>>

Figure 3.29

Terminal Screen MET Metering Quantities

Summary of Contents for SEL-421-4

Page 1: ...SEL 421 Relay Instruction Manual PM421 04 NB SEL 421 4 5 Protection Automation and Control System Instruction Manual 20171021 ...

Page 2: ...atories Inc reserves all rights and benefits afforded under federal and international copyright and patent laws in its products including without limitation software firmware and documentation Portions 1982 2013 QNX Software Systems Limited under license to SEL The information in this document is provided for informational use only and is subject to change without notice Schweitzer Engineering Lab...

Page 3: ...peration 3 8 Technical Support 3 23 Section 4 Front Panel Operations Front Panel LCD Default Displays 4 1 Front Panel Menus and Screens 4 3 Target LEDs 4 9 Front Panel Operator Control Pushbuttons 4 13 One Line Diagrams 4 15 Section 5 Protection Functions Current and Voltage Source Selection 5 2 Polarizing Quantity for Distance Element Calculations 5 14 Frequency Estimation 5 15 Undervoltage Super...

Page 4: ...amples 230 kV Overhead Distribution Line Example 6 1 500 kV Parallel Transmission Lines With Mutual Coupling Example 6 18 345 kV Tapped Overhead Transmission Line Example 6 53 EHV Parallel 230 kV Underground Cables Example 6 87 Out of Step Logic Application Examples 6 119 Autoreclose Example 6 137 Autoreclose and Synchronism Check Example 6 141 Circuit Breaker Failure Application Examples 6 151 23...

Page 5: ...ts 11 34 Section 12 Analog Quantities Appendix A Firmware ICD File and Manual Versions Firmware A 1 SELBOOT A 9 ICD File A 9 Instruction Manual A 10 Appendix B Converting Settings From SEL 421 0 1 2 3 to SEL 421 4 5 Relay Word Bit Changes B 1 Analog Quantity Changes B 2 Global Settings Changes B 3 Group Settings Changes B 3 Front Panel Settings Changes B 4 Port Settings Changes B 4 DNP3 Mapping Ch...

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Page 7: ...Table 5 3 Available Current Source Selection Settings Combinations When ESS Y NUMBK 2 5 5 Table 5 4 Available Voltage Source Selection Setting Combinations 5 6 Table 5 5 ESS N Current and Voltage Source Selection 5 8 Table 5 6 ESS 1 Current and Voltage Source Selection 5 8 Table 5 7 ESS 2 Current and Voltage Source Selection 5 9 Table 5 8 ESS 3 Current and Voltage Source Selection 5 10 Table 5 9 E...

Page 8: ... 5 94 Table 5 56 Negative Sequence Overcurrent Element Settings 5 94 Table 5 57 Residual Ground Overcurrent Element Settings 5 95 Table 5 58 Phase Instantaneous Definite Time Line Overcurrent Relay Word Bits 5 95 Table 5 59 Negative Sequence Instantaneous Definite Time Line Overcurrent Relay Word Bits 5 95 Table 5 60 Residual Ground Instantaneous Definite Time Line Overcurrent Relay Word Bits 5 96...

Page 9: ...lated Hidden Settings 6 129 Table 6 34 Relay Configuration Group 6 129 Table 6 35 Out of Step Tripping Blocking 6 130 Table 6 36 Automatically Calculated Hidden Settings 6 136 Table 6 37 Relay Configuration Group 6 136 Table 6 38 Out of Step Tripping Blocking 6 136 Table 6 39 Settings for Autoreclose Example 6 140 Table 6 40 Settings for Autoreclose and Synchronism Check Example 6 149 Table 6 41 S...

Page 10: ...33 Breaker 1 Current Interrupted and Breaker 2 Current Interrupted 8 11 Table 8 34 Group Settings Categories 8 12 Table 8 35 Line Configuration 8 13 Table 8 36 Relay Configuration 8 13 Table 8 37 Mho Phase Distance Element Reach 8 15 Table 8 38 Quadrilateral Phase Distance Element Reach 8 15 Table 8 39 Phase Distance Element Time Delay 8 16 Table 8 40 Mho Ground Distance Element Reach 8 16 Table 8...

Page 11: ...egions 10 1 Table 10 2 SEL 421 Database Structure LOCAL Region 10 2 Table 10 3 SEL 421 Database Structure METER Region 10 2 Table 10 4 SEL 421 Database Structure DEMAND Region 10 4 Table 10 5 SEL 421 Database Structure TARGET Region 10 5 Table 10 6 SEL 421 Database Structure HISTORY Region 10 5 Table 10 7 SEL 421 Database Structure BREAKER Region 10 6 Table 10 8 SEL 421 Database Structure STATUS R...

Page 12: ...elay Word Bits Alarms 11 55 Table 11 38 Relay Word Bits Time and Date Management and Frequency Estimation 11 55 Table 11 39 Relay Word Bits Pushbuttons and Outputs 11 56 Table 11 40 Relay Word Bits Pushbuttons 11 57 Table 11 41 Relay Word Bits Pushbutton LED Bits 11 57 Table 11 42 Relay Word Bits Data Reset Bits 11 57 Table 11 43 Relay Word Bits Target Logic Bits 11 57 Table 11 44 Relay Word Bits ...

Page 13: ...ble A 3 ICD File Revision History A 9 Table A 4 Instruction Manual Revision History A 10 Table B 1 Relay Word Bit Differences B 1 Table B 2 Analog Quantity Differences B 2 Table B 3 Global Settings Differences B 3 Table B 4 Group Settings Differences B 3 Table B 5 Serial Port Settings Differences B 4 Table B 6 Ethernet Port Settings Differences B 4 Table B 7 Binary Inputs Point Mapping for MAPSEL ...

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Page 15: ...NT5 I O Interface Board 2 14 Figure 2 15 INT6 I O Interface Board 2 14 Figure 2 16 INT7 I O Interface Board 2 14 Figure 2 17 INT8 I O Interface Board 2 14 Figure 2 18 Jumper Location on the Main Board 2 16 Figure 2 19 Major Component Locations on the SEL 421 Main Board 2 18 Figure 2 20 Major Component Locations on the SEL 421 INT1 INT2 INT4 INT5 INT6 INT7 and INT8 I O Boards 2 21 Figure 2 21 Major...

Page 16: ...QuickSet 3 10 Figure 3 8 Uploading Group 1 Settings to the SEL 421 3 11 Figure 3 9 ELEMENT SEARCH Screen 3 11 Figure 3 10 RELAY ELEMENTS Screen Containing Element 50Q1 3 12 Figure 3 11 Group 1 Relay Configuration Settings QuickSet 3 14 Figure 3 12 Breaker 1 Breaker Monitor Settings QuickSet 3 15 Figure 3 13 Group 1 Line Configuration Settings QuickSet 3 16 Figure 3 14 Directional Settings QuickSet...

Page 17: ...cuit Breaker Configuration 5 8 Figure 5 6 ESS 2 Single Circuit Breaker Configuration 5 9 Figure 5 7 ESS 3 Double Circuit Breaker Configuration 5 10 Figure 5 8 ESS 4 Double Circuit Breaker Configuration 5 11 Figure 5 9 Tapped EHV Overhead Transmission Line 5 12 Figure 5 10 ESS Y Tapped Line 5 12 Figure 5 11 ESS Y Single Circuit Breaker With Current Polarizing Source Tapped Power Transformer 5 13 Fi...

Page 18: ...e 5 61 Zone 2 Quadrilateral Distance Element Logic Diagram 5 79 Figure 5 62 Zones 3 4 and 5 Quadrilateral Ground Distance Element Logic 5 80 Figure 5 63 Zone 1 Mho Phase Distance Element Logic Diagram 5 82 Figure 5 64 Zone 2 Mho Phase Distance Element Logic Diagram 5 83 Figure 5 65 Zones 3 4 and 5 Mho Phase Distance Element Logic Diagram 5 84 Figure 5 66 Quadrilateral Phase Distance Element Charac...

Page 19: ...18 Partial Breaker and a Half or Partial Ring Bus Breaker Arrangement 5 158 Figure 5 119 Synchronism Check Voltages for Two Circuit Breakers 5 159 Figure 5 120 Synchronism Check Settings 5 160 Figure 5 121 Synchronism Check Relay Word Bits 5 161 Figure 5 122 Example Synchronism Check Voltage Connections to the SEL 421 5 163 Figure 5 123 Synchronism Check Voltage Reference 5 164 Figure 5 124 Normal...

Page 20: ... Potential Sources 6 147 Figure 6 40 Scheme 1 All Faults and Scheme 2 Multiphase Fault Timing Diagram 6 154 Figure 6 41 Scheme 2 Single Phase Fault Timing Diagram 6 155 Figure 6 42 230 kV Power System for Circuit Breaker Failure Scheme 1 6 155 Figure 6 43 Timing Diagram for Setting BFPU1 Scheme 1 6 157 Figure 6 44 Circuit Breaker Failure Trip and Circuit Breaker Trip DC Connections 6 160 Figure 6 ...

Page 21: ...ation about using the SEL 421 For example to learn about relay protection functions read the protection sections of this manual and skim the automation sections then concentrate on the operation sections or on the automation sections of this manual as your job needs and responsibilities dictate An overview of each manual section and section topics follows SEL 421 Instruction Manual Preface Describ...

Page 22: ...dix A Firmware ICD File and Manual Versions Lists the current firmware and manual versions and details differences between the current and pre vious versions Appendix B Converting Settings From SEL 421 0 1 2 3 to SEL 421 4 5 Describes differences in settings Relay Word bits analog quantities and DNP3 mapping between these versions of the relay SEL 400 Series Relays Instruction Manual Preface Descr...

Page 23: ...Control Equation Programming Describes multiple setting groups and SELOGIC control equations and how to apply these equations Discusses expanded SELOGIC control equation features such as PLC style commands math functions counters and conditioning timers Pro vides a tutorial for converting older format SELOGIC control equations to new freeform equations Section 14 ASCII Command Reference Provides a...

Page 24: ...itions of various technical terms used in the SEL 400 series instruction manuals Safety Information Dangers Warnings and Cautions This manual uses three kinds of hazard statements defined as follows Safety Symbols The following symbols are often marked on SEL products DANGER Indicates an imminently hazardous situation that if not avoided will result in death or serious injury WARNING Indicates a p...

Page 25: ...es différentes de celles indiquées dans ce manuel peut désarmer les dispositifs de protection d opérateur normalement actifs sur cet équipement WARNING Have only qualified personnel service this equipment If you are not qual ified to service this equipment you can injure yourself or others or cause equipment damage AVERTISSEMENT Seules des personnes qualifiées peuvent travailler sur cet appareil S...

Page 26: ... d installer une Carte d Interface INT4 I O dans votre relais vérifiez en premier la version du logiciel du relais Si la ver sion est R111 ou antérieure vous devez mettre à jour le logiciel du relais avec la version la plus récente et vérifier que la mise à jour a été correc tement installée sur la nouvelle carte Les instructions complètes de mise à jour sont fournies quand le nouveau logiciel est...

Page 27: ...ION Ne pas mettre le relais sous tension avant d avoir complété ces procé dures et d avoir reçu l instruction de brancher l alimentation Des dom mages à l équipement pourraient survenir autrement CAUTION Use of controls or adjustments or performance of procedures other than those specified herein may result in hazardous radiation exposure ATTENTION L utilisation de commandes ou de réglages ou l ap...

Page 28: ...ert when A deasserts Rising edge of A starts timers Output B will assert time X after the rising edge of A B will remain asserted for time Y If Y is zero B will assert for a single processing interval Input A is ignored while the timers are running Input S asserts output Q until input R asserts Output Q deasserts or resets when R asserts EXCLUSIVE OR B A If either A or B is asserted output C is as...

Page 29: ...Support We appreciate your interest in SEL products and services If you have questions or comments please contact us at Schweitzer Engineering Laboratories Inc 2350 NE Hopkins Court Pullman WA 99163 5603 U S A Tel 1 509 338 3838 Fax 1 509 332 7990 Internet selinc com support Email info selinc com ...

Page 30: ...This page intentionally left blank ...

Page 31: ...cluding Telnet FTP IEC 61850 and DNP3 serial and LAN WAN protocols Purchase of an SEL 421 includes the ACSELERATOR QuickSet SEL 5030 Soft ware program QuickSet assists you in setting controlling and acquiring data from the relays both locally and remotely ACSELERATOR Architect SEL 5032 Software is included with purchase of the optional Ethernet card with IEC 61850 protocol support Architect enable...

Page 32: ...ycle detection of power system faults Reclosing Incorporate programmable single pole and three pole tripping and reclosing of one and two circuit breakers into an integrated substation con trol system Synchronism and voltage checks from multiple sources provide complete bay control Breaker Failure The SEL 421 incorporates CT subsidence detection to pro duce element dropout in 5 8 cycle Apply the S...

Page 33: ...n Take advantage of enhanced automation features that include programmable elements for local control remote control protection latch ing and automation latching Local metering on the large format front panel liquid crystal display LCD eliminates the need for separate panel meters Use serial and Ethernet links to efficiently transmit key information includ ing metering data protection element and ...

Page 34: ...t response View real time phasors Settings Reduction Internal relay programming shows only the settings for the functions and elements you have enabled Thermal Overload Modeling Use the SEL 421 with the SEL 2600 RTD Mod ule for dynamic overload protection using SELOGIC control equations For more information see SEL Application Guide AG2003 06 Implementation of the SEL 49 Relay Line Thermal Protect...

Page 35: ...si tive and optoisolated Contact outputs 2 standard Form A 3 standard Form C and 3 high current interrupting Form A outputs Additional I O board for 4U and 5U chassis INT1 Contact inputs 8 independent inputs programmable pickup threshold Contact outputs 13 standard Form A and 2 standard Form C outputs INT2 Contact inputs 8 independent inputs level sensitive and optoisolated Contact outputs 13 stan...

Page 36: ... 125 Vdc or 110 120 Vac 125 250 Vdc or 110 240 Vac Secondary inputs 1 A nominal or 5 A nominal CT inputs 300 V phase to neutral wye configuration PT inputs Ethernet card options Ethernet card with combinations of 10 100BASE T and 100BASE FX media connections on each of two ports Communications protocols Complete group of SEL protocols SEL ASCII SEL Compressed ASCII SEL Settings File Trans fer SEL ...

Page 37: ...dard Fault Locating Standard Standard SELOGIC Control Equations Standard Standard Maximum Automation SELOGIC Control Equations 100 1000 Substation Battery Monitor Standard Standard Breaker Wear Monitor Standard Standard Event Report Multicycle Data and Sequential Events Recorder Standard Standard Instantaneous RMS and Demand Meter Standard Standard DNP3 Level 2 Outstation Standard Standard Synchro...

Page 38: ... acronym to represent all three phases of a relay analog input For example IW represents IAW IBW and ICW for A B and C Phase current inputs on terminal W respectively The drawings list a separate phase designator if you need only one or two phases of the analog input set VAZ for the A Phase voltage of the VZ input set for example The SEL 421 supports remote data acquisition through use of the SEL ...

Page 39: ...guration ESS 3 SEL 421 Relay BUS CB1 3 1 3 IW IX VAZ VY 3 Analog Input IW IX VY VAZ Function CB1 protection line protection CB1 breaker failure Line protection Synchronism check SEL 421 Relay BUS 1 BUS 2 CB1 CB2 3 3 3 IW IX VAZ VY VBZ 1 1 Analog Input IW IX IW IX VY VAZ VBZ Function Line Protection CB1 protection CB2 protection Line protection Synchronism check Circuit Breaker 1 Synchronism check ...

Page 40: ...2 CB1 CB2 3 3 3 3 IW IX VAZ VY VBZ 1 1 Analog Input IW IX IW IX VY VAZ VBZ Function CB2 protection Line protection CB1 protection Line protection Synchronism check Circuit Breaker 1 Synchronism check Circuit Breaker 2 HV Tripping Direction LV MOD SEL 421 Relay IW VY 1 1 3 3 VAZ VBZ CB2 CB1 Analog Input IW VY VAZ VBZ Function Line protection Line protection Synchronism check Circuit Breaker 1 Synch...

Page 41: ... Tapped and three terminal lines Five zones Three zero sequence compensation factors for more accurate ground distance reach on either side of tap Independent reach settings for phase ground mho and phase ground quadrilateral elements Multiple settings groups cover any switching configurations Bus tie or transfer circuit breakers Multiple setting groups Match relay settings group to each line subs...

Page 42: ...al protocols Ethernet IEC 61850 DNP3 Ethernet FTP Telnet Customized protection and automation schemes Separate protection and automation SELOGIC control equa tion programming areas Use timers and counters in expanded SELOGIC control equa tions for complete flexibility Synchrophasors The SEL 421 can function as a phasor measurement unit PMU at the same time as it provides best in class protective r...

Page 43: ...n freeform 421 4 1 block of 100 lines 421 5 10 blocks of 100 lines each SELOGIC variables 64 protection 256 automation SELOGIC math variables 64 protection 256 automation Conditioning timers 32 protection Sequencing timers 32 protection 32 automation Counters 32 protection 32 automation Latch bits 32 automation 32 protection Control Remote bits 32 Breakers Two for control and three for status 1 2 ...

Page 44: ...eyond this limit 5 A Nominal 247 5 A 1 A Nominal 49 5 A One Second Thermal Rating 1 A Nominal 100 A 5 A Nominal 500 A One Cycle Thermal Rating 1 A Nominal 250 A peak 5 A Nominal 1250 A peak Burden Rating 1 A Nominal 0 1 VA at 1 A 5 A Nominal 0 5 VA at 5 A AC Voltage Inputs Three phase four wire wye connections are supported Rated Voltage Range 0 300 VLN Ten Second Thermal Rating 600 Vac Burden 0 1...

Page 45: ...rupt DC Outputs With Arc Suppression Enabled Make 30 A Carry 6 A continuous carry 1 s Rating 50 A MOV Protection 330 Vdc 130 J Breaking Capacity 10 000 Operations 48 Vdc 10 A L R 40 ms 125 Vdc 10 A L R 40 ms 250 Vdc 10 A L R 20 ms Breaker Open Closed LEDs 250 Vdc on for 150 300 Vdc 192 288 Vac 125 Vdc on for 80 150 Vdc 96 144 Vac 48 Vdc on for 30 60 Vdc 24 Vdc on for 15 30 Vdc Note With nominal co...

Page 46: ... without condensation Weight Maximum 3U Rack Unit 8 0 kg 17 7 lb 4U Rack Unit 9 4 kg 20 7 lb 5U Rack Unit 11 3 kg 25 0 lb Terminal Connections Rear Screw Terminal Tightening Torque 8 Ring Lug Minimum 1 0 Nm 9 in lb Maximum 2 0 Nm 18 in lb User terminals and stranded copper wire should have a minimum temperature rating of 105 C Ring terminals are recommended Wire Sizes and Insulation Wire sizes for...

Page 47: ...Memory 3 s of back to back event reports sampled at 8 kHz Nonvolatile Memory At least 4 event reports of a 3 s duration sampled at 8 kHz Resolution 4 and 8 samples cycle Event Summary Storage 100 summaries Breaker History Storage 128 histories Sequential Events Recorder Storage 1000 entries Trigger Elements 250 relay elements Resolution 0 5 ms for contact inputs 1 8 cycle for all elements Processi...

Page 48: ...e 3 of setting at line angle for SIR 30 5 of setting at line angle for 30 SIR 60 Transient Overreach 5 of setting plus steady state accuracy Instantaneous Definite Time Overcurrent Elements Phase Residual Ground and Negative Sequence Pickup Range 5 A Model OFF 0 25 100 00 A secondary 0 01 A steps 1 A Model OFF 0 05 20 00 A secondary 0 01 A steps Accuracy Steady State 5 A Nominal 0 05 A plus 3 of s...

Page 49: ...condary 1 A Model 0 25 to 480 secondary 0 25 to 480 secondary Accuracy Steady State 5 A Model 5 of setting plus 0 01 A for SIR source to line impedance ratio 30 10 of setting plus 0 01 A for 30 SIR 60 1 A Model 5 of setting plus 0 05 A for SIR source to line impedance ratio 30 10 of setting plus 0 05 A for 30 SIR 60 Transient Overreach 5 of setting plus steady state accuracy Positive Sequence Over...

Page 50: ...00 Vac PF 0 0 5 lead lag 3 MVA S Per Phase Wye 3 Wye or Delta Per Terminal 1 0 1 1 2 INOM 33 5 300 Vac PF 1 0 5 lead lag 1 0 7 0 1 1 2 INOM 33 5 300 Vac PF 1 0 5 lead lag 3 PF Per Phase Wye 3 Wye or Delta Per Terminal 1 0 1 1 2 INOM 33 5 300 Vac PF 1 0 5 lead lag 1 0 7 0 1 1 2 INOM 33 5 300 Vac PF 1 0 5 lead lag 3 Energy MWh P Per Phase Wye 3 Wye or Delta 1 0 1 1 2 INOM 33 5 300 Vac PF 1 0 5 lead ...

Page 51: ...ards on page 2 13 Jumpers on page 2 15 Relay Placement on page 2 24 Connection on page 2 25 AC DC Connection Diagrams on page 2 50 It is also very important to limit access to the SEL 421 settings and control func tions by using passwords For information on relay access levels and passwords see Changing the Default Passwords in the Terminal on page 3 10 in the SEL 400 Series Relays Instruction Man...

Page 52: ... is the same for all 3U 4U and 5U vertical versions of the relay The SEL 421 front panel has three pockets for slide in labels one pocket for the target LED label and two pockets for the operator control labels Figure 2 1 shows the front panel pocket areas and openings for typical horizontal and verti cal relay orientations dashed lines denote the pocket areas Refer to the instruc tions included i...

Page 53: ... a 3U relay with fixed terminal block analog inputs Figure 2 3 shows a rear panel for a 3U relay with Connector ized analog inputs See Rear Panel Layout on page 2 26 for representative 3U 4U and 5U relay rear panels large drawings are in Figure 2 24 Figure 2 32 Figure 2 1 Horizontal Front Panel Template a Vertical Front Panel Template b Operator Control Labels Target LED Label Opening a b Opening ...

Page 54: ...Secondary Circuit Connectors Fixed Terminal Blocks Connect PT and CT inputs to the fixed terminal blocks in the bottom row of the relay rear panel You cannot remove these terminal blocks from the relay rear panel These termi nals offer a secure high reliability connection for PT and CT secondaries Connectorized The Connectorized SEL 421 features receptacles that accept plug in plug out connectors ...

Page 55: ...s L N See AC Voltage Inputs on page 1 14 for complete PT input specifications Some applications do not use all three phases of a source for example voltage synchronization sources can be single phase See Section 6 Protection Applica tions Examples for examples of connections to the potential inputs See Secondary Circuit Connections on page 2 34 for information on connecting power system secondary ...

Page 56: ... state conditions of power system equipment These high isolation con trol inputs are polarity sensitive circuits You cannot damage these inputs with a reverse polarity connection although the relay will not detect input changes with a reverse polarity input For more information on control input specifications see Control Inputs on page 1 15 Inputs can be independent or common Independent inputs ha...

Page 57: ...ts on page 1 15 You can debounce the control input pickup delay and dropout delay separately for each input or you can use a single debounce setting that applies to all the contact input pickup and dropout times see Global Settings on page 8 2 AC Control Signals Optoisolated control inputs can be used with ac control signals within the ratings shown in Control Inputs on page 1 15 Specific pickup a...

Page 58: ...lay is disabled When the relay is reenabled the control outputs assume the state that reflects the present protection process ing Standard Control Outputs NOTE You can use ac or dc circuits with standard control outputs The standard control outputs are dry Form A contacts rated for tripping duty Ratings for standard outputs are 30 A make 6 A continuous and 0 5 A or less break depending on circuit ...

Page 59: ...e maximum pickup time for the hybrid control outputs is 6 ms Figure 2 5 shows a representative connection for a Form A hybrid control output on the main board I O terminals See Section 1 Introduction and Specifications for complete hybrid control out put specifications High Speed High Current Interrupting Control Outputs NOTE You can use ac or dc circuits with high speed high current interrupting ...

Page 60: ...l resistors Short transient inrush current can flow at the closing of an external switch in series with open high speed high current interrupting contacts This transient will not energize the circuits in typical relay coil control applications trip coils and close coils and standard auxiliary relays will not pick up However an extremely sensitive digital input or light duty high speed auxiliary re...

Page 61: ... I O interface board the precharge resistors shown in Figure 2 8 are built in to the I O board and connected to a third terminal On the INT4 I O interface board there are no built in precharge resistors and each high speed high current interrupting control output has only two terminal connections Main Board I O The SEL 421 base model is a 3U chassis with I O interface on the main board the top boa...

Page 62: ...ming accuracy of 1 µs If both inputs are connected the SEL 421 uses the IRIG B signal from the BNC connection if a signal is avail able Battery Backed Clock If relay input power is lost or removed a lithium battery powers the relay clock providing date and time backup The battery is a 3 V lithium coin cell Ray O Vac No BR2335 or equivalent If power is lost or disconnected the battery dis charges t...

Page 63: ... relay in larger enclosures 4U or 5U with all partial or no extra I O boards installed NOTE Ordering the 4U and 5U relay with partial or no extra I O allows for future system expansion and future use of additional relay features Plug in communications cards are also available for the SEL 421 The optional Ethernet card allows you to use TCP IP FTP Telnet DNP3 LAN WAN and IEC 61850 applications on a...

Page 64: ...inputs are isolated from other inputs These control inputs are optoisolated and hence are not polarity sensitive i e the relay will detect input changes with volt age applied at either polarity or ac signals when properly configured see Optoisolated on page 2 7 Figure 2 13 INT4 I O Interface Board Figure 2 14 INT5 I O Interface Board Figure 2 15 INT6 I O Interface Board Figure 2 16 INT7 I O Interf...

Page 65: ...card pro vides Ethernet ports for industrial applications that process data traffic between the SEL 421 and a local area network LAN Jumpers The SEL 421 contains jumpers that configure the relay for certain operating modes The jumpers are located on the main board the top board and the I O interface boards one or two boards located immediately below the main board Table 2 3 Control Inputs Board In...

Page 66: ...located on the front of the main board immediately left of the power connector see Figure 2 18 There are four jumpers denoted D BREAKER PASSWORD and A from left to right position D is on the left Position PASSWORD is the password disable jumper position BREAKER is the circuit breaker control enable jumper Posi tions D and A are for SEL use Figure 2 18 shows the jumper header with the cir cuit brea...

Page 67: ...t The SEL 421 ships with circuit breaker Jumper BREAKER OFF For com missioning and testing of the SEL 421 contact outputs it may be convenient to set BREAKER ON so that the PULSE OUTnnn commands can be used to check output wiring BREAKER must also be set ON if SCADA control of the circuit breaker via Fast Operate is required or if the LOCAL CONTROL BREAKER CONTROL screens are going to be used BREA...

Page 68: ...ers on the main board to connect 5 Vdc to Pin 1 of each of the three rear panel EIA 232 serial ports The maximum current available from this Pin 1 source is 0 5 A The Pin 1 source is useful for powering an external modem Figure 2 19 Major Component Locations on the SEL 421 Main Board J18 or J21 Rear of Relay ...

Page 69: ...o change Jumpers JMP2 JMP3 and JMP4 are located at the rear of the main board directly in front of PORT 3 PORT 2 and PORT 1 respectively see Figure 2 19 Step 12 Install or remove the jumper as needed see Table 2 5 for jumper position descriptions Step 13 Reinstall the SEL 421 main board and reconnect the power the interface board and the analog input board cables Step 14 Reconnect the cable remove...

Page 70: ...he relay to service I O Interface Board Jumpers Jumpers on the I O interface boards identify the particular I O board configura tion and I O board control address Eight I O interface boards are available INT1 INT2 INT3 INT4 INT5 INT6 INT7 and INT8 see I O Interface Boards on page 2 13 for more information on these boards The jumpers on these I O interface boards are at the front of each board as s...

Page 71: ...2 21 Date Code 20171021 Instruction Manual SEL 421 Relay Installation Jumpers Figure 2 20 Major Component Locations on the SEL 421 INT1 INT2 INT4 INT5 INT6 INT7 and INT8 I O Boards ...

Page 72: ... boards Refer to Figure 2 20 for the locations of these jumpers The I O board control address has a hundreds series prefix attached to the control inputs and control outputs for that particular I O board chassis slot A 4U chassis has a 200 addresses slot for inputs IN201 IN202 etc and outputs OUT201 OUT202 etc A 5U chassis has a 200 addresses slot and a 300 addresses slot Figure 2 21 Major Compone...

Page 73: ... ac control power is used to operate the breaker then the corresponding arc suppression jumper must be removed If dc control power is used to operate the breaker then the arc suppression is strongly recommended to break inductive loads The arc suppression comes enabled from the factory Figure 2 21 shows the jumper locations on the magnetics auxiliary pushbutton board NOTE With arc suppression enab...

Page 74: ...e relay in extreme temperature and humidity locations The tem perature range over which the relay operates is 40 to 185 F 40 to 85 C see Operating Temperature on page 1 16 The relay operates in a humidity range from 5 to 95 percent no condensation and is rated for installation at a maximum altitude of 2000 m 6560 feet above mean sea level Rack Mounting When mounting the SEL 421 in a rack use the r...

Page 75: ...ing This subsection presents a representative sample of relay rear panel configurations and the connections to these rear panels Only horizontal chassis are shown rear panels of vertical chassis are identical to hori zontal chassis rear panels for each of the 3U 4U and 5U sizes When connecting the SEL 421 refer to your company plan for wire routing and wire management Be sure to use wire that is a...

Page 76: ...l connections for the INT1 or INT2 and the INT6 or INT7 I O interface boards are the same The INT5 or INT8 I O interface board has control output terminals grouped in threes with the fourth terminal as a blank additional separator terminals 4 8 12 16 20 24 28 and 32 The INT3 INT4 and INT5 or INT8 I O interface boards both contain high speed high current interrupting control outputs but use a diffe...

Page 77: ...171021 Instruction Manual SEL 421 Relay Installation Connection Figure 2 25 EtherCAT Board for TiDL Figure 2 26 4U Rear Panel Main Board Without Optional I O Figure 2 27 4U Rear Panel Main Board INT5 I O Interface Board ...

Page 78: ... 20171021 Installation Connection Figure 2 28 4U Rear Panel Main Board INT8 I O Interface Board The INT3 board is the 200 addresses slot the INT1 board is the 300 addresses slot Figure 2 29 5U Rear Panel Main Board INT3 and INT1 I O Interface Board ...

Page 79: ...Relay Installation Connection The INT4 board is the 200 addresses slot the INT1 board is the 300 addresses slot Figure 2 30 5U Rear Panel Main Board INT4 and INT1 I O Interface Board Figure 2 31 5U Rear Panel Main Board INT6 and INT4 I O Interface Board ...

Page 80: ...mum width of 9 1 mm 0 360 in The screws in the rear panel screw terminal connectors are 8 32 binding head slot ted nickel plated brass screws Tightening torque for the terminal connector screws is 1 0 Nm to 2 0 Nm 9 in lb to 18 in lb You can remove the screw terminal connectors from the rear of the SEL 421 by unscrewing the screws at each end of the connector block Perform the following steps to r...

Page 81: ...nction screw terminal connectors to other locations on the rear panel To move these connectors to other locations you must change the screw terminal connector keying Inserts in the circuit board receptacles key the receptacles for only one screw ter minal connector in one orientation Each screw terminal connector has a missing web into which the key fits see Figure 2 34 If you want to move a screw...

Page 82: ...ection Figure 2 35 Rear Panel Receptacle Keying A B C 1 2 3 A B C 1 2 3 A B C 2 1 3 C A B B 2 1 3 A C 1 2 3 A B C 2 1 3 C A B B 1 2 3 A C 1 2 3 Key Inserts One Pair for Each Screw Terminal Connector 200 Addresses Receptacles 100 Addresses Receptacles 300 Addresses Receptacles ...

Page 83: ...8 AWG or larger size wire to connect to the POWER terminals Connection to external power must comply with IEC 60947 1 and IEC 60947 3 and must be identified as the disconnect device for the equipment Place an external disconnect device switch fuse combination or circuit breaker in the POWER leads for the SEL 421 this device must interrupt both the hot H and neutral N power leads The current rating...

Page 84: ...s in detail The alert symbol and the word DANGER on the rear panel indicate that you should use all safety precautions when connecting secondary circuits to these ter minals To verify these connections use SEL 421 metering see Examining Metering Quantities on page 3 35 in the SEL 400 Series Relays Instruction Manual You can also review metering data in an event report that results when you issue t...

Page 85: ... install these connectors in only one orientation Control Circuit Connections You can configure the SEL 421 with many combinations of control inputs and control outputs See Main Board I O on page 2 11 and I O Interface Boards on page 2 13 for information about I O configurations This subsection provides details about connecting these control inputs and outputs Refer to Figure 2 2 Figure 2 10 and F...

Page 86: ... Connect the hybrid high current interrupt ing outputs to dc circuits only The screw terminal connector legends alert you about this requirement by showing polarity marks on the hybrid high current interrupting contacts Form A SPST NO contacts comprise the majority of the control outputs Two pairs of Form C SPDT CO contacts are on the main board the INT1 INT2 I O interface board and the INT6 INT7 ...

Page 87: ...age 3 67 in the SEL 400 Series Relays Instruction Manual In addition you can use the SET O command see Output Settings on page 8 35 for more details You can also use the front panel to set and verify operation of the outputs see Set Show on page 4 25 in the SEL 400 Series Relays Instruction Manual Auxiliary TRIP CLOSE Pushbuttons and OPEN CLOSED LEDs Select Models Only Select relay models feature ...

Page 88: ...ard SEL 421 Relay Axion Remote Modules The SEL 2240 Axion is a fully integrated analog and digital I O control solution that is suitable for remote data acquisition An Axion node consists of a 10 slot 4 slot or dual 4 slot chassis that is configurable to contain a power module and combinations of CT PT digital input DI or digital output DO modules SEL 2243 Power Coupler Each chassis requires a SEL...

Page 89: ...mod ules that occur in the network Only the first 12 of 24 inputs are used in each module to help distribute the I O around the network more efficiently The inputs are mapped to the relay inputs based on the order in which the DI module occurs in the TiDL network There can be multiple DI modules in an Axion node and the order of the DI modules will proceed from left to right in the node to determi...

Page 90: ...s The outputs use the first 8 of the10 outputs and map as follows Fifth SEL 2244 2 DI Module IN501 IN512 Sixth SEL 2244 2 DI Module IN513 IN524 Figure 2 40 SEL 2244 2 Digital Input Module First SEL 2244 5 DO Module OUT301 OUT308 Second SEL 2244 5 DO Module OUT309 OUT316 Third SEL 2244 5 DO Module OUT401 OUT408 Fourth SEL 2244 5 DO Module OUT409 OUT416 Fifth SEL 2244 5 DO Module OUT501 OUT508 Sixth...

Page 91: ...t Module The SEL 2245 42 AC Analog Input Module see Figure 2 42 provides protec tion class ac analog input CT PT and can accept three voltage and three current inputs The module samples at 24 kHz and is 1 A or 5 A software selectable Depending on the supported fixed topology multiple CT PT input modules can function in each node Some topologies only support one CT PT module per node See Topologies...

Page 92: ...iDL system is commissioned see Commissioning on page 2 44 the firmware validates the connected Axion nodes and identifies if the installed CT PT modules in the system match one of the supported topologies for the SEL 421 Ports listed as optional in the following topology diagrams do not require a CT PT module to be connected to them All other ports require a CT PT module to be connected for the re...

Page 93: ...onal VCZ optional SEL Relay SEL Axion SEL Axion SEL Axion SEL Axion SEL Axion Substation Yard Control House This topology uses two CT PT modules installed in one Axion node The first module maps to the W currents and Y voltages and the second module maps to the X currents and Z voltages Figure 2 44 Topology 2 VBZ IAX IBX ICX VAY VBY VCY VAZ IAW IBW ICW Port 6A Analogs IAW IBW ICW VAY VBY VCY IAX I...

Page 94: ...his data to the Axion modules and adjusts the scaling in the appropriate Axion module when this com mand is used In addition to the CT nominal values TiDL relays also require that the nominal frequency be set by issuing the CFG NFREQ command At Access Level 2 issue a CFG NFREQ 60 command to set the relay to 60 Hz nominal or issue a CFG NFREQ 50 command to set the relay to 50 Hz nominal This comman...

Page 95: ...logy is complete the voltages and currents map according to the topology assignments see Topologies on page 2 42 Secondary injection testing takes place at each Axion node Test sources must inject voltages and currents to the Axion node to verify correct installation and mapping Monitoring of the voltages and currents remains in the control house with the relay LED Status As shown in Figure 2 46 t...

Page 96: ...ed on the unit that is farthest from the source This termination provides impedance matching of the cable for the best possible signal to noise ratio Where distance between the SEL 421 and the IRIG B sending device exceeds the cable length recommended for conventional EIA 232 metallic conductor cables you can use transceivers to provide isolation and to establish communication to remote locations ...

Page 97: ... establish communication between the relay and a DTE device a computer terminal for example with a DB 9 con nector use an SEL C234A cable Alternatively you can use a SEL C662 cable to connect to a USB port Figure 2 47 shows the configuration of SEL C234A cable that you can use for basic ASCII and binary communication with the relay A properly configured ASCII terminal terminal emulation program or...

Page 98: ...e locations examples are the SEL 28XX series transceivers Lower data speed communication is less susceptible to interference and will transmit greater distances over the same medium than higher data speeds Use the lowest data speed that provides an adequate data transfer rate Ethernet Network Connections The optional Ethernet card for the SEL 421 comes with two ports either A and B or C and D You ...

Page 99: ... are high you must either use STP cable or shield UTP using grounded ferrous raceways such as a steel con duit Figure 2 49 Two 100BASE FX Port Configuration on Ports 5A and 5B Figure 2 50 Two 10 100BASE T Port Configuration on Ports 5A and 5B Figure 2 51 100BASE FX and 10 100BASE T Port Configuration on Ports 5A and 5B Figure 2 52 Two 100BASE FX Port Configuration on Ports 5C and 5D Figure 2 53 Tw...

Page 100: ...ithin panels rather make them perpendicular to the other wiring You must use a cable and connector rated as Category 5 Cat 5 to operate the twisted pair interface 10 100BASE T at 100 Mbps Because lower categories are becoming rare and because you may upgrade a 10 Mbps network to 100 Mbps we recommend using all Cat 5 or better components Some industrial Ethernet network devices use 9 pin connectors...

Page 101: ... IBW IAW VCY VBY VAY A BUS SEL 421 Relay B C LINE Forward Direction Trip Coil 52A1 OUT101 Breaker 1 Trip Circuit TC Close Coil 52B1 OUT102 Breaker 1 Close Circuit CC Lock Out 86B1 OUT103 Breaker Failure Trip Circuit 86 OUT108 Alarm to Annunciator RTU or SEL 2020 2030 IN101 IN102 52A1 Breaker Status 1 Breaker Failure Lock Out Power Power Vdc1 Vdc2 Monitor Vdc1 Station Battery Monitor Vdc2 Trip Circ...

Page 102: ... 2030 OUT108 Trip Coil 52A1 OUT101 Breaker 1 Trip Circuit TC Close Coil 52B1 OUT102 Breaker 1 Close Circuit CC Lock Out 86B1 OUT103 Bus 1 Breaker Failure Trip Circuit 86 Trip Coil 52A2 OUT201 Breaker 2 Trip Circuit TC Close Coil 52B2 OUT202 Breaker 2 Close Circuit CC Lock Out 86B2 OUT203 Bus2 Breaker Failure Trip Circuit 86 Synchronism Check Circuit Breaker 2 VBZ VCY VBY VAY Power Power Vdc1 Monit...

Page 103: ...rams Figure 2 57 SEL 421 Example Wiring Diagram Using the Auxiliary TRIP CLOSE Pushbuttons Remote Close Auto Reclose To Close Circuit Manual Close Pushbutton 207 208 52b Breaker Open Breaker Closed Manual Trip Pushbutton Remote Trips Protection Trips 43 Local 52a 52 TC 203 204 201 202 205 206 ...

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Page 105: ...e input module board At the right side of the relay main board the top board is the processing module The input to the processing module is multipin connector J24 the analog or low level test interface connection Receptacle J24 is on the right side of the main board for a locating diagram see Figure 2 19 on page 2 18 Figure 3 1 shows the low level interface connections Note the nominal voltage lev...

Page 106: ...he applied test voltages and currents pro duce correct relay operating quantities The UUT Database entries for the SEL 421 in the SEL 5401 Relay Test System Software are shown in Table 3 1 and Table 3 2 Figure 3 1 Low Level Test Interface Table 3 1 UUT Database Entries for SEL 5401 Relay Test System Software 5 A Relay Label Scale Factor Unit 1 IAW 75 A 2 IBW 75 A 3 ICW 75 A 4 IAX 75 A 5 IBX 75 A 6...

Page 107: ...The text and figures in this subsection describe the test source connections you need for relay protection element checks You can use these connections to test protective elements and simulate all fault types 5 IBX 15 A 6 ICX 15 A 7 VAY 150 V 8 VBY 150 V 9 VCY 150 V 10 VAZ 150 V 11 VBZ 150 V 12 BCZ 150 V Table 3 2 UUT Database Entries for SEL 5401 Relay Test System Software 1 A Relay Sheet 2 of 2 ...

Page 108: ...hows the connections to use when you have three voltage sources and three current sources available Figure 3 2 Test Connections Using Three Voltage and Three Current Sources Three Phase Voltage and Current Test Sources IA VB IB VC IC VA IAW Z01 Z02 Z03 Z04 Z05 Z06 Z13 Z14 Z15 Z16 Z17 Z18 IBW ICW VAY VBY VCY Relay Rear Panel Analog Voltage and Current Inputs N N N ...

Page 109: ...ions shown in Figure 3 3 to simulate phase to phase phase to ground and two phase to ground faults Use the connections shown in Figure 3 4 to simulate three phase faults Figure 3 3 Test Connections Using Two Current Sources for Phase to Phase Phase to Ground and Two Phase to Ground Faults Three Phase Voltage and Current Test Sources IA VB IB VC IC VA IAW Z01 Z02 Z03 Z04 Z05 Z06 Z13 Z14 Z15 Z16 Z17...

Page 110: ...nnections Figure 3 4 Test Connections Using Two Current Sources for Three Phase Faults Three Phase Voltage and Current Test Sources IA VB IB VC IC VA IAW Z01 Z02 Z03 Z04 Z05 Z06 Z13 Z14 Z15 Z16 Z17 Z18 IBW ICW VAY VBY VCY Relay Rear Panel Analog Voltage and Current Inputs N N N ...

Page 111: ...rrent source You can use the connections shown in Figure 3 5 to simulate phase to ground faults Use the connections shown in Figure 3 6 to simulate phase to phase faults Figure 3 5 Test Connections Using a Single Current Source for a Phase to Ground Fault Three Phase Voltage and Current Test Sources IA VB IB VC IC VA IAW Z01 Z02 Z03 Z04 Z05 Z06 Z13 Z14 Z15 Z16 Z17 Z18 IBW ICW VAY VBY VCY Relay Rea...

Page 112: ...elay metering to verify that the relay current and voltage inputs are the proper magnitude and phase rotation see Examining Metering Quantities on page 3 35 in the SEL 400 Series Relays Instruction Man ual Commissioning tests help you verify that you have properly connected the relay to the power system and all auxiliary equipment These tests confirm proper con nection of control inputs and contro...

Page 113: ... inputs with the phase overcurrent element pickup setting The relay asserts the phase overcurrent elements when any of the three phase cur rents exceeds the corresponding element pickup setting Negative Sequence Overcurrent Elements The SEL 421 negative sequence overcurrent elements compare a negative sequence calculation of the three phase secondary inputs with the corresponding negative sequence...

Page 114: ... overcur rent element Use a similar procedure to test other overcurrent elements Step 1 Configure the relay a Start ACSELERATOR QuickSet SEL 5030 Software and read the present configuration in the SEL 421 b Click Settings Read The relay sends all settings and configuration data to QuickSet c Expand the Group 1 settings and click the Negative Seq Inst O C button of the Settings tree view as shown i...

Page 115: ...ront panel LCD MAIN MENU b Highlight RELAY ELEMENTS and press ENT c Press ENT to go to the ELEMENT SEARCH submenu shown in Figure 3 9 d Use the navigation keys to highlight 5 and then press ENT to enter characters in the text input field e Enter the 0 Q and 1 characters in turn f Highlight ACCEPT and press ENT The relay displays the screen containing the 50Q1 element as shown in Figure 3 10 Figure...

Page 116: ... sequence directional element asserts the phase directional element asserts The relay also contains a ground directional element F32G R32G for directional control of the ground distance elements and ground overcurrent elements For more information on directional elements see Ground Directional Element on page 5 33 and Section 6 Protection Applications Examples The SEL 421 calculates the negative s...

Page 117: ...nce threshold Equation 3 2 becomes Equation 3 4 when Equation 3 5 For a reverse fault impedance threshold where Z2c Z2R Equation 3 2 becomes Equation 3 6 when the angle calculation is the same as Equation 3 5 For more information on the directional elements see Ground Directional Ele ments on page 1 18 and Quadrilateral Ground Distance Elements on page 1 18 For settings and application information...

Page 118: ...the Settings tree view as shown in Figure 3 11 d Disable supervisory elements Confirm that ELOP is set to N e In a similar sequence click on the button to expand the Relay Configuration tree view click on Load Encroachment and confirm that ELOAD is set to N f Defeat the pole open logic g Click the button next to Breaker Monitor to expand the Breaker Monitor branch of the Settings tree view see Fig...

Page 119: ...ration dialog box of Figure 3 13 b Confirm the default settings of Z1MAG at 7 80 and Z1ANG at 84 00 c Click the mark next to the Relay Configuration branch to expand that Settings branch d Select the Directional button You will see the Directional dialog box similar to Figure 3 14 e Confirm the following settings E32 is AUTO ORDER is Q 50FP is 0 60 50RP is 0 40 Z2F is 3 90 Z2R is 4 00 a2 is 0 10 a...

Page 120: ...3 16 SEL 421 Relay Instruction Manual Date Code 20171021 Testing Checking Relay Operation Figure 3 13 Group 1 Line Configuration Settings QuickSet ...

Page 121: ...roups dialog box in Figure 3 15 b Click the check box for Group 1 and for Breaker Monitor c Click OK d QuickSet responds with a Transfer Status dialog box as in Figure 3 15 If you see no error message the new settings are loaded in the relay Figure 3 14 Directional Settings QuickSet Table 3 3 Negative Sequence Directional Element Settings AUTO Calculations Setting Calculation 50FP 0 12 INOM 50RP 0...

Page 122: ...ure 3 16 Step 5 Calculate impedance thresholds a For this test apply an A Phase voltage of VA 3V2 18 0 180 V secondary b Use Equation 3 6 to find the current that is equal to the reverse impedance threshold Z2R Equation 3 7 Step 6 Use Equation 3 4 to find the current that is equal to the forward impedance threshold Z2F Equation 3 8 Figure 3 15 Uploading Group 1 and Breaker Monitor Settings to the ...

Page 123: ... and currents to the relay analog inputs that simulate fault and load conditions to test distance elements The relay supervises distance elements so that these elements operate under the appropriate conditions Be sure to satisfy all the element supervisory conditions before testing a relay element For supervi sory conditions for a particular element see Mho Ground Distance Elements on page 5 72 Ph...

Page 124: ... VBC phasor is to equate VB and VC and determine the appropriate angles to make an equilateral triangle as shown in Figure 3 17 Subtract 30 degrees angle 1 from 180 degrees to obtain the angle for test source VC phasor VC 46 8 150 V Similarly add 30 degrees angle 2 to 180 degrees to obtain test source VB phasor VB 46 8 150 V Test voltage VA can be the nominal value VA 67 0 V Thus the resulting pha...

Page 125: ...directly to the Zone 2 phase distance element you can apply this procedure to any other forward reaching phase to phase distance element zone Step 1 Configure the relay Perform the procedure listed under Step 1 in Checking the Negative Sequence Directional Element Phase Faults on page 3 13 Step 2 Set test values in the relay Perform the procedure listed under Step 2 in Checking the Negative Sequen...

Page 126: ...reen d Press ENT to go to the ELEMENT SEARCH submenu shown in Figure 3 9 e Use the navigation keys to highlight M and press ENT to enter character in the text input field f Enter the B C and 2 characters in like manner g Highlight ACCEPT and press ENT The relay displays the LCD screen containing the MBC2 element as shown in Figure 3 19 Step 6 Set the magnitudes and angles of the test signals for a...

Page 127: ...D screen Relay Word bit MBC2 asserts when IB 2 5 A indicating that the relay impedance calculation is less than the Z2MP reach setting Technical Support We appreciate your interest in SEL products and services If you have questions or comments please contact us at Schweitzer Engineering Laboratories Inc 2350 NE Hopkins Court Pullman WA 99163 5603 U S A Tel 1 509 338 3838 Fax 1 509 332 7990 Interne...

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Page 129: ...rgets Accessing settings Controlling relay operations General front panel operations are described in the Section 4 Front Panel Oper ations in the SEL 400 Series Relays Instruction Manual This section provides additional information that is unique to the SEL 421 This section includes the following Front Panel LCD Default Displays on page 4 1 Front Panel Menus and Screens on page 4 3 Target LEDs on...

Page 130: ...1 are representative values Table 4 1 Metering Screens Enable Settings Name Prompt Range Default RMS_V RMS Line Voltage Screen Y N N RMS_I RMS Line Current Screena a The default displays are RMS_I and FUND_VI Y N Y RMS_VPP RMS Line Voltage Phase to Phase Screen Y N N RMS_W RMS Active Power Screen Y N N FUNDVAR Fundamental Reactive Power Screen Y N N RMS_VA RMS Apparent Power Screen Y N N RMS_PF RM...

Page 131: ...um of 9 display points screens If a display point does not have text to display the screen space for that display point is maintained Front Panel Menus and Screens Operate the SEL 421 front panel through a sequence of menus that you view on the front panel display The MAIN MENU is the introductory menu for other front panel menus These additional menus allow you on site access to metering con Figu...

Page 132: ...on most of these screens The following screen descrip tions are unique to the SEL 421 Meter The SEL 421 displays metering screens on the LCD Highlight METER on the MAIN MENU screen to select these screens The METER MENU shown in Figure 4 2 allows you to choose the following metering screens corresponding to the relay metering modes RMS METER FUNDAMENTAL METER DEMAND METER if enabled ENERGY METER M...

Page 133: ...ettings configuration Other combinations of settings ESS and NUMBK do not require separate circuit breaker metering screens for these configurations the relay does not present the METER SUBMENU screen See Section 5 Protection Functions and Global Settings on page 6 3 for information on configuring global settings ESS NUMBK LINEI BK1I and BK2I The relay presents the meter screens in the order shown...

Page 134: ...x xxx x xxx SEQUENCE V kV V1 x xxx x xxx 3V2 x xxx x xxx 3V0 x xxx x xxx FUND LINE METER ACTIVE POWER MW A xx xxx x B xx xxx x C xx xxx x 3P xx xxx x REACTIVE MVAR A xx xxx x B xx xxx x C xx xxx x 3P xx xxx x FUND LINE METER APPARENT POWER MVA A xx xxx xx B xx xxx xx C xx xxx xx 3P xx xxx xx POWER FACTOR A x xx LEAD B x xx LEAD C x xx LEAD 3P x xx LEAD FUND LINE METER CURRENTS A IA x xxx xx xxx IB...

Page 135: ...xxx xx ENERGY METER ENERGY TOTAL MWh A xx xxx xx B xx xxx xx C xx xxx xx 3P xx xxx xx ENERGY METER RESET ENERGY NOW NO YES LAST ENERGY RESET MM DD YYYY HH MM SS CURRENTS A IA MAX xx xxx x MIN xx xxx x IB MAX xx xxx x MIN xx xxx x IC MAX xx xxx x MIN xx xxx x I1 MAX xx xxx x 3I2 MAX xx xxx x 3I0 MAX xx xxx x MAX MIN LINE BREAKER METERING ACTIVE POWER MW 3P MAX xx xxx x MIN xx xxx x MAX MIN LINE FRE...

Page 136: ...gure 4 7 View Configuration You can use the front panel to view detailed information about the configuration of the firmware and hardware components in the SEL 421 Relay In the MAIN MENU highlight the VIEW CONFIGURATION option by using the navigation pushbut tons The relay presents four screens in the order shown in Figure 4 8 Use the navigation pushbuttons to scroll through these screens When fin...

Page 137: ...Panel Settings on page 8 35 Use the slide in labels to mark the LEDs with custom names Included on the SEL 421 Product Literature CD are Customer Label Templates to print labels for the slide in label carrier Figure 4 8 VIEW CONFIGURATION Sample Screens FID SEL 421 5 R101 V0 Z012012 D20100130 PART NUMBER 0451541 5XC0X4H60X0XXX S N 201001001 SELBOOT BFID SLBT 4XX R205 V0 Z001002 D20100130 CHECKSUM ...

Page 138: ...round distance element pick up and the relay has not illuminated the COMM or SOTF targets The TIME target LED indicates that a timed relay element caused a relay trip Table 4 3 lists the elements that activate the TIME LED in the factory default set tings Figure 4 9 Factory Default Front Panel Target Areas 16 or 24 LEDs Table 4 2 Front Panel Target LEDs Label Function ENABLED TRIP Operational INST...

Page 139: ... Z2P or Z2G distance elements operated or if the high speed Zone 2 elements operated and the similar ele ments in Zone 1 did not operate The ZONE 3 target illuminates if either the Z3P or Z3G distance elements operated or if the high speed Zone 3 elements operated and the similar ele ments in Zone 1 and Zone 2 did not operate The ZONE 4 target illuminates if either the Z4P or Z4G distance elements...

Page 140: ...LE target illuminates when the relay the relay is in the autoreclose cycle state for Circuit Breaker 1 Miscellaneous Status The 25 SYNCH BKR CLOSE BKR FAIL OSB and LOP target LEDs illuminate in the SEL 421 for miscellaneous status conditions The 25 SYNCH LED illuminates when the relay detects that the Circuit Breaker 1 voltages are within Synchronism Angle 1 Relay Word bit 25A1BK1 is asserted See ...

Page 141: ... 4 For a concise listing of the default programming for the front panel pushbuttons and LEDs see Front Panel Settings on page 8 35 Figure 4 10 Operator Control Pushbuttons and LEDs 8 or 12 Pushbuttons Table 4 4 Operator Control Pushbuttons and LEDs Factory Defaults Label Function SPT ENABLED Enable single pole tripping COMM SCHEME ENABLED Enable communications scheme ALT SETTINGS Switch between se...

Page 142: ...ow or the Down Arrow pushbutton Pressing the ESC pushbutton will return the user to the ROTATING DISPLAY The second way to program the operator control pushbutton is through SELOGIC control equations using the pushbutton output as a programming element Using SELOGIC control equations you can readily change the default LED func tions Use the slide in labels to mark the pushbuttons and pushbutton LE...

Page 143: ...ables and disables the CLOSE pushbutton PBn_LED 52ACL1 and 52BCL1 and 52CCL1 BREAKER CLOSED BREAKER CLOSED Press this operator control pushbutton to enable disable the automatic recloser The corresponding LED illuminates to indicate the RECLOSE ENABLED state PBn_LED PLT06 RECLOSE ENABLED RECLOSE ENABLED Press this operator control pushbutton to enable disable local front panel circuit breaker clos...

Page 144: ...Line Diagrams You can also configure an HMI pushbutton to give you direct access to the bay control screen Figure 4 13 shows an example of how to configure HMI Pushbut ton 1 by selecting the BC option from the drop down menu Figure 4 12 Bay Control Screen Selected for Rotating Display ...

Page 145: ...ased on the EPOLDIS setting If EPOLDIS Y then the breaker status is indicated by the Relay Word bits 52ACLn 52BCLn and 52CCLn which check for current to determine the breaker status This setting is useful to identify a pole discrepancy where a pole may not open but the other two do In this case the breaker status would display a pole discrep ancy screen as shown below in Figure 4 14 If EPOLDIS N t...

Page 146: ... 4 18 Figure 4 19 Bus 1 Bus 2 and Transfer Bus one line diagram Figure 4 20 Transfer Bay one line diagram Figure 4 21 Tie Breaker Bay one line diagram Figure 4 22 Figure 4 23 Main Bus and Transfer Bus one line diagram Figure 4 24 Figure 4 25 Main Bus one line diagram Figure 4 26 Figure 4 30 Breaker and a Half one line diagram Figure 4 31 Figure 4 32 Ring Bus one line diagram Figure 4 33 Figure 4 3...

Page 147: ... Configurations Main Bus and Auxiliary Bus Figure 4 15 Bay With Ground Switch Option 1 Figure 4 16 Bay Without Ground Switch Option 2 BAYNAME BUSNAM1 SW4 SW5 BK1 SW2 SW3 SW1 BUSNAM2 ESC NAVIG AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 BAYNAME BUSNAM1 SW4 BK1 SW2 SW3 SW1 BUSNAM2 ESC NAVIG AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ...

Page 148: ...Diagrams Bus 1 Bus 2 and Transfer Bus Figure 4 17 Tie Breaker Bay Option 3 BAYNAME BUSNAM1 BK1 SW2 SW1 BUSNAM2 ESC NAVIG AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 Figure 4 18 Bay With Ground Switch Option 4 BAYNAME BUSNAM1 BUSNAM3 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW4 SW5 BK1 SW2 SW3 SW1 ...

Page 149: ...ine Diagrams Transfer Bay Figure 4 19 Bay Without Ground Switch Option 5 BAYNAME BUSNAM1 BUSNAM3 ESC NAVIG BUSNAM2 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 SW4 BK1 SW2 SW3 SW1 Figure 4 20 Transfer Bay Option 6 BAYNAME BUSNAM1 BUSNAM3 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 BK1 SW2 SW3 SW1 ...

Page 150: ...rams Tie Breaker Bay Main Bus and Transfer Bus Figure 4 21 Tie Breaker Bay Option 7 BAYNAME BUSNAM1 BUSNAM3 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 BK1 SW2 SW1 Figure 4 22 Bay With Ground Switch Option 8 BAYNAME BUSNAM1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW3 SW4 BK1 SW2 SW1 ...

Page 151: ...ons One Line Diagrams Main Bus Figure 4 23 Bay Without Ground Switch Option 9 BAYNAME BUSNAM1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW3 BK1 SW2 SW1 Figure 4 24 Bay With Ground Switch Option 10 BAYNAME AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG SW3 SW4 BK1 SW2 BUSNAM1 SW1 ...

Page 152: ...grams Breaker and a Half Figure 4 25 Bay Without Ground Switch Option 11 BAYNAME AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG SW3 BK1 SW2 BUSNAM1 SW1 Figure 4 26 Left Breaker Bay With Ground Switch Option 12 BAYNAME BUSNAM1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW3 SW2 SW4 BK1 BK3 BK2 SW1 ...

Page 153: ...el Operations One Line Diagrams Figure 4 27 Right Breaker Bay With Ground Switch Option 13 Figure 4 28 Middle Breaker Bay Option 14 BAYNAME BUSNAM1 ESC NAVIG BUSNAM2 SW3 SW2 SW4 BK3 BK2 BK2 SW1 BAYNAME BUSNAM1 ESC NAVIG BUSNAM2 SW3 BAYLAB1 BAYLAB2 BK1 BK2 BK3 SW1 SW2 ...

Page 154: ... Figure 4 29 Left Breaker Bay Without Ground Switch Option 15 Figure 4 30 Right Breaker Bay Without Ground Switch Option 16 BAYNAME BUSNAM1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW3 SW2 BK1 BK3 BK2 SW1 BAYNAME BUSNAM1 ESC NAVIG BUSNAM2 SW3 SW2 BK1 BK3 BK2 SW1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ...

Page 155: ...ne Line Diagrams Ring Bus Figure 4 31 Bay With Ground Switch Option 17 Figure 4 32 Bay Without Ground Switch Option 18 BAYNAME BAYLAB1 BAYLAB2 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG SW2 BK1 BK2 SW1 SW3 BAYNAME BAYLAB1 BAYLAB2 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG SW2 BK1 BK2 SW1 ...

Page 156: ...us Double Breaker Figure 4 33 Left Breaker Bay With Ground Switch Option 19 Figure 4 34 Left Breaker Bay Without Ground Switch Option 20 BAYNAME BUSNAM1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW3 SW2 BK1 BK2 SW1 SW4 BAYNAME BUSNAM1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ESC NAVIG BUSNAM2 SW3 SW2 BK1 BK2 SW1 ...

Page 157: ...ams Figure 4 35 Right Breaker Bay With Ground Switch Option 21 Figure 4 36 Right Breaker Bay Without Ground Switch Option 22 BAYNAME BUSNAM1 ESC NAVIG BUSNAM2 SW3 SW2 BK1 BK2 SW1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 SW4 BAYNAME BUSNAM1 ESC NAVIG BUSNAM2 SW3 SW2 BK1 BK2 SW1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 ...

Page 158: ...ine Diagrams Source Transfer Bus Throw Over Bus Figure 4 37 Source Transfer Option 23 BAYNAME ESC NAVIG BUSNAM2 BAYLAB1 BUSNAM1 BK2 BK1 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 Figure 4 38 Throw Over Bus Type 1 Switch Option 24 BAYNAME BUS1 ESC NAVIG BUS2 SW2 AQ_2 AQ_1 SW1 AQ_3 AQ_4 AQ_5 AQ_6 BK1 ...

Page 159: ... visible in the present screen view Figure 4 40 shows an example station with a breaker and a half application Figure 4 39 Throw Over Bus Type 2 Switch Option 25 BAYNAME BUS1 ESC NAVIG BUS2 SW5 SW3 SW1 SW4 BK2 BK1 SW2 AQ_1 AQ_2 AQ_3 AQ_4 AQ_5 AQ_6 Figure 4 40 Screen 1 BB1 SW1 SW2 SW3 SW4 CT1 BKR1 Screen1 Screen 2 Common Area BB2 SW5 SW6 SW7 SW8 CT2 CT3 CT4 BKR2 BKR3 CT T2 CT BKR T2 R2 CT CT2 T B T...

Page 160: ...two front panel screens Screen 1 plus the common area Figure 4 40 Screen 2 plus the common area Figure 4 41 When you specify a custom screen be sure to separately specify these three areas Figure 4 41 Screen 2 BB1 BB2 SW1 SW2 SW3 SW4 SW5 SW6 SW7 SW8 CT1 CT2 CT3 CT4 BKR1 BKR2 BKR3 BB1 SW1 SW2 SW3 SW4 SW5 CT1 BKR1 C C B BK BK CT CT2 T2 K 2 KR2 R2 2 C CT B T2 BK 2 K KR2 2 Screen1 Screen 2 Common Area...

Page 161: ...cation on page 5 23 Open Phase Detection Logic on page 5 24 Pole Open Logic on page 5 25 Loss of Potential Logic on page 5 28 Fault Type Identification Selection Logic on page 5 33 Ground Directional Element on page 5 33 Phase and Negative Sequence Directional Elements on page 5 45 Directionality on page 5 46 CVT Transient Detection on page 5 47 Series Compensation Line Logic on page 5 48 Load Enc...

Page 162: ...the main breaker then current IX is used as the line current source instead SELOGIC setting ALTI controls the switching between currents IW and IX as the line cur rent source assert setting ALTI to switch to designated alternate line current ALINEI IX Alternate line current source settings ALINEI and ALTI are not used often and thus are usually set to NA Setting ALTI is automatically hidden and se...

Page 163: ...3 on page 8 2 influences available settings combinations covered in Table 5 1 Table 5 2 and Table 5 3 In general if NUMBK 1 then no settings directly involving a second circuit breaker are made i e Breaker 2 current source setting BK2I is automatically set to NA and hidden as indicated with the shaded cells in the BK2I columns in Table 5 1 and Table 5 2 Also for source selection setting ESS N the ...

Page 164: ...NA NA 1 3 not allowed 1 4 not allowed 2 Y see Table 5 3 2 N IW NA IW NA NA 2 1 not allowed 2 2 not allowed 2 3 COMB NA IW IX NA 2 4 IW NA IX COMB NA Table 5 2 Available Current Source Selection Settings Combinations When ESS Y NUMBK 1a a NA not applicable Shaded cells indicate settings forced to given values and hidden NUMBK number of breakers ESS source selection LINEI line current source ALINEI ...

Page 165: ...ent Source Selection Settings Combinations When ESS Y NUMBK 2a a NA not applicable NUMBK number of breakers ESS source selection LINEI line current source ALINEI alternate line current source BK1I Breaker 1 current source BK2I Breaker 2 current source IPOL polarizing current 2 Y IW IX IW IX NA 2 Y IW IX IW COMB NA 2 Y IW IX IW NA NA 2 Y IW IX IX COMB NA 2 Y IW IX IX NA NA 2 Y IW IX NA IX NA 2 Y IW...

Page 166: ... polar ized directional element Such a directional element is applied to ground overcur rent elements see Table 5 31 and Table 5 27 Setting IPOL is not used often and thus is usually set to NA Notice that in Table 5 1 Table 5 2 and Table 5 3 there are relatively few scenarios where setting IPOL can be set to a current channel selection only those cases where three phase current input IX is not use...

Page 167: ...logic Series compensation line logic Load encroachment logic OOS out of step logic Distance elements SOTF switch onto fault logic POTT permissive overreaching transfer tripping scheme logic Metering on page 7 1 including synchrophasors Default Applications Use setting ESS Current and Voltage Source Selection to easily configure the relay for your particular application Five application settings ES...

Page 168: ...d as an alternate line current source ALINEI IX or as a polarizing current channel e g IPOL IBX but not both see Table 5 1 Table 5 5 ESS N Current and Voltage Source Selection Setting Prompt Entry Comments NUMBK Number of Breakers in Scheme 1 2 1 LINEI Line Current Source IW COMB IW Hidden BK1I Breaker 1 Current Source IW IX NA IW Hidden BK2I Breaker 2 Current Source IX COMB NA NA Hidden Figure 5 ...

Page 169: ...nd Circuit Breaker 2 ALINEV Alternate Line Voltage Source VZ NA NA ALTV Alternate Voltage Source SELOGIC Equation NA Hidden a Hidden when preceding setting is NA Table 5 6 ESS 1 Current and Voltage Source Selection Sheet 2 of 2 Setting Prompt Entry Comments Figure 5 6 ESS 2 Single Circuit Breaker Configuration Table 5 7 ESS 2 Current and Voltage Source Selection Setting Prompt Entry Comments NUMBK...

Page 170: ...ailure for Circuit Breaker 2 Figure 5 7 ESS 3 Double Circuit Breaker Configuration Table 5 8 ESS 3 Current and Voltage Source Selection Setting Prompt Entry Comments NUMBK Number of Circuit Breakers in Scheme 1 2 2 LINEI Line Current Source COMB COMB Automatic ALINEI Alternate Line Current Source NA NA Automatic ALTI Alternate Current Source SELOGIC Equation NA Hidden BK1I Breaker 1 Current Source...

Page 171: ...heme to 2 so you can program the auto reclosing function and synchronism check elements to control both of the low side circuit breakers Figure 5 8 ESS 4 Double Circuit Breaker Configuration Table 5 9 ESS 4 Current and Voltage Source Selection Setting Prompt Entry Comments NUMBK Number of Circuit Breakers in Scheme 1 2 2 LINEI Line Current Source IW IW Automatic ALINEI Alternate Current Source NA ...

Page 172: ...ide of a power transformer and two cir cuit breakers on the low side Figure 5 9 Tapped EHV Overhead Transmission Line Figure 5 10 ESS Y Tapped Line SEL 421 SEL 421 BK1S BK1R BK2S CB1 CB2 BK2R SEL 421 S R MOD HV LV T HV LV MOD SEL 421 Relay IW VY 1 1 3 3 VAZ VBZ CB2 CB1 Analog Input IW VY VAZ VBZ Function Line protection Line protection Synchronism check Circuit Breaker 1 Synchronism check Circuit ...

Page 173: ...ternate Current Source SELOGIC Equation NA Hiddena a Hidden when preceding setting is NA BK1I Breaker 1 Current Source IW IX NA NA BK2I Breaker 2 Current Source IX COMB NA NA IPOL Polarizing Current IAX IBX ICX NA NA ALINEV Alternate Line Voltage Source VZ NA NA Default ALTV Alternate Voltage Source SELOGIC Equation NA Hidden Figure 5 11 ESS Y Single Circuit Breaker With Current Polarizing Source ...

Page 174: ...ntity for Distance Element Calculations The relay uses positive sequence memory voltage as the polarizing quantity for distance element calculations Memory polarization ensures proper operation during zero voltage three phase faults and provides expansion of the mho charac teristic back to the source impedance improving fault resistance coverage How ever longer memory may impair distance element s...

Page 175: ...rocessing rate is called frequency tracking Note that frequency measurement is not the same as frequency tracking The relay first measures the frequency and then tracks the frequency by changing the processing rate The relay measures the frequency over the 20 80 Hz range protection frequency see FREQP in Table 5 16 but only tracks the frequency over the 40 65 Hz range see FREQ in Table 5 16 If the...

Page 176: ...he six voltage inputs to VF11 VF12 and VF13 The relay uses VF01 VF02 and VF03 as sources if the SELOGIC evaluation of EAFSRC is 0 The relay uses VF11 VF12 and VF13 as sources if EAFSRC is 1 The relay calculates the alpha quantity Valpha as shown in Figure 5 12 using the mapped sources Note that the alpha quantity is based on the instantaneous secondary voltage samples from the mapped resources and...

Page 177: ...e logic shown in Figure 5 13 supervises the frequency elements for system undervoltage conditions In the logic the com parator compares the absolute value of the alpha component voltage Valpha against the 81UVSP setting value Equation 5 1 shows the equation for calculat ing Valpha Equation 5 1 VF02 Local Freq Source 2 ZERO VAY VBY VCY VAZ VBZ VCZ VBY VF03 Local Freq Source 3 ZERO VAY VBY VCY VAZ V...

Page 178: ...age phasor Relay Word bit 27B81 asserts if Valpha falls below the 81UVSP setting value for longer than a cycle Calculate the 81UVSP Setting Value Because the relay accepts voltage input from the potential transformers PTs in any combination Valpha can have different values depending on the voltage inputs In general the following examples use the average 60 percent of the 50 to 70 percent undervolt...

Page 179: ...n 5 13 Equation 5 14 Table 5 17 summarizes the results of the three cases Over and Underfrequency Elements Use the relay frequency elements for such abnormal frequency protection as underfrequency load shedding Figure 5 15 shows the logic for the six levels of over and underfrequency ele ments in the relay Valpha 2 67 V Valpha 94 75 V 81UVSP 0 6 94 75 V 81UVSP 56 85 V Table 5 17 Table Y12 Summary ...

Page 180: ...y element operations during system faults Over and Underfrequency Element Settings E81 Enable 81 Elements Set E81 to enable as many as six over and underfrequency elements When E81 N the relay disables the frequency elements and hides corresponding set tings you do not need to enter these hidden settings 81UVSP 81 Element Undervoltage Supervision NOTE See Undervoltage Supervision Logic on page 5 1...

Page 181: ...sing edge operator R_TRIG should not be used in the LOADTE setting A correction feature allows the present time error estimate TE to be discarded and a new value TECORR loaded when SELOGIC control equation LOADTE asserts For example if the TECORR value is set to zero and then LOADTE is momentarily asserted the TE analog quantity will be set to 0 000 seconds The TECORR analog quantity can be pre lo...

Page 182: ...cal 1 will stall freeze the time error function The TE value will not change when STALLTE is asserted unless LOADTE asserts Relay Word bit FREQOK Frequency measurement valid If this Relay Word bit deasserts the TE quan tity is frozen see Table 5 16 OUTPUTS Description Analog Quantity TE Time error estimate in seconds Positive numbers indicate that the ac clock would be fast ahead of the reference ...

Page 183: ... a fault occurs at the midpoint of the protected line and you set LL to 126 for a line length of 126 kilo meters the result of the relay distance to fault calculation is 63 Distance to fault calculation results range from 999 99 to 999 99 If the calcula tion cannot be determined e g insufficient information or if the result is outside the specified range the relay reports the fault location as The...

Page 184: ...e Label Fault Type AG A Phase to ground BG B Phase to ground CG C Phase to ground AB A Phase to B Phase BC B Phase to C Phase CA C Phase to A Phase ABG A Phase to B Phase to ground BCG B Phase to C Phase to ground CAG C Phase to A Phase to ground ABC Three phase Table 5 21 Fault Location Settings Setting Prompt Range Default 5 A Z1MAG Positive Sequence Line Impedance Magnitude 0 25 1275 INOM 7 80 ...

Page 185: ...ential transformers for relaying pur poses Do not select option V if shunt reactors are applied because the voltage decays slowly after the circuit breaker s opens If you select EPO V the relay can incorrectly declare LOP during a pole open condition if there is charging cur rent that exceeds the open pole current threshold Table 5 23 Open Phase Detection Relay Word Bits Name Description B1OPHA Br...

Page 186: ...tions Pole Open Logic SPOC C Phase open SPO One or two poles open 3PO All three poles open 27APO A Phase undervoltage pole open 27BPO B Phase undervoltage pole open 27CPO C Phase undervoltage pole open Table 5 26 Pole Open Logic Relay Word Bits Sheet 2 of 2 Name Description ...

Page 187: ...gure 5 17 Pole Open Logic Diagram LOPHA Relay Word Bit 52AA1 52AA2 SPOA SPOB SPOC 0 3POD 0 SPOD SPO 3PO RESET VA Setting 27PO 27APO Relay Word Bit Setting EPO V SPOA Relay Word Bits SPOB SPOC NUMBK 2 BK2TYP 1 BK1TYP 1 Setting EPO 52 Identical Logic for B and C Phases Relay Word Bits Control Inputs ...

Page 188: ... an LOP when the circuit breaker s closes again The SEL 421 also asserts LOP upon circuit breaker closing for one or two miss ing PTs If the relay detects a voltage unbalance with balanced currents at circuit breaker close then the relay declares a loss of potential condition Inputs into the LOP logic are as follows 3PO three pole open condition SPO single pole open condition OOSDET out of step co...

Page 189: ...OP Y1 If you set ELOP to Y1 and an LOP condition occurs the voltage polarized direc tional elements and all distance elements are disabled This setting for ELOP also disables the overcurrent elements that these voltage polarized directional ele ments control Figure 5 18 illustrates how the LOP logic processes an LOP decision Figure 5 19 provides a logic diagram for the LOP logic Table 5 27 LOP Log...

Page 190: ...ing delta change in V1 V1 10 shown as an input in the logic diagram in Figure 5 19 2 Positive sequence current magnitude not changing Measure positive sequence current magnitude I1 k and compare it to I1 k 1 cycle from one cycle earlier If this difference is greater than two percent nominal current the condition measured is not an LOP even if all other conditions are met This input is labeled as I...

Page 191: ...le I0k and compare it to I0 k 1 cycle If this difference is greater than 5 degrees the condition measured is not an LOP even if all other condi tions are met This input is labeled as I0 5 in Figure 5 19 For security this declaration requires that I0 be greater than five percent of nominal cur rent to override an LOP declaration If the criteria identified in all five steps listed above are met the ...

Page 192: ... Y Y1 ILOP V 1 last cycle 8 V NOM V 1 85 V NOM I G 5 I NOM I 1 5 I NOM I 1 2 I NOM V 0 15 V 1 I G 15 I 1 V 1 15 V NOM Δ I G 6 I NOM Δ I 1 2 I NOM I G last cycle 5 I NOM I 1 last cycle 5 I NOM LOP last interval 15 CYC 0 0 CYC 30 3PO SPOA SPOB SPOC OOSDET 0 20 CYC 0 2 CYC 60 CYC 0 Δ I 1 5 Δ I G 5 3POR Δ V 1 10 S R Q 3PO Reset Relay Word Bits Setting Relay Word Bits Relay Word Bits ...

Page 193: ... set equal to Y to ensure proper operation of the phase and ground distance elements Ground Directional Element The SEL 421 offers a choice of three independent directional elements to super vise the ground distance elements and directional residual ground overcurrent elements 67Gn where n equals 1 through 4 during ground faults You can also use the ground directional element for torque control In...

Page 194: ...ional element is indicated by the 32SPOF and the 32SPOR Relay Word bits As the single pole open directional element may operate because of unbalance currents generated during the single pole open condition it is recommended that ground and negative sequence overcurrent elements that are used for single pole tripping be supervised by the single pole open condition To supervise overcur rent elements...

Page 195: ...ovide equal or better protection than E32 AUTO for most systems Detailed Settings Description If you set E32 to Y you can change the settings listed in Table 5 33 50FP and 50RP Setting 50FP is the threshold for the current level detector that enables forward decisions for both the negative and zero sequence voltage polarized directional elements If the magnitude of 3I2 or 3I0 is greater than 50FP ...

Page 196: ...factor k2 also compensates for highly unbalanced systems This factor is the ratio of the magnitude of negative sequence current to the magnitude of zero sequence current I2 I0 If the measured ratio exceeds k2 the negative sequence voltage polarized directional element is enabled If the measured ratio is less than k2 the zero sequence voltage polarized directional element is enabled Typically you c...

Page 197: ...depending on the setting ORDER If ORDER does not contain Q the relay hides the Z2F Z2R a2 and k2 settings If ORDER does not contain V the relay hides the Z0F and Z0R settings If ORDER contains only Q the relay hides settings a0 E32IV Z0F and Z0R E32IV SELOGIC control equation setting E32IV must be asserted to enable the zero sequence voltage polarized or zero sequence current polarized directional...

Page 198: ...PO ILOP Setting Enable Q listed in setting ORDER Relay Word Bits 50FP Setting 3I2L 50QR 50RP Setting 32QE Internal Enable 32QGE Internal Enable a2 I1L Setting Setting I2L k2 I0L I2L 50GF Relay Word Bits SPO Setting Enable SELOGIC Enable I listed in setting ORDER Setting Enable V listed in setting ORDER Relay Word Bit 50FP Setting IGL 50GR 50RP Setting E32IV Setting 32VE Internal Enables Internal E...

Page 199: ...evel detector 50GR Reverse zero sequence supervisory current level detector 32VE 32V internal enable HSDGF Ground fault high speed forward directional element HSDGR Ground fault high speed reverse directional element 32IE 32I internal enable 32GF Forward ground directional declaration 32GR Reverse ground directional declaration F32I Forward current polarized zero sequence directional element R32I ...

Page 200: ...d directional element enabled ORDER 1 2 3 position 3 internal enable asserted Best Choice Ground Directional enable output Enable ground directional element that corresponds to position 1 internal enable ORDER 1 1 2 or 1 2 3 where any combination of Q V and I are set in positions 1 2 or 3 for ground directional element priority Q 32QGE V 32VE I 32IE 32QGE 32VE 32IE Best Choice Ground Directional e...

Page 201: ...l Element Logic SPO F32QG Forward R32QG Reverse Relay Word Bit 32QGE Relay Word Bit Relay Word Bit Relay Word Bits 50QR Best Choice Ground Directional Logic enable output ILOP Enable 50QF V2 I2L Z2FTH Calculation Z2RTH Calculation z2 Calculation Relay Word Bit 1 2 SPO Relay Word Bits F32V Forward R32V Reverse Relay Word Bit Relay Word Bit 32VE Relay Word Bit 50GR Relay Word Bit ILOP 50GF 3V0 IGL Z...

Page 202: ...on 1 2 Figure 5 26 Ground Directional Element Output Logic Diagram Table 5 37 Reference Table for Figure 5 23 Figure 5 24 and Figure 5 25 Sheet 1 of 2 Name Description z2 Negative sequence voltage polarized directional element impedance calculation Z2FTH Negative sequence voltage polarized directional element forward threshold calculation Z2RTH Negative sequence voltage polarized directional eleme...

Page 203: ...polarized directional element calculation 32IFTH Zero sequence current polarized directional element forward threshold calculation 32IRTH Zero sequence current polarized directional element reverse threshold calculation Table 5 37 Reference Table for Figure 5 23 Figure 5 24 and Figure 5 25 Sheet 2 of 2 Name Description Table 5 38 Vector Definitions for Equation 1 1 Through Equation 1 11 Vector Ana...

Page 204: ...al Calculation Equation 5 20 Forward Threshold If Z0F is less than or equal to 0 Equation 5 21 If Z0F is greater than 0 Equation 5 22 Reverse Threshold If Z0R is greater than or equal to 0 Equation 5 23 If Z0R is less than 0 Equation 5 24 Z2RTH 0 75 Z2R 0 25 V2 I2 Z2RTH 1 25 Z2R 0 25 V2 I2 z0 Re 3V0 IG 1 Z0ANG IG 2 Z0FTH 0 75 Z0F 0 25 3V0 IG Z0FTH 1 25 Z0F 0 25 3V0 IG Z0RTH 0 75 Z0R 0 25 3V0 IG Z0...

Page 205: ...ol to Y the settings you enter for 50FP 50RP Z2F Z2R and a2 affect the 32Q element see Ground Directional Element on page 5 33 for more details where IP Polarizing Current 32I Re IG IP 32IFTH 0 01 InX nominal rating nominal current rating 32IRTH 0 01 InX nominal rating nominal current rating Table 5 39 Phase and Negative Sequence Directional Elements Relay Word Bits Name Description F32P Forward p...

Page 206: ...verse R32Q Relay Word Bit Relay Word Bit Relay Word Bits Relay Word Bit Relay Word Bit Setting The stability counter can add as much as a 0 5 cycle delay This prevents the logic from toggling between forward and reverse declarations and gives other protection elements that rely on the directional decision time to operate Figure 5 28 32Q Negative Sequence Directional Element Logic Diagram Relay Wor...

Page 207: ...ach during external faults If CVT tran sient blocking is enabled and the relay detects a high SIR source to impedance ratio when a Zone 1 distance element is picked up the relay delays tripping for as long as 1 5 cycles to allow the CVT transients to stabilize You do not need to enter settings The relay adapts automatically to different sys tem SIR conditions by monitoring the measured voltage and...

Page 208: ...sformers Capacitors can be on either end of a line in the middle of a line or at both ends of a line Capacitors that are external to a protected line section can have an effect if infeed conditions are present In applications where there is a series capacitor on an adjacent line for any SEL 421 Relays on non compensated lines set ESERCMP Y and XC OFF This allows the Zone 1 element to be set to the...

Page 209: ...ence threshold 10 percent of the nominal relay current Relay Word bit ZLOUT indicates that load is flowing out with respect to the relay an export condition Relay Word bit ZLIN indicates that load is flowing in with respect to the relay an import condi tion Figure 5 31 illustrates load encroachment settings and corresponding char acteristics in the positive sequence impedance plane Either Relay Wo...

Page 210: ... all power swings that enter the OOS characteristics even if a single pole open condition exists Relay Word bit SPO equals logical 1 If either negative sequence directional element 67QUBF or 67QUBR 67Q1T for Zone 1 picks up during a power swing and a single pole open condition does not exist Relay Word bit SPO equals logical 0 the logic overrides OOS blocking Figure 5 31 Load Encroachment Characte...

Page 211: ...tect a power swing when a single pole open condition exists for such a case the logic can block both phase and ground distance pro tection Refer to Section 6 Protection Applications Examples for detailed descriptions of the various functions utilized by the OOS logic The following rules apply when you set the OOS logic You can enable the OOS logic when setting Z1ANG is greater than 45 degrees Sett...

Page 212: ... after it asserts for more than 2 seconds You can latch OSB if the power swing moves outside of Zone 6 before the two second timer expires Y N N EOOST Out of Step Trip Delayc c Option I enables tripping on the way into Zone 6 option O enables tripping on the way out of Zone 6 option N disabled OST Out of Step Trip N I O C N OSTDa Out of Step Trip Delay cycles 0 500 8000 0 500 X1T7a Zone 7 Reactanc...

Page 213: ...OSTO Outgoing out of step tripping OST Out of step tripping 67QUBF Negative sequence forward directional element 67QUBR Negative sequence reverse directional element OOSDET OOS condition detected OSB1 Block Zone 1 during out of step condition OSB2 Block Zone 2 during out of step condition OSB3 Block Zone 3 during out of step condition OSB4 Block Zone 4 during out of step condition OSB5 Block Zone ...

Page 214: ...ve Sequence Measurements Figure 5 34 OOS Override Logic UBOSBD D 0 Internal Function UBOSB 3φ Unblock X1 X1 X1 R1 R1 R1 Zone 6 Zone 7 1 1 Relay Word Bits 50ABC 50ABCP 3PO ILOP X7ABC X6ABC V1 I1L I1L Relay Word Bits Setting UBD 0 CYC 67QUBF Relay Word Bits UBD 0 CYC 67QUBR Relay Word Bit Relay Word Bit 32QF Setting 3I2L 50QUBP 32QR ...

Page 215: ...agram S R Q OSBD Reset 0 OSTD 0 0 1 8 CYC 2 SEC 0 UBOSB X7ABC EOOST N EOOST I X6ABC Settings Settings OSBLTCH Y Setting Relay Word Bits Relay Word Bits Relay Word Bit Relay Word Bit EOOST 0 OOSB1 Y OOSB2 Y OOSB3 Y OOSB4 Y OOSB5 Y Setting OSB OSTI OST OST0 OSB1 OOSDET OSB2 OSB3 OSB4 OSB5 Reset Takes Priority OOS Detected After 0 1 SEC ...

Page 216: ...zero setting out of step blocking function is based on the five functional blocks shown in Figure 5 37 These blocks are the swing center voltage slope detector the swing signature detector the reset conditions the dependable out of step blocking detector and the three phase fault detector Notice that when either SD swing center voltage slope detector or SSD swing signature detec tor asserts the La...

Page 217: ...he positive sequence swing center voltage d2SCV1_UF ultra fast second derivative not filtered of the positive sequence swing center voltage Swing Center Voltage Slope Detector In Figure 5 38 the top four comparators determine whether the swing is fast dSCV1_F remains asserted for 1 75 cycles or slow dSCV1_S remains asserted for 5 cycles for both negative and positive slopes if the supervision cond...

Page 218: ...positive sequence impedance is in the Starter Zone Z1ZNS When AND Gate AND 5 asserts SD asserts When SD asserts the Latch in Figure 5 37 asserts causing OSB_I and OSB to assert Figure 5 38 includes two checks for Z1 the positive sequence impedance whether Z1 is in the Starter Zone see Figure 5 39 and whether Z1 is in Zone 7 see Figure 5 32 Figure 5 38 Swing Center Voltage Slope Detection Logic AND...

Page 219: ...rithm automatically calculates the Starter Zone from the Z2MP Z5MP XP2 XP5 and RP2 RP5 Group settings using the following equations R_SZ max 2 Z2P OOSB2 1 5 Z3P OOSB3 1 5 Z4P OOSB4 1 5 Z5P OOSB5 X_SZ max 3 Z2P OOSB2 2 Z3P OOSB3 2 Z4P OOSB4 2 Z5P OOSB5 The slope detector typically detects the majority of power swing conditions However there are some system conditions for which the slope detector ma...

Page 220: ...settings Phase distance elements included in the power swing blocking function are further supervised by the OSB unbalance reset conditions 67QUBF see Figure 5 52 and open pole conditions Similarly ground distance elements included in the power swing blocking func tion are further supervised by open pole conditions If any of these distance elements asserts no supervisory conditions then the top in...

Page 221: ...nce impedance Z1 will be outside the starter zone for more than 0 5 s or the OST function will be enabled and Z1 will stay outside Zone 7 for more than 30 cycles 2 The slow derivative dSCV1_S will be smaller than 0 0026 pu V cyc for more than 10 cycles under a no fault condition Figure 5 41 Swing Signature Detector Logic AND 2 AND 4 OSBA OSBB OSBC Z2G OOSB2 Y Z3G OOSB3 Y Z4G OOSB4 Y Z5G OOSB5 Y Z2...

Page 222: ...3 if a close reverse or forward fault clears with a signifi cant delay there is a possibility that the network has entered a power swing In this case the Z1 trajectory at the relay may cross into the Zone 2 or Zone 1 phase mho characteristic right after the fault clears but before the slope detector has detected the power swing In this case the phase mho elements of the relay may issue a trip sign...

Page 223: ... signal if a power swing has not been detected the signal from a fault detector has lasted several cycles and been cleared the relay has issued no trip signal and a Zone 2 mho phase has picked up within a time delay Depending on the EOOS setting the relay selects either the logic shown in Figure 5 44 EOOS Y1 or the logic shown in Figure 5 45 EOOS Y Figure 5 44 shows the dependable power swing bloc...

Page 224: ...etector Logic EOOS Y1 DIR5 F DIR4 F Z5P Z4P Z3P Z2P OSB OSB1 TRIP SERCAB SERCBC MAB1I XAB1I MBC1I XBC1I SERCCA MCA1I XCA1I MAB2I XAB2I MBC2I XBC2I MCA2I XCA2I Z1MAG FZAVG Z1Fk Z1Fk 1 8 NFREQ d2SCV1_UF 2 d2SCV1_UF_avg 0 06 DIR3 F 0 0 25 CYC 0 0 25 CYC 0 0 25 CYC 0 25 CYC 0 0 0 25 CYC 0 2 5 CYC 0 0 125 CYC 1 5 CYC 0 0 2 5 CYC DOSBY1 0 1 5 CYC 0 60 CYC 1 ...

Page 225: ...the sec ond derivative of SCV1 has a higher than usual value Furthermore the SCV1 has a low value and its rate of change is very small These properties are taken into account in the three phase fault detector so as to implement a very fast detector independent from the swing speed Three phase faults will be detected with a minimum and maximum time delay of two and five cycles respectively Figure 5...

Page 226: ...nce current and the nega tive sequence currents If the angular relationship indicates a fault the logic shown in Figure 5 41 turns off AND 4 thus preventing the swing signature detec tion SSD from asserting When SSD is deasserted the distance elements can clear the fault For example if the A Phase is open the angle of the ratio normally lies between 60 and 60 degrees If a fault now occurs on B or ...

Page 227: ...pole open condition SPO Table 5 48 shows the input output combinations of the logic Phase Mho Element Reset Logic If the OSB function is enabled and a power swing occurs the OSB signal blocks the phase fault detectors but not the ground fault detectors Therefore to remove the OSB signal and clear a fault that occurs during an OOS condition the relay must detect three phase and phase to phase fault...

Page 228: ...he Zone 6 and Zone 7 blinder settings and are common for the conven tional and the zero setting OST function see Figure 5 32 Figure 5 53 shows the resistive and reactive blinders used in the OST scheme logic The OST logic uses the traditional OOS calculations for the left R1R6 right R1R7 top X1T6 and bottom X1T7 blinders of Zone 6 and Zone 7 Specify Settings X1B6 and X1B7 under the advanced settin...

Page 229: ...es whether the positive sequence impedance Z1 falls within the Zone 6 and or Zone 7 polygons provided there is no three pole open 3PO or loss of potential ILOP conditions Figure 5 53 OST Scheme Logic Resistive and Reactive Blinders R jX XT 7 XT 6 XB 6 XB 7 RR 7 RR 6 RL 6 RL 7 R 1 R 6 X1 T7 X1 T6 X1 B6 X1 B7 Line Operate Restrain R 1 R 7 R 1 L7 R 1 L6 ...

Page 230: ... Functions Out of Step Logic Zero Settings Figure 5 54 Logic That Determines Positive Sequence Impedance Trajectory EOOS Y1 IA1LFM 50ABC X1T7_C X1B7_C R1R7_C R1L7_C X1T6_C X1B6_C R1R6_C R1L6_C R1RB_C R1LB_C Re Z1 Im Z1 3PO ILOP 50ABCP setting X7ABC X6ABC UBOSB UBOSBD 0 ...

Page 231: ... turns off all three outputs OSTI OST and OSTO are also turned off Figure 5 55 Out of Step Trip Logic EOOS Y1 EOOST I EOOST N OSB_I EOOST O or C EOOST 0 On the Way Out EOOST C On the Way Out with counts EOOST O EOOST C R7T X7T X6T RR6 RL6 R6T RR7 RL7 OST OSTI OSTO AND 1 OSTFF1 X 7 T X 6 T R R 6 R L 6 R 6 T R R 7 R L 7 R 7 T FF1 S R Q OSTFF3 FF3 S R Q Pole Slip Counter Ck Reset OSTFF2 FF2 S R Q OST...

Page 232: ...faults The first three zones of mho ground distance protection Zone 1 through Zone 3 are for high speed operation typical detection time is less than one cycle NOTE If the relay is using a remote data acquisition system such as TiDL the operating times will be delayed by 1 5 ms Use caution when setting the relay coordination times to account for this added delay The Zone 1 zero sequence compensati...

Page 233: ...one 2 A Phase mho ground distance element MBG2 Zone 2 B Phase mho ground distance element MCG2 Zone 2 C Phase mho ground distance element MAG3 Zone 3 A Phase mho ground distance element MBG3 Zone 3 B Phase mho ground distance element MCG3 Zone 3 C Phase mho ground distance element MAG4 Zone 4 A Phase mho ground distance element MBG4 Zone 4 B Phase mho ground distance element MCG4 Zone 4 C Phase mh...

Page 234: ...tance Element Logic Diagram y Word Bits Relay Word Bits Relay Word Bit Relay Word Bits 32SPOF CVTBL MAG1 MBG1 Z1G MCG1 XAG1 XBG1 XCG1 32GF IAL IGL mAGF Z1MG FSA SPO SPOA OSB1 OSBA 3PO 67Q1T ILOP VPOLV SERCA 0 1 INOM mAGF A Phase to Ground Mho Distance Calculation A Phase Mho Ground Distance Logic B and C Phase Logic is Similar Z50G1 setting ...

Page 235: ...ment Logic Diagram 32SPOF MAG2 MBG2 Z2G MCG2 XAG2 XBG2 XCG2 32GF FSA SPO SPOA OSB2 OSBA 3PO ILOP VPOLV A Phase Mho Ground Distance Logic B and C Phase Logic is Similar mAGF is the Forward A Phase to Ground Mho Distance Calculation Relay Word Bit Relay Word Bits Relay Word Bits Relay Word Bits Relay Word Bit Relay Word Bits IAL IGL mAGF Z2MG 0 1 INOM ...

Page 236: ...ts either forward or reverse You select whether the quadrilateral ground distance elements use negative or zero sequence current to polarize the reactance line when the Advanced Settings are enabled setting EADVS Y otherwise negative sequence current is the default setting Figure 5 59 Zones 3 4 and 5 Mho Ground Distance Element Logic Diagram 32SPOF DIRn F MAGn MBGn ZnG MCGn XAGn XBGn XCGn 32GF OSB...

Page 237: ...resistive blinder is disabled it uses self polarization Table 5 50 shows the differences between behavior of the adaptive right resis tance blinder and the existing resistance blinder Each quadrilateral ground distance element is supervised by the Relay Word bit ENX2nG where n is the A B or C phase This supervisory condition secures the reactance blinder in the quadrilateral ground distance elemen...

Page 238: ...ilateral ground distance element XCG5 Zone 5 C Phase quadrilateral ground distance element Table 5 51 Quadrilateral Ground Distance Elements Relay Word Bits Sheet 2 of 2 Name Description Figure 5 60 Zone 1 Quadrilateral Ground Distance Element Logic Diagram CVTBL XAG1 IAL IGL 0 1 INOM RG1 rAG1 RG1 xAG1 XG1 FSA SPO 3PO 0SB1 67Q1T ILOP VPOLV SERCA B and C Phase Logic is Similar xAG1 is the A Phase t...

Page 239: ... Element Logic Diagram Relay Word Bits Relay Word Bits Relay Word Bit Setting Setting XAG2 XGPOL IG 32VE 32QE 32GF XGPOL I2 IAL IGL xAGF XG2 RG2 rAGF RG2 0 1 INOM FSA SPO B and C Phase Logic is Similar xAGF is the A Phase to Ground Forward Reactance Calculation rAGF is the A Phase to Ground Forward Resistance Calculation 3IA2LF 3PO ILOP VPOLV ARESE N ENX2AG ...

Page 240: ...21 has five independent zones of quadrilateral phase distance protec tion see Quadrilateral Phase Distance Elements on page 5 85 Although the mho and quadrilateral phase elements are independent you can enable both at the same time To this end the outputs from the mho and quadrilateral phase ele ments are ORed to a single protection output see Figure 5 61 Figure 5 64 and Figure 5 65 The SEL 421 ha...

Page 241: ... faults The first three zones of mho phase distance protection Zone 1 Zone 2 and Zone 3 are for high speed operation typical detection time is less than one cycle Table 5 52 Mho Phase Distance Elements Relay Word Bits Relay Word Bit Description MAB1 Zone 1 mho A B phase element MBC1 Zone 1 mho B C phase element MCA1 Zone 1 mho C A phase element Z1P Zone 1 phase distance element MAB2 Zone 2 mho A B...

Page 242: ...tput Z1P is the OR combination of the following Zone 1 elements ØØ AB BC CA Conventional mho elements MØØ1 Conventional quadrilateral elements XØØ1 Figure 5 63 Zone 1 Mho Phase Distance Element Logic Diagram Relay Word Bits Relay Word Bits Relay Word Bits IABLFM MABDF mABF Z1MP setting F32P 32SPOF SPOA 67Q1T SPOB SPOC VPOLV SERCAB CVTBL ILOP OSBA OSB1 0 1 INOM MAB1 MBC1 XBC1 XCA1 MCA1 XAB1 Z1P FSA...

Page 243: ...64 Output Z2P is the OR combination of the following Zone 2 elements ØØ AB BC CA Conventional mho elements MØØ2 Conventional quadrilateral elements XØØ2 Figure 5 64 Zone 2 Mho Phase Distance Element Logic Diagram Relay Word Bits Relay Word Bits Relay Word Bits IABLFM MABDF mABF Z2MP setting F32P 32SPOF SPOA 67QUBF SPOB FSA FSB SPOC VPOLV ILOP OSBA OSB2 0 1 INOM MAB2 MBC2 XBC2 XCA2 MCA2 XAB2 Relay ...

Page 244: ...llowing Zone n n 3 4 5 elements ØØ AB BC CA Conventional mho elements MØØn Conventional quadrilateral elements XØØn Figure 5 65 Zones 3 4 and 5 Mho Phase Distance Element Logic Diagram Relay Word Bits Relay Word Bits Relay Word Bits Relay Word Bits Setting 32SPOF IABLFM DIRn F F32P SPOA SPOB R32P 32SPOR SPOC VPOLV ILOP OSBA OSBn 67QUBF 67QUBR ZnMP setting ZnMP setting IABL 0 1 INOM 0 1 INOM mABF F...

Page 245: ...ions Table 5 53 summarizes the zone directional settings for the high speed and con ventional elements The impedance reach for each zone of quadrilateral phase distance protection lies on the line positive sequence impedance angle Z1ANG rather than on the ordi nate reactance of the impedance plane When setting the reactance reach of the relay do not convert the line impedance to a reactance Enter ...

Page 246: ...es not affect the resistance values Figure 5 66 shows the quadrilateral phase characteristic with TANGP 0 degrees Figure 5 67 shows the quadrilateral phase distance element characteristic with TANGP 10 degrees Notice that the reactance elements are tilted by 10 degrees but the resistance blinders are unaffected by this setting Also notice that the pivot point of the tilt is the line impedance and ...

Page 247: ...rk in Figure 5 68 to determine whether the negative sequence network is homogeneous ZLEFT is the total impedance up to the fault F on the left hand side while ZRIGHT is the total impedance up to the fault on the right hand side Figure 5 67 Quadrilateral Phase Distance Element Characteristic TANGP 10 degrees Zone 3 TANGP 10 degrees Zone 2 Zone 1 Z1ANG RP1 XP1 XP2 XP3 jX RP RP2 RP3 R Figure 5 68 Net...

Page 248: ...ult con ditions 32QE 1 This supervisory condition secures the reactance element in the quadrilateral phase distance element against unusual unbalanced load condi tions where currents but not voltages are unbalanced A supervisory condition is applied to force the right resistive blinders to be self polarized under the previous unusual unbalanced loads The adaptability of the positive sequence polar...

Page 249: ...drilateral phase distance element for the AB loop Fault calculations for BC and CA faults have similar logics Table 5 54 Quadrilateral Phase Distance Elements Relay Word Bits Relay Word Bit Description XAB1 Zone 1 quad A B phase element XBC1 Zone 1 quad B C phase element XCA1 Zone 1 quad C A phase element XAB2 Zone 2 quad A B phase element XBC2 Zone 2 quad B C phase element XCA2 Zone 2 quad C A ph...

Page 250: ...r logics Figure 5 70 Zone 1 AB Loop Conventional Quadrilateral Phase Distance Element Logic Figure 5 71 Zone 2 AB Loop Conventional Quadrilateral Phase Distance Element Logic IABLFM 0 1 INOM F32P CVTBL XAB1 RABX1 OSB1 67Q1T FSA FSB HSDAGF HSDBGF SERCAB ILOP SPO MABDF xABF XP1 setting Phase Selection VPOLV ENX2AB 32QE Z50P1 setting IABLFM 0 1 INOM F32P XAB2 RABX2 OSB2 67QUBF FSA FSB HSDAGF HSDBGF I...

Page 251: ... 5 ms Use caution when setting the relay coordination times to account for this added delay The SEL 421 supports two philosophies of zone timing Independent timing the phase and ground distance elements drive separate timers for each zone Common timing the phase and ground distance elements both drive a common timer Figure 5 72 Zone 3 4 and 5 AB Loop Conventional Quadrilateral Phase Distance Eleme...

Page 252: ...G OR Z2PT OR Z2GT Common Zone Timing Use Relay Word bits ZnT Zone n Distance Protection to select common zone timing in SELOGIC control equation TR Trip n 1 5 The next example uses common timing for Zone 2 distance protection TR Z1P OR Z1G OR Z2T If the timer input drops out while timing the relay suspends the common zone timer for two cycles This feature prevents resetting the timer when a fault ...

Page 253: ...4 and definite time directional overcurrent elements 67PnT 67QnT 67GnT where n 1 4 See Directionality on page 5 46 for details on the directional control option Note that the 67Pn and 67PnT elements are not directionally controlled by the built in logic they can be made directional through the use of torque con trol settings 67P1TC 67P4TC Figure 5 73 Zone Timers Relay Word Bits Relay Word Bits Rel...

Page 254: ...D Level 1 Time Delay cycles 0 000 16000 0 000 67P2D Level 2 Time Delay cycles 0 000 16000 0 000 67P3D Level 3 Time Delay cycles 0 000 16000 0 000 67P4D Level 4 Time Delay cycles 0 000 16000 0 000 67P1TC Level 1 Torque Control SELOGIC Equation 1 67P2TC Level 2 Torque Control SELOGIC Equation 1 67P3TC Level 3 Torque Control SELOGIC Equation 1 67P4TC Level 4 Torque Control SELOGIC Equation 1 Table 5 ...

Page 255: ... element 50P2 Level 2 instantaneous phase overcurrent element 50P3 Level 3 instantaneous phase overcurrent element 50P4 Level 4 instantaneous phase overcurrent element 67P1 Level 1 definite time phase directional overcurrent element 67P2 Level 2 definite time phase directional overcurrent element 67P3 Level 3 definite time phase directional overcurrent element 67P4 Level 4 definite time phase dire...

Page 256: ... overcurrent element 50G2 Level 2 instantaneous residual ground overcurrent element 50G3 Level 3 instantaneous residual ground overcurrent element 50G4 Level 4 instantaneous residual ground overcurrent element 67G1 Level 1 definite time residual ground directional overcurrent element 67G2 Level 2 definite time residual ground directional overcurrent element 67G3 Level 3 definite time residual grou...

Page 257: ...74 Phase Instantaneous Definite Time Overcurrent Elements 67P1D 67P1 50P1 IAL IBL ICL 67P1TC SELOGIC Setting 50P1P Setting 67P1T 0 67P2D 67P2 50P2 67P2TC SELOGIC Setting 50P2P Setting 67P2T 0 67P3D 67P3 50P3 67P3TC SELOGIC Setting 50P3P Setting 67P3T 67P4T 0 67P4D 67P4 50P4 67P4TC SELOGIC Setting 50P4P Setting 0 Relay Word Bits ...

Page 258: ...0G1 67G1 67G1T IGL 50G1P Setting 67G1TC SELOGIC Setting 32GF Relay Word Bit Relay Word Bits 67G2D 0 50G2 67G2 67G2T 50G2P Setting 67G2TC SELOGIC Setting 32GF Relay Word Bit 67G3D 0 50G3 67G3 67G3T 50G3P Setting DIR3 F Setting 67G3TC SELOGIC Setting 32GF Relay Word Bit 32GR Relay Word Bit 67G4D 0 50G4 67G4 67G4T 50G4P Setting DIR4 F Setting 67G4TC SELOGIC Setting 32GF Relay Word Bit 32GR Relay Word...

Page 259: ...nding upon settings BK1I and BK2I Symmetrical component current quantities are available only for the line current source Table 5 61 defines the available setting choices for operating quantities and the corresponding analog quantity name as found in Section 12 Analog Quantities Figure 5 76 Negative Sequence Instantaneous Directional Overcurrent Elements 67Q1D 0 50Q1 67Q1 67Q1T 3I2L 50Q1P Setting ...

Page 260: ...M B2IGFIM Table 5 62 Selectable Inverse Time Overcurrent Settings Settinga a Parameter n is L for Line 1 for BK1 and 2 for BK2 Prompt Range Default 5 A E51S Selectable Inverse Time Overcurrent Element N 1 3 1 51S1O Operating Quantity Element 1 IAn IBn ICn IMAXn I1L 3I2L 3I0n 3I0L 51S1P 51S1 O C Pickup Element 1 A 0 05 3 2 INOM 0 75 51S1C 51S1 Inverse Time O C Curve Element 1 U1 U5 C1 C5 U3 51S1TD ...

Page 261: ...me Overcurrent Element 1 reset 51S2 Inverse Time Overcurrent Element 2 pickup 51S2T Inverse Time Overcurrent Element 2 timed out 51S2R Inverse Time Overcurrent Element 2 reset 51S3 Inverse Time Overcurrent Element 3 pickup 51S3T Inverse Time Overcurrent Element 3 timed out 51S3R Inverse Time Overcurrent Element 3 reset Tp operating time in seconds Tr electromechanical induction disk emulation rese...

Page 262: ...rve Type Operating Time Reset Time Figure C1 Standard Inverse Figure 5 82 C2 Very Inverse Figure 5 83 C3 Extremely Inverse Figure 5 84 C4 Long Time Inverse Figure 5 85 C5 Short Time Inverse Figure 5 86 Tp TD 0 14 M 0 02 1 Tr TD 13 5 1 M 2 Tp TD 13 5 M 1 Tr TD 47 3 1 M 2 Tp TD 80 M 2 1 Tr TD 80 1 M 2 Tp TD 120 M 1 Tr TD 120 1 M Tp TD 0 05 M 0 04 1 Tr TD 4 85 1 M 2 ...

Page 263: ...50 6 00 5 00 4 00 3 00 2 00 1 00 15 00 12 00 10 00 8 00 01 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 264: ...0 5 00 4 00 3 00 2 00 1 00 15 00 12 00 10 00 8 00 01 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 265: ... 1 00 0 50 10 00 8 00 6 00 5 00 4 00 3 00 2 00 15 00 01 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 266: ... 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 Time in Seconds Multiples of Pickup 3 00 2 00 1 00 0 50 15 00 12 00 10 00 8 00 6 00 5 00 4 00 Time in Cycles 60 Hz 50Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 267: ...50 1 00 2 00 6 00 3 00 4 00 5 00 10 00 8 00 12 00 15 00 01 5 6 7 8 1 9 02 03 04 05 06 07 1 08 09 2 3 4 5 6 1 7 8 9 2 3 4 5 6 7 8 10 9 20 30 50 40 60 100 90 70 80 80 9 2 3 4 5 6 7 8 10 20 30 40 50 60 70 90 100 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 60 50 30 25 150 125 300 250 1500 1250 600 500 3000 2500 6000 5000 ...

Page 268: ...60 0 05 0 50 0 40 0 30 0 20 0 10 1 00 0 90 0 80 0 70 01 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 269: ... 0 20 0 10 0 05 1 00 0 90 0 80 0 70 0 60 0 50 0 40 01 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 270: ...1 5 6 7 8 9 1 02 03 04 05 09 07 06 08 1 2 3 4 5 7 6 9 8 1 4 2 3 5 6 7 8 9 10 40 20 30 70 50 60 80 90 100 80 10 2 3 6 4 5 7 9 8 20 50 30 40 60 70 100 90 0 20 0 10 0 05 1 00 0 90 0 80 0 70 0 60 0 50 0 40 0 30 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 3 2 5 6 5 15 12 5 30 25 60 50 600 500 150 125 300 250 1500 1250 3000 2500 6000 5000 ...

Page 271: ...1 00 0 90 0 80 0 70 0 60 0 50 0 40 0 30 7 6 5 1 9 8 1 4 2 3 5 6 8 7 9 1 2 3 4 5 7 6 4 2 3 7 6 5 10 9 8 40 20 30 70 50 60 80 90 100 50 9 8 10 20 30 40 300 200 100 80 60 70 90 1000 900 800 700 600 500 400 Time in Seconds Multiples of Pickup Time in Cycles 60 Hz 50 Hz 30 25 60 50 150 125 300 250 3000 2500 600 500 1500 1250 6000 5000 15000 12500 30000 25000 60000 50000 ...

Page 272: ...0 20 30 40 50 60 70 80 90 100 1 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 01 02 03 04 05 06 07 08 09 100 1 2 3 4 5 6 7 8 9 5 6 7 8 9 90 80 70 60 50 40 30 20 10 Time in Seconds Time in Cycles 60 Hz 50 Hz 6000 5000 3000 2500 1500 1250 600 500 300 250 150 125 60 50 30 25 15 12 5 6 5 3 2 5 Multiples of Pickup 0 05 0 10 0 20 0 30 0 40 0 50 0 60 0 70 0 80 0 90 1 00 ...

Page 273: ...ix overvoltage elements Each of these 12 elements has two levels for a total of 24 over and undervoltage ele ments Figure 5 88 shows the undervoltage element logic and Figure 5 89 shows the undervoltage element logic The relay supports two voltage terminals Y and Z Select any one of the voltage quantities from Table 5 66 as an input quantity 27On and 59On settings You can select the same quantity ...

Page 274: ...s Voltage Quantity Description VAFIM Filtered instantaneous A Phase voltage magnitude VBFIM Filtered instantaneous B Phase voltage magnitude VCFIM Filtered instantaneous C Phase voltage magnitude V1FIM Filtered instantaneous positive sequence voltage magnitude VNMAXF Maximum phase to neutral voltage magnitude VNMINF Minimum phase to neutral voltage magnitude VPMAXF Maximum phase to phase voltage m...

Page 275: ...s to assert 27TCn Undervoltage Torque Control Use the torque control setting to specify conditions under which the undervoltage elements must be active There is only one setting for both Level 1 and Level 2 elements With the default setting equal to 1 both levels are active permanently Setting Prompt Range Default Category E27 Enable Undervoltage Elements N 1 6 N Group Setting Prompt Range Default...

Page 276: ...ts to assert 59PnP2 Overvoltage Level 2 Pickup Set pickup values for the voltage value above which you want the Level 2 over voltage elements to assert 59TCn Overvoltage Torque Control Use the torque control setting to specify conditions under which the overvoltage elements must be active There is only one setting for both Level 1 and Level 2 elements With the default setting equal to 1 both level...

Page 277: ...ingle Pole Open Delay is other than OFF Select either or both methods for the validating procedure The relay initiates SOTF protection at these corresponding instances Circuit breaker opening 52AEND timer timeout Circuit breaker closing CLOEND time timeout and SELOGIC control equation CLSMON assertion Circuit Breaker Opened SOTF Logic Set ESOTF to Y and set 52AEND to other than OFF to enable the c...

Page 278: ...SOTFD or until the logic detects a healthy voltage condi tion if EVRST Y see SOTF Options on page 5 118 SOTF Options Set EVRST Y to enable the Voltage Reset logic If the system voltage is bal anced ratio of negative sequence voltage to positive sequence voltage is below 0 1 Relay Word bit SOTFE resets when the relay measures positive sequence voltage at greater than VRSTPU times nominal voltage If...

Page 279: ...tch Onto Fault Logic Figure 5 90 SOTF Logic Diagram 52AEND ESPSTF Y 0 CLOEND 0 5 CYC 0 0 SOTFD SOTFE Reset 0 SOTFD SPO 3PO Relay Word Bit 52AEND OFF Settings CLOEND OFF CLSMON EVRST Y VA1FM VRSTPU VNOM 0 1 SPOA SPOB SPOC Setting 3VA2FM 3 VA1FM Setting SEL OGIC Setting Relay Word Bits ...

Page 280: ...ectional Comparison Unblocking DCB Directional Comparison Blocking All of these schemes work in both two terminal and three terminal line applica tions For the DCUB scheme you have separate settings choices for these appli cations ECOMM equals DCUB1 or DCUB2 because of unique DCUB logic considerations You must set Zone 3 reverse looking DIR3 equals R for all three schemes Table 5 69 ECOMM Setting ...

Page 281: ...hase and ground distance protection Z2PGS plus delayed Level 2 negative sequence residual ground directional overcurrent element 67QGS2 in the TRCOMM SELOGIC control equation See 345 kV Tapped Overhead Transmission Line Example on page 6 53 Momentarily delaying the forward looking Zone 2 and Level 2 elements that pro vide high speed tripping at the local terminal ensures that the local circuit bre...

Page 282: ...o not need a reverse off set Should the polarizing voltage for the distance elements collapse to zero the corresponding Zone 3 supervisory phase to phase current level detectors will cause the Zone 3 phase distance elements to latch Use timer Z3XD Zone 3 Reverse Time Delay on Dropout to extend the block ing signal during current reversals Use timer Z3XPU Zone 3 Reverse Time Delay on Pickup to prev...

Page 283: ...rity over the nondirectional starting ele ments however directional starting elements must have priority over the stop ping elements Figure 5 92 shows that the directional starting elements have internal priority over the stopping elements Use SELOGIC control equations to make sure that the stopping elements have priority over the nondirectional start ing elements OUT101 NSTRT AND NOT STOP OR DSTR...

Page 284: ...can also implement a POTT scheme with other conventional communications channels such as leased telephone lines and microwave The DCUB trip scheme is a better choice if the communications channel is less than perfect but communications channel failures are unlikely to occur during external faults POTT Scheme Selection The SEL 421 offers three POTT schemes POTT POTT2 and POTT3 The type of communica...

Page 285: ...ach channel indicates permissive trip for single phase Multiphase fault detection results in all three channels transmitting a per missive trip For details about implementing a POTT3 scheme see Three Channel POTT Scheme POTT3 on page 6 46 POTT Scheme Logic The POTT scheme logic performs the following tasks Keys the communications equipment to send permissive trip PT when any element you include in...

Page 286: ... receiving end have sufficient time to operate and block the received echo signal for external faults behind the remote terminal This delay also guards the echo and weak infeed logic against noise bursts that can occur on the communications channel during close in external faults Typically these noise bursts coincide with faults external to the line section Because of the brief duration of noise b...

Page 287: ... feature of the relay When the EWFC setting is Y the ECTT logic is enabled When the setting EWFC is SP the relay can convert echo to a single pole trip at the local terminal ECTT logic is disabled when the setting is N Three Terminal Lines If you apply the POTT scheme to a three terminal line program SELOGIC control equation PT1 as follows PT1 IN105 AND IN106 General Permissive Trip Received SELOG...

Page 288: ... POTT Settings Sheet 2 of 2 Setting Prompt Range Default 5 A Table 5 73 POTT Relay Word Bits Sheet 1 of 2 Name Description PT Permission to trip received ECOMM POTT or POTT2 PTA A Phase permissive trip received ECOMM POTT3 PTB B Phase permissive trip received ECOMM POTT3 PTC C Phase permissive trip received ECOMM POTT3 EPTDIR Directional element permissive trip enabled ECOMM POTT PTDIR Directional...

Page 289: ...ansmit permission to single pole trip KEY3 Transmit permission to three pole trip Figure 5 93 Permissive Trip Receiver Logic Diagram Table 5 73 POTT Relay Word Bits Sheet 2 of 2 Name Description PT To POTT Logic Relay Word Bit PTDRX Relay Word Bit PTDIR Relay Word Bit ECOMM POTT Setting ECOMM DCUB1 ECOMM DCUB2 PT1 PT2 ECOMM POTT2 Setting EPTDIR Y Setting Setting Setting Control Input Assignments ...

Page 290: ...Reset 0 1 8 CYC 1 8 CYC ETDPU EDURD 1 CYCLE 0 0 Z3RB KEY KEYD EKEY ECTT WFC Relay Word Bits ILOP Z3P Z3G 67G3 67Q3 3PO ELOP Y1 TRCOMMD COMZDTC TRCOMM Relay Word Bits PT EPO 52 3PT VAB VBC VCA 27PPW 80 3 VO 59NW 5 Relay Word Bit Relay Word Bits Relay Word Bits SEL OGIC Setting Setting Setting EBLKD OFF ETDPU OFF Settings Setting Settings EWFC Y SP VA 27AWI 27BWI VB 27CWI VC 27PWI 47 Setting ...

Page 291: ...l SEL 421 Relay Protection Functions Permissive Overreaching Transfer Tripping Scheme Figure 5 95 POTT Cross Country Logic Diagram 0 2 CYC 0 EDURD ETDPU 0 KEY3 KEY1 Reset 3PT Z2P Z3RB Z2G APS BPS CPS PT3 PT1 SPO Relay Word Bits Relay Word Bits ...

Page 292: ...me Logic ECOMM POTT3 With Echo and Weak Infeed ILOP ELOP Y1 SPOA MAG3 XAG2 EBLKD OFF ETDPU OFF PTA TPA KEYA Z3RBA EKEYA ECTTA WFC Vab Vbc Vca 27PPW 59NW 3V0 EWFC Y SP Note PTB KEYB for B Phase PTC KEYC for C phase MAG2 Z2P APS Z2G Z3G 67G3 67Q3 XAG3 Z3P 67QGSP Y Multi Phase Fault 3PO 67G3 67Q3 ETDPU 0 0 EBLKD 0 EDURD 0 2 CYC 0 5 CYC Z3RBD 0 75 CYC 0 ...

Page 293: ...me The following is an explanation of the differences between setting choices DCUB1 and DCUB2 DCUB1 directional comparison unblocking scheme for two terminal lines i e communication from one remote terminal DCUB2 directional comparison unblocking scheme for three terminal lines i e communication from two remote terminals The DCUB logic takes the loss of guard and permissive trip outputs from the c...

Page 294: ...sent Delay This timer determines the minimum time before the relay reinstates permissive tripping following a loss of channel condition Channel 1 and Channel 2 logic use separate timers but have this same delay setting Table 5 74 DCUB Settings Setting Prompt Range Default 5 A Z3RBD Zone 3 Reverse Block Time Delay cycles 0 000 16000 5 000 EBLKD Echo Block Time Delay cycles 0 000 16000 10 000 ETDPU ...

Page 295: ...nel 1 and Channel 2 logic use separate timers but have this same delay setting Table 5 75 DCUB Relay Word Bits Name Description UBB1 Block permissive trip on Receiver 1 PTRX1 Permissive trip received on Channel 1 UBB2 Block permissive trip on Receiver 2 PTXR2 Permissive trip received on Channel 2 UBB Block permissive trip received on Channel 1 or Channel 2 PTRX Permissive trip received on Channel ...

Page 296: ...D 0 GARD1D UBEND 0 0 Relay Word UBB2 LOG2 PT2 Loss of Guard Input Permissive Trip Input Loss of Guard Input Permissive Trip Input PT1 GARD1D 0 0 UBDURD 0 UBEND Z3RB Settings Logic Enabled if Setting Logic Enabled ECOMM DCUB1 if Setting or ECOMM DCUB2 PTRX2 UBB1 PTRX1 Loss of Channel Loss of Channel Relay Word Bit SEL OGIC Bits ECOMM DCUB2 LOG1 Settings SEL OGIC ...

Page 297: ...gic and Reclose Sources for Single Pole Breaker Applications on page 6 25 in the SEL 400 Series Relays Instruction Manual Single Pole Tripping The relay uses single pole tripping logic if Relay Word bit E3PT three pole trip enable SELOGIC control equation equals logical 0 You can either set E3PT to 0 or assign a control input so that an external condition changes the state of this Relay Word bit T...

Page 298: ...tion DTA DTB and DTC The DTA DTB and DTC SELOGIC control equations determine which elements directly trip the remote terminal Each equation is phase selective If you are applying three pole tripping only set DTA DTB and DTC to the same Relay Word bit expression TRSOTF The TRSOTF control equation defines which elements trip while SOTF protec tion is active These elements trip instantaneously if the...

Page 299: ... trip TDUR3D replaces TDUR1D Trip During Open Pole Time Delay If another fault occurs it is common to trip the two remaining phases for the fol lowing two periods During the single pole open interval following the original single pole trip During the reclosing relay reclaim reset time state following a single pole reclose To use the reclosing relay in the SEL 421 to reclose the breaker s see Inter...

Page 300: ... the individual poles of the circuit breakers for single pole tripping schemes Use Relay Word bit 3PT Three Pole Trip to trip all three poles of both circuit breakers Manual Trip Logic The SEL 421 also has additional logic for manually tripping the circuit breakers Use SELOGIC control equations BK1MTR and BK2MTR to trip the circuit breakers manually Use SELOGIC control equations ULMTR1 and ULMTR2 ...

Page 301: ...ion Time Delay cycles 2 000 8000 6 000 TDUR3D Three Pole Trip Minimum Trip Duration Time Delay cycles 2 000 8000 12 000 E3PT Three Pole Trip Enable SELOGIC Equation 1 E3PT1 Breaker 1 Three Pole Trip SELOGIC Equation 1 E3PT2 Breaker 2 Three Pole Trip SELOGIC Equation 1 ER Event Report Trigger Equation SELOGIC Equation R_TRIG Z2P OR R_TRIG Z2G OR R_TRIG 51S1 OR R_TRIG Z3P OR R_TRIG Z3G a Make settin...

Page 302: ...SPOC DTB DTC DTR TR TRSOTF SOTFE FSA mAG1F mBCF 67Q2 67G2 TRCOMM Z3RB SPO PTDRX TRCOMMD ECTT ECTTA ECTTB ECTTC EWFC Y SP Z2P ECOMM POTT3 ECOMM POTT2 PT3 E3PT 3PT 3φ φa φb φc Z1G SOTFT 3 Phases Selected RX Trip Permission Comm Assisted Trip Permission Z2GT Z2GTSP Y 67QGSP Y ECOMM POTT3 XAG2 XAG2 Z2P PTA ECOMM POTT3 ECOMM POTT3 ECTTA ECTT Z3RBA XAG1 MAG1 MAG2 MAG2 APS ECOMM POTT3 APS COMPRM TRPRM RX...

Page 303: ...nstruction Manual SEL 421 Relay Protection Functions Trip Logic Figure 5 99 Trip Logic Diagram Continued 0 TDURD RESET RESET RESET SPT 3PT TPA TPB TPC ULTRA ATPA TRPRM A3PT ATPB ATPC TRIP ULTRB ULTRC ULTR RSTTRGT 0 TDURD 0 TDURD ...

Page 304: ...eed B Phase undervoltage 27CWI Weak infeed C Phase undervoltage ULTRA Unlatch A Phase trip ULTRB Unlatch B Phase trip ULTRC Unlatch C Phase trip ULTR Unlatch all protection trips ATPA Assert A Phase trip ATPB Assert B Phase trip ATPC Assert C Phase trip A3PT Assert three pole trip TPA Trip A Phase TPB Trip B Phase TPC Trip C Phase TRIP Trip A Phase or B Phase or C Phase 3PT Three pole trip SPT Sin...

Page 305: ... Functions Trip Logic Figure 5 100 Two Circuit Breakers Trip Logic Diagram 0 TDUR3D 0 TDUR3D BK1MTR ULMTR1 TPA TPB TPC E3PT1 E3PT2 BK2MTR ULMTR2 TPA2 TPB2 TPC2 TPA1 TPB1 TPC1 SELOGIC Setting SELOGIC Settings Relay Word Bits Relay Word Bits Relay Word Bits Relay Word Bit ...

Page 306: ...ole initiations are available for circuit breaker failure including extended breaker failure initiation The circuit breaker failure logic also includes breaker failure trip latching logic The failure to interrupt fault current logic includes two schemes both are suit able for three pole or single pole tripping applications Scheme 1 is basic circuit breaker failure that is useful for most applicati...

Page 307: ...ior to the assertion of Relay Word bit BFI3P1 Breaker 1 Three Pole Circuit Breaker Failure Initiation At circuit breaker failure initiation timer BFPU1 Breaker 1 Circuit Breaker Failure Time Delay on Pickup Timer starts timing If 50FA1 remains asserted when the BFPU1 timer expires Relay Word bit FBF1 asserts Use this Relay Word bit in the circuit breaker failure tripping logic to cause a cir cuit ...

Page 308: ... 5 105 applies to three pole tripping for one or two circuit breakers EBFL 2 Use this logic when the protected circuit breaker fails following a three pole trip from the line relaying scheme Fault current causes 50FA1 Breaker 1 A Phase Instantaneous Overcurrent Ele ment to assert immediately following fault inception and just prior to the asser tion of Relay Word bit BFIA1 Breaker 1 A Phase Circui...

Page 309: ...ailure Initiation At circuit breaker failure initiation timer BFPU1 Breaker 1 Circuit Breaker Failure Time Delay on Pickup Timer starts timing Timer BFPU1 cas cades into timer SPBFPU1 Breaker 1 Single Pole Trip Breaker Failure Time Delay on Pickup Timer Therefore use this second timer SPBFPU1 to coordi nate circuit breaker failure operations for single pole and three pole trips If 50FA1 remains as...

Page 310: ... three pole retrip following the unsuccessful single pole trip Attempt all local retrips before the correspond ing circuit breaker failure time delay BFPUn and SPBFPUn on pickup timer expires Retrip Scheme 2 Three Pole Setting EBFL 2 Figure 5 109 illustrates the current supervised three pole retrip logic EBFL 2 Timer RT3PPU1 Breaker 1 Three Pole Retrip Time Delay on Pickup Timer begins timing when...

Page 311: ...hase Retrip asserts immediately after timer RTPU1 expires You can use just the RTA1 output for single pole retrip without current supervision Relay Word bit RTSA1 Breaker 1 Current Supervised A Phase Retrip asserts if 50FA1 is picked up Figure 5 109 Scheme 2 Current Supervised Three Pole Retrip Logic 50FA1 50FB1 50FC1 BFIA1 RTS3P1 RT1 RT3P1 Relay Word Bit BFIB1 BFIC1 RTSA1 RTSB1 RTSC1 Relay Word B...

Page 312: ...han BFIDO1 and the circuit breaker failure initiate is greater than the dif ference of the two timers the relay seals in the circuit breaker failure extended initiation after the initiate signal deasserts until the BFIDO1 time expires and all 50F n elements deassert No Current Residual Current Circuit Breaker Failure Protection Logic The SEL 421 has separate circuit breaker failure logic that oper...

Page 313: ...failure protection Figure 5 115 shows that the output of the load current protec tion is Relay Word bit LCBF1 Load Current Breaker Failure Use this output to activate an external alarm retrip the circuit breaker or energize a lockout relay Load Current Detection 50LP1 This scheme detects failures of the circuit breaker to open when circuit breaker current is greater than the 50LP1 setting The 50LP...

Page 314: ...detect when an open circuit breaker pole flashes over Set BLKFOA1 to TPA or CLS1 to block flashover protection for 6 cycles if an A phase single pole trip occurs or when circuit breaker BK1 closes Figure 5 116 shows the flashover circuit breaker failure logic Flashover timer FOPU1 Flashover Time Delay BK1 starts timing if the circuit breaker is open and current exceeds setting 50FO1 Flashover Curr...

Page 315: ...ilure FBFC1 C Phase circuit breaker failure FBF1 Circuit breaker failure NBF1 No current residual current circuit breaker failure LCBF1 Load current circuit breaker failure BLKFOA1 Block A Phase flashover detection BLKFOB1 Block B Phase flashover detection BLKFOC1 Block C Phase flashover detection FOA1 A Phase flashover detected FOB1 B Phase flashover detected FOC1 C Phase flashover detected FOBF1...

Page 316: ...Table 5 80 Circuit Breaker Failure Relay Word Bits Sheet 2 of 2 Namea Description IABKn BFI3Pn BnOPHA 50FAn 50FBn 50FCn IBBKn BnOPHB ICBKn 50FPn BnOPHC BFI3PTn Relay Word Bit Relay Word Bit BFIATn Relay Word Bit Relay Word Bits Relay Word Bits SELOGIC Setting 0 BFIDOn BFISPn 0 BFIAn 50FAn SELOGIC Setting 0 BFIDOn BFISPn 0 BFI3Pn BFI3PTn OR When the Scheme requires BFI Seal In BFIAn BFIATn OR When ...

Page 317: ...lashover Protection Logic Diagram EFOBFn Y 50FOAn 52AAn BLKFOAn Relay Word bit BLKFOAn asserts if an A phase single pole trip occurs or if the corresponding circuit breaker closes n 1 or 2 corresponds to Circuit Breaker 1 or Circuit Breaker 2 BnOPHA 50FOn IABKn FOBFn FOAn FOBn FOCn Relay Word Bit Relay Word Bit Relay Word Bits Relay Word Bits 5 CYC 0 FOPUn 0 6 CYC 0 SELOGIC Settings S R Q Setting ...

Page 318: ...sm check elements to program the relay to supervise cir cuit breaker closing include the synchronism check element outputs in the close SELOGIC control equations These element outputs are Relay Word bits 25W1BK1 25A1BK1 25W2BK1 25A2BK1 25W1BK2 25A1BK2 25W2BK2 and 25A2BK2 see Synchronism Check Logic Outputs on page 5 160 and Angle Checks and Synchronism Check Element Outputs on page 5 168 An exampl...

Page 319: ...that if the monitored single phase voltage inputs are in phase within a set table voltage angle difference and they meet the criteria of being healthy within a settable voltage magnitude window and or the voltage difference is less than a set limit the other phase to neutral voltages are likewise in phase and share the same voltage magnitude relationship The line voltage source is three phase but ...

Page 320: ...ions explain these settings and include an explanation of Alternative Synchronism Check Voltage Source 2 settings see Figure 5 131 Synchronism Check Logic Outputs Figure 5 121 shows the correspondence between synchronism check logic out puts Relay Word bits and the two circuit breaker arrangement These Relay Word bits assert to logical 1 e g 59VP equals logical 1 if true and deassert to logical 0 ...

Page 321: ...1 frequency greater than line frequency fS1 fP SLOW1 Bus 1 frequency less than line frequency fS1 fP 59VS2 VS2 within healthy voltage window 59VDIF2 Circuit Breaker BK2 synchronizing voltage difference less than limit 25ENBK2 Circuit Breaker BK2 synchronism check element enabled SFZBK2 Circuit Breaker BK2 slip frequency less than 0 005 Hz no slip condition SFBK2 0 005 Hz Circuit Breaker BK2 slip f...

Page 322: ... in the relay compensate for any steady state magnitude or angle difference with respect to a synchronism check voltage reference as discussed next in this example Three phase line voltages are connected to relay voltage inputs VAY VBY and VCY these voltage inputs are also used for distance elements fault location loss of potential load encroachment and directionality Only one of these single phas...

Page 323: ...phase rota tion The synchronism check voltage reference VP is from the A Phase voltage VA of the line You can connect phase to phase voltage VBC originating from Bus 1 and connect phase to neutral voltage VC from Bus 2 Thus Bus 1 voltage VBC lags synchronism check voltage reference VP by 90 degrees and Bus 2 volt age VC lags the synchronism check voltage reference VP by 240 degrees To compensate f...

Page 324: ...ty suppose Bus 1 voltage VBC is 201 V secondary phase to phase and the syn chronism check voltage reference VP is 67 V secondary phase to neutral Then the magnitude compensation setting would be as in Equation 5 32 Equation 5 32 Normalized Synchronism Check Voltage Sources VS1 and VS2 The Figure 5 123 example continues in Figure 5 124 which graphically illus trates how the introduced settings adju...

Page 325: ...e of the circuit breaker normalized voltage VS1 for Circuit Breaker BK1 and normalized voltage VS2 for Circuit Breaker BK2 must lie within a healthy voltage window bounded by voltage threshold settings 25VH and 25VL see Figure 5 125 The relay asserts Relay Word bits 59VP 59VS1 and 59VS2 to indicate healthy synchronism check voltages VP VS1 and VS2 respectively see Figure 5 125 If either of the vol...

Page 326: ...dary check to ensure the relay does not operate on erroneous signals Block Synchronism Check If the block synchronism check BSYNBKn SELOGIC control equation where n 1 or 2 for Circuit Breaker BK1 or Circuit Breaker BK2 respectively asserts synchronism check cannot proceed for the corresponding circuit breaker Follow ing is an example for Circuit Breaker BK1 BSYNBK1 52AA1 AND 52AB1 AND 52AC1 Block ...

Page 327: ... synchronism check is blocked for Circuit Breaker BK1 There is no need to qualify or continue with the synchronism check for circuit breaker closing the circuit breaker is already closed Synchronism Check Enable Logic The relay combines the voltage check elements and block synchronism check condition to create a synchronism check enable condition for each circuit breaker as shown in Figure 5 127 S...

Page 328: ...LOGIC Setting 59VP 59VS2 BSYNBK2 Block synchronism check for Circuit Breaker BK2 0 25ENBK2 Enable synchronism check for Circuit Breaker BK2 SELOGIC Setting VP healthy VS2 healthy E25BK1 Y E25BK2 Y SELOGIC Setting 59VDIF1 Relay Word Bit Relay Word Bit Relay Word Bit Relay Word Bit Relay Word Bit E25BK1 Y1 BSYNBK1 6 cyc 6 cyc 6 cyc 0 Relay Word Bit 25ENBK1 Enable synchronism check for Circuit Breake...

Page 329: ...een synchronism check element outputs 25W1BK1 and 25A1BK1 are apparent in the slip with compensation exam ple Figure 5 130 The second angle difference setting ANG2BK1 for Circuit Breaker BK1 oper ates similarly to affect synchronism check element outputs 25W2BK1 and 25A2BK1 No Slip Synchronism Check Refer to the paralleled system beyond the open circuit breaker in Figure 5 119 For such a system th...

Page 330: ...sert to logical 1 or deassert to logical 0 Slip No Compensation Synchronism Check The four cases a b c and d shown in Figure 5 129 are slip no com pensation cases for asynchronous systems not paralleled The cases progress in time from top to bottom The normalized synchronism check voltage source Figure 5 128 No Slip System Synchronism Check Element Output Response VP a b c d VS1 VP VS1 VP VS1 VP V...

Page 331: ...to VS1 has a higher system frequency than the system correspond ing to VP fS1 fP Positive slip frequency is the counter clockwise rotation of VS1 with respect to reference VP as shown in Figure 5 129 Relay Word bit FAST1 asserts to logical 1 and Relay Word bit SLOW1 deasserts to logical 0 to indicate this condition Figure 5 129 Slip No Compensation Synchronism Check Element Output Response VP a b ...

Page 332: ...o slip condition Figure 5 128 and the slip no compensation Figure 5 129 condi tion results from the maximum slip frequency setting 25SFBK1 OFF Setting 25SFBK1 has no effect in a no slip scenario Figure 5 128 but the setting does affect the operation of synchronism check element output 25A1BK1 see the slip no compensation scenario Figure 5 129 With setting 25SFBK1 OFF the relay does not compensate ...

Page 333: ... the angle between VS1 and V S1 increases for a greater slip between VS1 and VP fS1 fP a greater Circuit Breaker BK1 close time setting TCLSBK1 or both in combination Figure 5 130 Slip With Compensation Synchronism Check Element Output Response VP a b c d VS1 V S1 VP VS1 VP VS1 VP VS1 Response of synchronism check element outputs Relay Word Bits 25W1BK1 logical 1 25A1BK1 logical 1 25W1BK1 logical ...

Page 334: ... however that V S1 is approaching synchronism check reference VP This is where element output 25A1BK1 behaves differently than element output 25W1BK1 for setting 25SFBK1 set to some value other than OFF As V S1 approaches VP 25A1BK1 remains deasserted equals logical 0 until the phase angle difference between reference VP and V S1 equals zero degrees At this zero degrees difference between VP and V...

Page 335: ... source voltage connection adjust the source to reference magnitude ratio with setting AKS2M and the source to reference angle compensation with setting AKS2A considering the settings for Volt age Magnitude and Angle Compensation on page 5 163 For example in Figure 5 131 the Bus 2 voltage is the regular Synchronism Check Voltage Source 2 for synchronism check across Circuit Breaker BK2 However if ...

Page 336: ...tch to control inputs on the SEL 421 Circuit breaker BK3 to IN103 Generator switch to IN104 These input connections are for this application example only use relay inputs that are appropriate for your system Set the ALTS2 SELOGIC control equation to assert when Circuit Breaker BK3 is open and the generator switch is closed ALTS2 NOT IN103 AND IN104 Alternative Synchronism Source 2 SELOGIC Equation...

Page 337: ... Autoreclose Example on page 6 137 Autoreclose and Synchronism Check Example on page 6 141 Circuit Breaker Failure Application Examples on page 6 151 230 kV Tapped Transmission Line Application Example on page 6 170 230 kV Overhead Distribution Line Example Figure 6 1 shows a double ended 230 kV line with SEL 421 protection at each end This example explains how to calculate settings for the SEL 42...

Page 338: ... looking instantaneous underreaching protection Zone 2 forward looking time delayed tripping Table 6 1 System Data 230 kV Overhead Transmission Line Parameter Value Nominal system line to line voltage 230 kV Nominal relay current 5 A secondary Nominal frequency 60 Hz Line length 50 miles Line impedances Z1L Z0L 39 84 primary 124 81 5 primary Source S impedances Z1S Z0S 50 86 primary Source R imped...

Page 339: ...Configure the SEL 421 for one circuit breaker NUMBK 1 Number of Breakers in Scheme 1 2 BID1 Circuit Breaker 1 Breaker 1 Identifier 40 characters You can select both nominal frequency and phase rotation for the relay NFREQ 60 Nominal System Frequency 50 60 Hz PHROT ABC System Phase Rotation ABC ACB Current and Voltage Source Selection The voltage and current source selection is for one circuit brea...

Page 340: ...input for line relaying The settings VNOMY and VNOMZ specify the nominal secondary line to line voltage of the potential transformers see Figure 6 2 CTRW 100 Current Transformer Ratio Input W 1 50000 PTRY 2000 Potential Transformer Ratio Input Y 1 10000 VNOMY 115 PT Nominal Voltage L L Input Y 60 300 V secondary PTRZ 2000 Potential Transformer Ratio Input Z 1 10000 VNOMZ 115 PT Nominal Voltage L L...

Page 341: ...he ratio based on the Zone 1 reach because you do not want Zone 1 distance protection to overreach during an external fault Equation 6 3 ECVT N CVT Transient Detection Y N NOTE The SEL 421 4 does not provide series compensated line protection logic The transmission line is not series compensated ESERCMP N Series Compensated Line Logic Y N You can select a common time delay or an independent time d...

Page 342: ...ly determining fault distance or direction Occasional loss of potential LOP to the distance relay while unavoidable is detectable When the relay detects the loss of potential the relay can block dis tance element operation block or enable forward directional overcurrent ele ments and issue an alarm for any true LOP condition NOTE If line side PTs are used the circuit breaker s must be closed for t...

Page 343: ...ce protection equal to 80 percent of the transmission line positive sequence impedance Z1MP 0 8 Z1L 1 56 Z1MP 1 56 Zone 1 Reach OFF 0 05 64 secondary Zone 2 Phase Distance Element Reach Zone 2 phase distance protection must have adequate reach to detect all phase to phase phase to phase to ground and three phase faults along the protected line to make certain delayed tripping occurs for faults loc...

Page 344: ...values for k0M1 and k0A1 k0M1 0 727 Zone 1 ZSC Factor Magnitude AUTO 0 000 10 k0A1 3 65 Zone 1 ZCS Factor Angle Distance Element Common Time Delay Set the appropriate timers Z1D and Z2D for both phase and ground distance ele ments NOTE If the relay is using a remote data acquisition system such as TiDL the operating times will be delayed by 1 5 ms Use caution when setting the relay coordination ti...

Page 345: ...e advantage of resetting SOTF protection quickly is that unwanted tripping does not occur for subsequent faults external to the remote terminals during the SOTF period these trips can occur if you set instantaneous Zone 2 distance protection elements in the TRSOTF SELOGIC control equation Enable the voltage reset option and leave the VRSTPU setting at default 0 8 EVRST Y Switch Onto Fault Voltage ...

Page 346: ...minal for a close in three phase fault use weak source condi tions so that the relay operates for low level fault current 50P1P 13 29 Level 1 Pickup OFF 0 25 100 A secondary This application uses 50P1 as an instantaneous overcurrent element you do not need time delay 67P1D 0 000 Level 1 Time Delay 0 000 16000 cycles This application uses 50P1 as a nondirectional overcurrent element you do not need...

Page 347: ...GF 51S1 Torque Control SELOGIC Equation Directional Control The SEL 421 uses an array of directional elements to supervise the ground dis tance elements and residual ground directional overcurrent elements during ground fault conditions Internal logic automatically selects the best choice for the ground directional element 32G from among the negative sequence voltage polarized directional element ...

Page 348: ... is important when you use line side potential trans formers for relaying Use the 3POD setting to stabilize the ground distance ele ments in case of pole scatter during closing of the circuit breaker 3POD 0 500 Three Pole Open Time Dropout Delay 0 000 60 cycles Trip Logic This logic configures the relay for tripping These settings consist of four catego ries Trip equations Trip unlatch options Tri...

Page 349: ...fines which protection elements cause the relay to trip when the SOTF scheme is active Assertion of these protection elements during the SOTFD time causes the relay to trip instantaneously see SOTF Scheme on page 6 8 Set instantaneous Zone 2 distance protection Z2P and Z2G and Level 1 phase instantaneous overcurrent element 50P1 in the TRSOTF SELOGIC control equation TRSOTF Z2P OR Z2G OR 50P1 Swit...

Page 350: ...etting for this timer is 9 cycles TDUR3D 9 000 Three Pole Trip Minimum Trip Duration Time Delay 2 000 8000 cycles Three Pole Tripping Enable The relay contains both three pole and single pole tripping logic Set E3PT Three Pole Trip Enable equal to logical 1 to enable the SEL 421 for three pole tripping only E3PT 1 Three Pole Trip Enable SELOGIC Equation Also set the appropriate three pole tripping...

Page 351: ...uency Hz 60 PHROT System Phase Rotation ABC ACB ABC DATE_F Date Format MDY YMD DMY MDY FAULT Fault Condition Equation SELOGIC Equation 50P1 OR 51S1 OR Z2P OR Z2G OR Z3P OR Z3G Current and Voltage Source Selection Global ESS Current and Voltage Source Selection Y N 1 2 3 4 N Breaker Configuration Breaker Monitoring EB1MON Breaker 1 Monitoring Y N N BK1TYP Breaker 1 Trip Type Single Pole 1 Three Pol...

Page 352: ...OTT POTT2 POTT3 DCUB1 DCUB2 N EBFL1 Breaker 1 Failure Logic N 1 2 Y1 Y2 N E25BK1 Synchronism Check for Breaker 1 Y N Y1 Y2 N E79 Reclosing Y Y1 N N EMANCL Manual Closing Y N N ELOP Loss of Potential Y Y1 N Y1 EDEM Demand Metering N THM ROL N EADVS Advanced Settings Y N N Mho Phase Distance Element Reach Group Z1MP Zone 1 Reach OFF 0 05 64 secondary 1 56 Z2MP Zone 2 Reach OFF 0 05 64 secondary 2 34...

Page 353: ...erating Quantity Time Overcurrent Element Settings Group 51S1O 51S1 Operating Quantity IAn IBn ICn IMAXn I1L 3I2L 3I0n a 3I0L 51S1P 51S1 Overcurrent Pickup 0 25 16 A secondary 1 72 51S1C 51S1 Inverse Time Overcurrent Curve U1 U5 U3 51S1TD 51S1 Inverse Time Overcurrent Time Dial 0 50 15 00 1 96 51S1RS 51S1 Inverse Time Overcurrent Electromechanical Reset Y N Y 51S1TC 51S1 Torque Control SELOGIC Equ...

Page 354: ...0 kV circuit Distance protection is enabled ULTR Unlatch Trip SELOGIC Equation TRGTR ULMTR1 Unlatch Manual Trip Breaker 1 SELOGIC Equation NOT 52AA1 AND 52AB1 AND 52AC1 TOPD Trip During Open Pole Time Delay 2 000 8000 cycles 2 000 TULO Trip Unlatch Option 1 2 3 4 3 Z2GTSP Zone 2 Ground Distance Time Delay SPT Y N N 67QGSP Zone 2 Dir Neg Seq Residual O C Single Pole Trip Y N N TDUR1D SPT Minimum Tr...

Page 355: ...1S Z0S Z1R Z0R Z0M VY VAZ IX IW S Moscow R Pullman Line 2 Line 1 BK1B BK1A BUS 1 BUS 2 SEL 421 500 kV 500 kV Table 6 7 System Data 500 kV Parallel Overhead Transmission Lines Parameter Value Nominal system line to line voltage 500 kV Nominal relay current 5 A secondary Nominal frequency 60 Hz Line length 75 miles Line impedances Z1L1 Z1L2 Z0L1 Z0L2 44 78 87 6 primary 162 9 82 1 primary Zero sequen...

Page 356: ...me Three zones of phase mho and ground mho and quadrilateral distance protection Zone 1 forward looking instantaneous underreaching protection Zone 2 forward looking communications assisted and time delayed tripping Zone 3 reverse looking prevents unwanted tripping during current reversals Inverse time directional zero sequence overcurrent backup protection SOTF protection fast tripping when the c...

Page 357: ...u can select both the nominal frequency and phase rotation NFREQ 60 Nominal System Frequency 50 60 Hz PHROT ABC System Phase Rotation ABC ACB Current and Voltage Source Selection The voltage and current source selection is for two circuit breakers in a circuit breaker and a half configuration Set ESS to 3 ESS 3 Current and Voltage Source Selection Y N 1 2 3 4 After you select 3 for setting ESS the...

Page 358: ...t Breaker 2 Inputs 52AA2 IN104 A Phase N O Contact Input BK2 SELOGIC Equation 52AB2 IN105 B Phase N O Contact Input BK2 SELOGIC Equation 52AC2 IN106 C Phase N O Contact Input BK2 SELOGIC Equation Group Settings Line Configuration The SEL 421 has four transformer turns ratio settings that convert the secondary potentials and currents that the relay measures to the corresponding primary val ues Thes...

Page 359: ...length This value has no defined unit you can set the line length in miles kilometers ohms etc Set the length in miles LL 75 00 Line Length 0 10 999 The relay fault locator uses the values you enter for Z1MAG Z1ANG Z0MAG Z0ANG and LL Relay Configuration You can select from zero to five phase mho E21P ground mho E21MG and ground quadrilateral E21XG distance zones You can independently select the nu...

Page 360: ... Out of Step Y N Do not enable the load encroachment logic as the minimum apparent load impedance is outside the mho phase distance characteristics ELOAD N Load Encroachment Y N Use Level 1 high set instantaneous phase overcurrent element for SOTF protection E50P 1 Phase Instantaneous Definite Time Overcurrent Elements N 1 4 This application does not require residual ground overcurrent protection ...

Page 361: ...annot detect a loss of potential condition when the circuit breaker s closes again At circuit breaker closing the relay can detect one or two missing potentials that occurred while the circuit breaker was open See Loss of Potential Logic on page 5 28 for more information Table 6 9 lists the three choices for enabling LOP Set ELOP to Y1 for this application example This choice reduces the chances o...

Page 362: ...e transmission line Set Zone 1 phase distance protection equal to 80 percent of the transmission line positive sequence impedance Z1MP 0 8 Z1L1 3 18 Z1MP 3 18 Zone 1 Reach OFF 0 05 64 secondary Zone 2 Phase Distance Element Reach Zone 2 phase distance protection must have adequate reach to detect all phase to phase phase to phase to ground and three phase faults along the protected line Set Zone 2...

Page 363: ...each setting should be no greater than 80 percent of the line Z1MG 0 8 Z1L1 3 18 Z1MG 3 18 Zone 1 OFF 0 05 64 secondary Zone 2 Mho Ground Distance Element Reach Zone 2 mho and ground distance reach must meet the same requirement as that for Zone 2 mho phase distance protection the reach setting is 120 percent of the line Z2MG 1 2 Z1L1 4 78 Z2MG 4 78 Zone 2 OFF 0 05 64 secondary Zone 3 Mho Ground D...

Page 364: ...9 which is Equation 3 in Appendix A Quadrilateral Reactive Reach Versus Resistive Reach Setting Guideline from the paper Digital Commu nications for Power System Protection Security Availability and Speed You can find a copy of this paper on the SEL website at selinc com Equation 6 9 XG1 is set at 80 percent of the transmission line i e m 0 8 per unit the posi tive sequence reactance of the overhe...

Page 365: ...quadrilateral resistive reach as follows Equation 6 12 RG2 12 00 Zone 2 Resistance 0 05 50 secondary Zone 3 Reactance Zone 3 quadrilateral ground distance reach must meet the same requirement as that for Zone 3 mho phase distance protection it equals Zone 2 reach XG3 XG2 4 78 XG3 4 78 Zone 3 Reactance OFF 0 05 64 secondary Zone 3 Resistance The Zone 3 quadrilateral resistive reach is also scaled b...

Page 366: ...equence network is homogeneous ZLEFT is the total impedance up to the fault F on the left hand side while ZRIGHT is the total impedance up to the fault on the right hand side A network is homogeneous with respect to the particular fault location if Equation 6 12 is satisfied Equation 6 13 Use Equation 6 14 and Equation 6 15 to determine the zero sequence and nega tive sequence homogeneity Equation...

Page 367: ... 15 for both the negative sequence and zero sequence networks The negative sequence network is more homogeneous than the zero sequence network because the magnitude of T2 is less than the magnitude of T0 Select negative sequence current flowing in the line as the polarizing quantity for the ground distance quadrilateral reactance measurement XGPOL I2 Quadrilateral Ground Polarizing Quantity I2 IG ...

Page 368: ...R The Zone 1 ground distance element has a dedicated zero sequence current compensation factor k01 Advanced Settings are enabled for this particular example set two independent zero sequence current compensation factors one for forward looking k0 zones and one for reverse looking k0R zones The SEL 421 ground distance elements do not employ zero sequence mutual coupling compensation Zero sequence m...

Page 369: ...alternate settings group if Zone 2 ground distance protection provides time delayed backup protec tion Zone 2 ground distance protection and downstream Zone 1 ground distance protection could coordinate poorly Distance Element Common Time Delay NOTE If the relay is using a remote data acquisition system such as TiDL the operating times will be delayed by 1 5 ms Use caution when setting the relay c...

Page 370: ...ted but before the SOTFD timer expires To quickly reset the SOTF period the relay must sense that the positive sequence voltage is greater than the VRSTPU setting multiplied by the nominal voltage Use setting EVRST Switch Onto Fault Voltage Reset to enable fast reset The advantage of resetting SOTF protection quickly is that unwanted tripping does not occur for subsequent faults external to the re...

Page 371: ... fault use weak source condi tions so that the relay operates for low level fault current 50P1P 7 21 Level 1 Pickup OFF 0 25 100 A secondary This application uses 50P1 as an instantaneous overcurrent element you do not need time delay 67P1D 0 000 Level 1 Time Delay 0 000 16000 cycles This application uses 50P1 as a nondirectional overcurrent element place no conditions on torque control 67P1TC 1 L...

Page 372: ...ime Overcurrent Electromechanical Reset Y N Torque control the overcurrent element with the forward decision from the ground directional element 51S1TC 32GF 51S1 Torque Control SELOGIC Equation Zone Level Direction Zone 1 and Zone 2 distance element directions are fixed in the forward direction You can select the other zones independently as forward looking F or reverse looking R Set Zone 3 distan...

Page 373: ... offers two options for deciding what conditions signify an open pole as listed in Table 6 11 Select the second option because a 52A contact is available The relay uses both open phase detection and status information from the circuit breaker to make the most secure decision EPO 52 Pole Open Detection 52 V Pole Open Time Delay on Dropout SPOD is the time delay on dropout after the Relay Word bit S...

Page 374: ...ccurs and the reverse looking elements drop out Set Z3RBD timer to accommodate for the following Remote terminal R circuit breaker maximum opening time Maximum communications channel reset time Remote terminal R Zone 2 relay maximum reset time Assume a circuit breaker opening time of 3 cycles a communications channel reset time of 1 cycle and remote Zone 2 relay reset time of 1 cycle The sum of th...

Page 375: ...it should remain for a minimum period of time and then stop even if a terminal receives a continuous permissive signal This termination of the echo signal prevents the permissive trip signal from latching between the two terminals Assume a 3 cycle circuit breaker at the remote terminal and a 1 cycle channel delay The sum of these two is a set ting of 4 cycles EDURD 4 000 Echo Duration Time Delay 0...

Page 376: ...e six SELOGIC control equations for tripping TR unconditional TRCOMM TRCOMMD communications assisted TRSOTF SOTF DTA DTB and DTC direct tripping The TR SELOGIC control equation determines which protection elements trip unconditionally Set TR to Zone 1 instantaneous distance protection Zone 2 time delayed distance protection and inverse time overcurrent protection for backup TR Z1T OR Z2T OR 51S1T ...

Page 377: ... original single pole trip If the SEL 421 internal reclosing relay is being used the E3PT E3PT1 and E3PT2 settings in the trip logic should be set as shown in Internal Recloser on page 6 9 and Internal Recloser on page 6 25 in the SEL 400 Series Relays Instruction Manual See Autoreclose Example on page 6 137 for information on using the SEL 421 reclosing relay To illustrate another way of using an...

Page 378: ...t SPT Y N Trip Timers The SEL 421 provides dedicated timers for minimum trip durations and open pole time delays Minimum Trip Duration The minimum trip duration timer settings TDUR1D and TDUR3D determine the minimum length of time that Relay Word bits TPA1 TPA2 TPB1 TPB2 TPC1 TPC2 and 3PT assert Use these timers to control the designated trip con trol outputs The control outputs programmed for tri...

Page 379: ...ngs E3PT1 IN107 Breaker 1 3PT SELOGIC Equation E3PT2 IN107 Breaker 2 3PT SELOGIC Equation Control Outputs Main Board Use SELOGIC control equations to assign the control outputs for tripping Use the main board control outputs for tripping The first three control outputs trip Circuit Breaker BK1A and the next three trip circuit breaker BK1B OUT101 TPA1 OUT102 TPB1 OUT103 TPC1 OUT104 TPA2 OUT105 TPB2...

Page 380: ...e identification between the line protection at both ends of the line In doing so you avoid three pole tripping both lines at Station S while single pole tripping both lines at Station R Transmit Equations Overcoming this mismatch requires at least two communications channels one for transmitting three pole trip permission KEY3 and another for transmitting all permissive trips KEY1 The relay at St...

Page 381: ...e pole trip only if both PT1 and PT3 assert PT3 confirms that the remote ter minal Station R has also identified the fault type as multiphase If the SEL 421 detects a multiphase fault in Zone 2 and receives only PT1 like in the cross country fault situation on a parallel line system the relay delays a trip until the permissive signal received agrees with the fault type detected locally The fault t...

Page 382: ...ay use the phase segregate three channel POTT scheme POTT3 to correctly single pole trip without a delay in the event of cross country faults In the previ ous cross country fault example the SEL 421 on line 1 at Station R will transmit KEYA to the relay at Station S which converts it to PTA a permissive A Phase trip signal The relay then combines a locally detected Zone 2 phase distance ele ment w...

Page 383: ...tion DTC RMB5A Direct Transfer Trip C Phase SELOGIC Equation Example Completed This completes the application example that describes how to set the SEL 421 for communications assisted protection of 500 kV parallel overhead transmission lines with zero sequence mutual coupling Analyze your particular power system to determine the appropriate settings for your application Relay Settings Table 6 13 l...

Page 384: ... Equation IN103 Breaker 2 Inputs Breaker Monitoring 52AA2 A Phase N O Contact Input BK2 SELOGIC Equation IN104 52AB2 B Phase N O Contact Input BK2 SELOGIC Equation IN105 52AC2 C Phase N O Contact Input BK2 SELOGIC Equation IN106 Line Configuration Group CTRW Current Transformer Ratio Input W 1 50000 400 CTRX Current Transformer Ratio Input X 1 50000 400 PTRY Potential Transformer Ratio Input Y 1 1...

Page 385: ...T POTT2 POTT3 DCUB2 DCUB2 POTT2 EBFL1 Breaker 1 Failure Logic N 1 2 Y1 Y2 N EBFL2 Breaker 2 Failure Logic N 1 2 Y1 Y2 N E25BK1 Synchronism Check for Breaker 1 Y N Y1 Y2 N E25BK2 Synchronism Check for Breaker 2 Y N Y1 Y2 N E79 Reclosing Y Y1 N N EMANCL Manual Closing Y N N ELOP Loss of Potential Y Y1 N Y1 EDEM Demand Metering N THM ROL N EADVS Advanced Settings Y N Y VMEMC Memory Voltage Control SE...

Page 386: ...k0M Forward Zones ZSC Factor Magnitude 0 000 10 1 540 k0A Forward Zones ZSC Factor Angle 180 0 to 180 0 degrees 9 0 k0MR Reverse Zones ZSC Factor Magnitude 0 000 10 1 540 k0AR Reverse Zones ZSC Factor Angle 180 0 to 180 0 degrees 9 0 Ground Distance Element Time Delay Group Z1GD Zone 1 Time Delay OFF 0 000 16000 cycles OFF Z2GD Zone 2 Time Delay OFF 0 000 16000 cycles OFF Z3GD Zone 3 Time Delay OF...

Page 387: ...on Group DIR3 Zone Level 3 Direction Control F R R Directional Control Group ORDER Ground Directional Element Priority combine Q V I QV E32IV Zero Sequence Voltage And Current Enable SELOGIC Equation 1 Pole Open Detection Group EPO Pole Open Detection 52 V 52 SPOD Single Pole Open Dropout Delay cycles 0 500 3POD Three Pole Open Dropout Delay cycles 0 500 POTT Trip Scheme Group Z3RBD Zone 3 Reverse...

Page 388: ...NOT 52AA1AND 52AB1 AND 52AC1 ULMTR2 Unlatch Manual Trip Breaker 2 SELOGIC Equation NOT 52AA2 AND 52AB2 AND 52AC2 TOPD Trip During Open Pole Time Delay 2 000 8000 cycles 215 000 TULO Trip Unlatch Option 1 2 3 4 3 Z2GTSP Zone 2 Ground Distance Time Delay SPT Y N N 67QGSP Zone 2 Directional Neg Seq Residual Ground Overcurrent SPT Y N N TDUR1D SPT Minimum Trip Duration Time Delay 2 000 8000 cycles 9 0...

Page 389: ...provide high speed protection for faults along the 345 kV circuit The relay uses distance elements and residual ground directional overcurrent elements in this protection scheme Another SEL 421 located on the 138 kV side of the autotransformer blocks high speed tripping at Stations S and R for faults on the 138 kV side of the autotrans former MIRRORED BITS Transmit Equations Outputs TMB1A SELOGIC ...

Page 390: ...Y VY 345 kV 13 8 kV 138 kV T Bonners Ferry Table 6 14 System Data 345 kV Tapped Overhead Transmission Line Sheet 1 of 2 Parameter Value EHV nominal system line to line voltage transformer primary 345 kV HV line to line voltage transformer secondary 138 kV MV line to line voltage transformer tertiary 13 8 kV Nominal relay current 5 A secondary Nominal frequency 60 Hz Line lengthsa S t Section 1 t R...

Page 391: ...5 kV 115 V 3000 0 CTR current transformer ratio 1000 5 200 Phase rotation ABC a Parameter t is the tap point on the 345 kV line S and R are terminals at the ends of the 345 kV line see Figure 6 11 Table 6 15 Secondary Impedances Parameter Value Line impedances Z1L1 Z1L2 Z0L1 Z0L2 Z1L3 Z0L3 2 84 7 secondary 6 44 73 secondary 3 84 7 secondary 9 65 73 secondary Transformer impedances XHM XML XHL 8 50...

Page 392: ...nverse time directional zero sequence overcurrent backup protection Load encroachment logic prevents unwanted tripping during heavy load conditions SOTF protection fast tripping when the circuit breaker closes Relay settings that are not mentioned in this example do not apply to this applica tion example Global Settings General Global Settings The SEL 421 has settings for identification These sett...

Page 393: ... a normally open auxiliary contact from the circuit breaker to determine whether the circuit breaker is open or closed 52AA1 IN101 A Phase N O Contact Input BK1 SELOGIC Equation Group Settings Line Configuration The SEL 421 has four transformer turns ratio settings that convert the secondary potentials and currents that the relay measures to the corresponding primary val ues These settings are the...

Page 394: ... relay fault locator uses the values you enter for Z1MAG Z1ANG Z0MAG Z0ANG and LL Relay Configuration You can select from zero to five phase zones of phase mho E21P ground mho E21MG and ground quadrilateral E21XG distance protection You can inde pendently select the number of zones per type of distance protection Select only the number of zones needed For this application example use three zones o...

Page 395: ... 2 residual ground overcurrent element 67G2 is forward looking and provides communications assisted tripping The Level 3 residual overcurrent element 67G3 is reverse looking and blocks the tripping at Station R during out of sec tion faults behind Station S Enable three levels of residual ground overcurrent protection E50G 3 Residual Ground Instantaneous Definite Time Overcurrent Elements N 1 4 Th...

Page 396: ... zone of mho phase distance protection as follows Zone 1 Instantaneous underreaching tripping Zone 2 DCB scheme tripping Zone 3 DCB scheme blocking Zone 1 Phase Distance Element Reach Zone 1 phase distance protection provides instantaneous protection for phase to phase phase to phase to ground and three phase faults for 80 percent of the dis tance from Station S to Station R because this is the sh...

Page 397: ...elay measures at Station S Apply these quantities in Equation 6 23 and Equation 6 26 to determine the fault impedance the relay measures for the two fault types shown in Table 6 17 Use Equation 6 23 for an A Phase to ground fault and Equation 6 26 for the three phase fault Equation 6 23 The relay uses the zero sequence compensation factor to measure zero sequence quantities in terms of positive se...

Page 398: ...m the furthest reaching remote Zone 2 for reverse faults when there is no infeed from the other remote terminal Figure 6 13 illustrates this coordination issue You must set the Zone 2 reach at Station T to account for infeed during faults beyond the tap on the 345 kV sys tem However when one 345 kV station is out of service the Zone 2 at Station T overreaches for faults on the other side of the ta...

Page 399: ... remote terminal during reverse faults with respect to Station S subtract the fault impedance from the cor responding apparent impedance measurement from Table 6 18 Calculate the overreach at Station R SW B open SW L and SW R closed Equation 6 28 Calculate the overreach at Station T SW R open SW L and SW B closed Equation 6 29 Table 6 18 Apparent Impedance Measurement for Remote Faults Station ZAG...

Page 400: ...h setting can be no greater than 80 percent of the protected line Z1MG Z1MP 3 2 Z1MG 3 20 Zone 1 OFF 0 05 64 secondary Zone 2 Mho Ground Distance Element Reach Set Zone 2 ground distance element reach equal to Zone 2 phase distance ele ment reach this ensures that Zone 2 ground distance elements can see faults internal to the tapped autotransformer Zone 2 phase distance element reach was set to se...

Page 401: ...ay displays the following values for k0M1 and k0MA k0M1 0 750 Zone 1 ZSC Factor Magnitude AUTO 0 000 10 k0MA 16 87 Zone 1 ZCS Factor Angle 180 0 to 180 0 degrees Distance Element Common Time Delay NOTE If the relay is using a remote data acquisition system such as TiDL the operating times will be delayed by 1 5 ms Use caution when setting the relay coordination times to account for this added dela...

Page 402: ...voltage Use setting EVRST Switch Onto Fault Voltage Reset to enable fast reset The advantage of resetting SOTF protection quickly is that unwanted tripping does not occur for subsequent faults external to the remote terminals during the SOTF period these trips can occur if you set instantaneous Zone 2 distance protection elements in the TRSOTF SELOGIC control equation Enable the voltage reset opti...

Page 403: ...elay uses a load encroachment feature that prevents operation of the phase distance elements during heavy load This unique feature permits the load to enter a predefined area of the phase distance characteristics without causing unwanted tripping Figure 6 15 illustrates the load encroachment function super imposed on the mho phase distance protection characteristics Define the load encroachment ch...

Page 404: ...45 Assume both forward export and reverse import load ranges to be the same PLAF 45 0 Forward Load Positive Angle 90 0 to 90 0 degrees NLAF 45 0 Forward Load Negative Angle 90 0 to 90 0 degrees PLAR 135 0 Reverse Load Positive Angle 90 0 to 270 0 degrees NLAR 225 0 Reverse Load Negative Angle 90 0 to 270 0 degrees Phase Instantaneous Definite Time Overcurrent Elements Use 50P1 Level 1 phase instan...

Page 405: ...nce elements measure fault resistance consisting of arcing resistance and ground return resistance Ground return resistance can consist of tower footing resistance and tree resistance The total ground fault resistance can lie outside of the ground distance characteristics Residual overcurrent protection is the best method available for detecting high resistance ground faults because this method of...

Page 406: ...y Use the following formula to determine approximately how much primary fault resistance coverage RF is provided by 51S1P on a radial basis Equation 6 36 Use the following as a guide to set the curve and time dial for secure backup pro tection perform a coordination study Set the local overcurrent element to coordinate with the downstream overcurrent element such that there is an 18 cycle 60 Hz no...

Page 407: ...irectional element classification is as follows Q Negative sequence voltage polarized directional element V Zero sequence voltage polarized directional element I Zero sequence current polarized directional element Set ORDER to QV The first listed directional element choice Q is the first pri ority directional element to provide directional control for the ground distance elements and residual dire...

Page 408: ...6 39 Equation 6 40 Perform the following two checks to make sure the ground directional element does not incorrectly make a forward decision during a reverse unbalanced fault 32QG Reverse Directional Check You set Z1MAG equal to Z1L1 plus Z1L2 so the fault locator provides correct results for internal faults not located on the tap i e source T is extremely weak and provides practically no infeed F...

Page 409: ... during a reverse unbalanced fault Equation 6 41 The downstream parallel impedance Z2P is the Line 3 impedance the trans former reactances and the Bus R impedance Equation 6 42 Use the following two assumptions to simplify the calculations 1 Assume the power system is purely reactive 2 Ignore source impedances Z1R and Z1T a conservative assumption Figure 6 16 345 kV Tapped Line Negative Sequence N...

Page 410: ...nt always operates correctly during reverse unbalanced faults check the following condition Z2F Z1L1 Z2P 2 2 1 35 2 3 35 The condition is satisfied the reverse negative sequence voltage polarized direc tional element decision is correct during reverse unbalanced faults XH 0 5 XHM XHL XML 0 5 0 016 0 6 0 4 0 108 per unit XM 0 5 XHM XML XHL 0 5 0 016 0 4 0 6 0 092 per unit XL 0 5 XHL XML XHM 0 5 0 6...

Page 411: ...ation 6 47 is the apparent zero sequence impedance measured by 32V during reverse unbalanced faults Equation 6 47 Equation 6 48 Use the following two assumptions to simplify the calculations 1 Assume the power system is purely reactive 2 Ignore source impedances Z0R and Z0T a conservative assumption Figure 6 17 345 kV Tapped Line Zero Sequence Network where Z0P parallel combination of the Line 3 i...

Page 412: ...e polarized 32V element always operates correctly during reverse unbalanced faults check the following condition Z0F Z0L1 Z0P 6 44 6 44 3 8 6 44 10 24 The condition is satisfied the reverse zero sequence voltage polarized direc tional element decision is correct during reverse unbalanced faults Pole Open Detection The setting EPO offers two options for deciding what conditions signify an open pole...

Page 413: ...ut of section faults Nondirectional elements are always faster than directional ele ments because directional elements need additional time to process the direc tional decision Select both types of elements for this application Assign Relay Word bit NSTRT Nondirectional Start to OUT102 to start trans mission of the blocking signal NSTRT asserts if Level 3 residual ground over current element 50G3 ...

Page 414: ...ickup prevents transmission of the blocking signal if a transient causes a reverse looking element to pick up momentarily Set the corresponding timer to 1 cycle Z3XPU 1 000 Zone 3 Reverse Pickup Time Delay 0 000 16000 cycles You can also extend the blocking signal during current reversals Set the corre sponding dropout timer to 5 cycles Z3XD 5 000 Zone 3 Reverse Dropout Delay 0 000 16000 cycles Co...

Page 415: ... Level 2 Overcurrent Short Delay 0 000 16000 cycles Blocking Signal Extension Assign a control input to recognize when the local terminal receives a blocking signal from the remote terminal during external faults BT IN103 Block Trip Received SELOGIC Equation The DCB trip scheme uses an on off carrier signal to block high speed tripping at Stations S and R for out of section faults Connect the carr...

Page 416: ...relay to trip unconditionally Set TR to the Zone 1 instantaneous distance pro tection Z1T Zone 2 time delayed distance protection and the inverse time overcurrent element 51S1 for backup protection For information on setting 51S1 see Selectable Operating Quantity Time Overcurrent Element 1 on page 6 10 TR Z1T OR Z2T OR 51S1T Trip SELOGIC Equation TRCOMM The TRCOMM SELOGIC control equation determin...

Page 417: ...ods for unlatching control outputs following a protection trip ULTR all three poles TULO phase selective ULTR Use ULTR the Unlatch Trip SELOGIC control equation to unlatch all three poles Use the default setting which asserts ULTR when you push the front panel target reset button ULTR TRGTR Unlatch Trip SELOGIC Equation TULO Use TULO Trip Unlatch Option to select the conditions that cause the SEL ...

Page 418: ...gic Set E3PT Three Pole Trip Enable to logical 1 to enable three pole tripping only E3PT 1 Three Pole Trip Enable SELOGIC Equation Also set the appropriate three pole tripping SELOGIC control equation for Circuit Breaker BK1 E3PT1 1 Breaker 1 3PT SELOGIC Equation Control Outputs Main Board OUT101 trips Circuit Breaker 1 OUT101 3PT OUT102 keys the local transmitter to send the blocking signal to th...

Page 419: ...N O Contact Input BK1 SELOGIC Equation IN101 Line Configuration Group CTRW Current Transformer Ratio Input W 1 50000 200 CTRX Current Transformer Ratio Input X 1 50000 200 PTRY Potential Transformer Ratio Input Y 1 10000 3000 0 VNOMY PT Nominal Voltage L L Input Y 60 300 V secondary 115 PTRZ Potential Transformer Ratio Input Z 1 10000 3000 0 VNOMZ PT Nominal Voltage L L Input Z 60 300 V secondary ...

Page 420: ... cycles OFF Z2PD Zone 2 Time Delay OFF 0 000 16000 cycles OFF Z3PD Zone 3 Time Delay OFF 0 000 16000 cycles OFF Mho Ground Distance Element Reach Group Z1MG Zone 1 OFF 0 05 64 secondary 3 20 Z2MG Zone 2 OFF 0 05 64 secondary 11 00 Z3MG Zone 3 OFF 0 05 64 secondary 50 5 Zero Sequence Current Compensation Factor Group k0M1 Zone 1 ZSC Factor Magnitude AUTO 0 000 10 0 750 k0A1 Zone 1 ZSC Factor Angle ...

Page 421: ...ent Pickup Group 50G1P Level 1 Pickup OFF 0 25 100 A secondary OFF 50G2P Level 2 Pickup OFF 0 25 100 A secondary 1 00 50G3P Level 3 Pickup OFF 0 25 100 A secondary 0 50 Residual Ground Overcurrent Definite Time Delay Group 67G2D Level 2 Time Delay 0 000 16000 cycles 0 000 67G3D Level 3 Time Delay 0 000 16000 cycles 0 000 Residual Ground Overcurrent Torque Control Group 67G2TC Level 2 Torque Contro...

Page 422: ...on NA DTB Direct Transfer Trip B Phase SELOGIC Equation NA DTC Direct Transfer Trip C Phase SELOGIC Equation NA BK1MTR Manual Trip Breaker 1 SELOGIC Equation OC1 OR PB8_PUL ULTR Unlatch Trip SELOGIC Equation TRGTR ULMTR1 Unlatch Manual Trip Breaker 1 SELOGIC Equation NOT 52AA1 AND 52AB1 AND 52AC1 TOPD Trip During Open Pole Time Delay 2 000 8000 cycles 2 000 TULO Trip Unlatch Option 1 2 3 4 3 Z2GTS...

Page 423: ...ent intrusion of moisture and to withstand fluid pressure The cables are also grounded at both ends Depending on the nature of a ground fault ground fault current can return via the sheath the ground or both the sheath and ground Power System Data Table 6 22 lists the power system data for this application example Substitute the values and parameters that correspond to your system when you set the...

Page 424: ...primary Source R Impedances Z1R Z0R 35 87 primary PTR potential transformer ratio 230 kV 115 V 2000 CTR current transformer ratio 1000 5 200 Phase Rotation ABC Table 6 23 Secondary Impedances Parameter Value Cable Impedances Z1L1 Z1L2 Z0L1 sheath return only Z0L2 sheath return only Z0L1 ground return only Z0L2 ground return only Z0L1 sheath and ground return Z0L2 sheath and ground return 0 48 42 5...

Page 425: ... 3 reverse looking prevents unwanted tripping during current reversals Inverse time directional negative sequence overcurrent backup protection SOTF protection fast tripping when the circuit breaker closes Relay settings that are not mentioned in this example do not apply to this applica tion example Global Settings General Global Settings The SEL 421 has settings for identification These settings...

Page 426: ...rmally open auxiliary contact 52A from the circuit breaker to determine whether the circuit breaker is open or closed 52AA1 IN101 N O Contact Input BK1 SELOGIC Equation Group Settings Line Configuration The SEL 421 has four transformer turns ratio settings that convert the secondary potentials and current s the relay measures to the corresponding primary values These settings are the potential tra...

Page 427: ... unit you can set the line length in miles kilometers ohms etc Set the length in miles LL 25 00 Line Length 0 10 999 The relay fault locator uses the values you enter for Z1MAG Z1ANG Z0MAG Z0ANG and LL Relay Configuration You can select from zero to five phase mho E21P ground mho E21MG and ground quadrilateral E21XG distance zones The number of zones per type of distance protection is independentl...

Page 428: ... ground overcurrent protection E50G N Residual Ground Instantaneous Definite Time Overcurrent Ele ments N 1 4 Enable three levels of negative sequence overcurrent protection Use these nega tive sequence current level detectors in conjunction with the communications assisted tripping scheme E50Q 3 Negative Sequence Instantaneous Definite Time Overcurrent Ele ments N 1 4 Use inverse time overcurrent...

Page 429: ...ced Settings Y N Phase Distance Elements 21P Mho Phase Distance Element Reach Employ each zone of distance protection as follows Zone 1 Instantaneous underreaching tripping Zone 2 Forward looking fault detector for the POTT scheme and backup time delayed tripping Zone 3 Current reversal guard for the POTT scheme echo tripping and weak infeed logic Zone 1 Phase Distance Element Reach Zone 1 phase d...

Page 430: ...because this example uses a POTT scheme So that Zone 3 has greater fault coverage than Zone 2 at the remote terminal set the reach to remote Zone 2 and rely upon the length of the protected cable as the safety margin Z3MP Z2P 0 58 Z3MP 0 58 Zone 3 Reach OFF 0 05 64 secondary Ground Distance Elements 21XG Quadrilateral Ground Distance Element Reach The main advantage of ground distance protection i...

Page 431: ...f the cable XG1 0 8 Z1L1 0 8 0 48 0 38 XG1 0 38 Zone 1 Reactance OFF 0 05 64 secondary Zone 1 Resistance Find RG1 Zone 1 Resistance from the per unit reach m of the Zone 1 reactance Use Equation 6 55 which is Equation 3 in Appendix A Quadrilateral Reactive Reach Versus Resistive Reach Setting Guideline from the paper Digital Commu nications for Power System Protection Security Availability and Spe...

Page 432: ...istance Use the following formula to set RG2 Equation 6 57 RG2 1 97 Zone 2 Resistance 0 05 50 secondary Zone 3 Reactance Zone 3 quadrilateral ground distance reach must meet the same requirement as that for Zone 3 mho phase distance protection it equals Zone 2 reach XG3 XG2 0 58 XG3 0 58 Zone 3 Reactance OFF 0 05 64 secondary Zone 3 Resistance Set the Zone 3 resistance reach equal to Zone 2 resist...

Page 433: ...igure 6 22 shows the network to determine negative sequence or zero sequence homogeneity Zleft is the total impedance up to the fault F on the left side of the fault location while Zright is the total impedance up to the fault on the right side of the network A network is homogeneous with respect to the particular fault location if Equation 6 58 is satisfied Equation 6 58 Use Equation 6 59 and Equ...

Page 434: ... network is more homogeneous than the zero sequence network when compared with two of the three corresponding cable zero sequence impedances Choose negative sequence current for polarizing the quad rilateral ground distance protection XGPOL I2 Quadrilateral Ground Polarizing Quantity I2 IG Selection I2 indicates that the negative sequence current flowing in the cable is the polarizing quantity for...

Page 435: ...distance elements should measure fault impedance in terms of positive sequence impedance only The relay has three zero sequence current compensation factors k01 k0 and k0R The Zone 1 ground distance element has a dedicated zero sequence current compensation factor k01 Advanced Settings are enabled for this particular example EADVS Y so you must set two additional independent zero sequence current ...

Page 436: ...Return Path First apply Equation 6 61 with k01 based on Z0L1 sheath and ground k01 equal to 0 374 39 2 This is the most common ground fault return path Set TANGG equal to zero and assume that IPOL is equal to negative sequence current i e XGPOL is equal to I2 Table 6 26 lists the corresponding XAG reactance of the phase to ground fault calculations for the remote single phase to ground fault for e...

Page 437: ...round fault Put both parallel cables in service Table 6 28 lists the corresponding XAG calculations for a remote Station R ground fault for each of the three possible zero sequence cable impedances when the k0 calcu lation is based on Z0L1 ground Replace k01 with k0 or replace k01 with k0R in Equation 6 61 and Equation 6 63 The results of Table 6 28 show that the XAG calculation does not underreac...

Page 438: ...delay setting is 20 cycles Z2D 20 000 Zone 2 Time Delay OFF 0 000 16000 cycles Short Adjacent Lines You do not need to consider the following fault current return path scenario for this application example this information is provided here for applications with short adjacent lines Figure 6 25 illustrates an important consideration if you apply time delayed Zone 2 ground distance protection to bac...

Page 439: ...e SOTF enable duration resets within at least 5 cycles after it first asserted but before the SOTFD timer expires To quickly reset the SOTF period before this time the relay must sense that the positive sequence voltage V1 is greater than setting VRSTPU times the nominal voltage Use setting EVRST Switch Onto Fault Voltage Reset to enable fast reset The advantage of resetting SOTF protection quickl...

Page 440: ...urrent measured at the local terminal for a close in three phase fault use weak source conditions so that the relay operates for low level fault current 50P1P 9 57 Level 1 Pickup OFF 0 25 100 A secondary This application uses 50P1 as an instantaneous overcurrent element you do not need time delay 67P1D 0 000 Level 1 Time Delay 0 000 16000 cycles This application uses 50P1 as a nondirectional overc...

Page 441: ...Q3P setting is the pickup for directional overcurrent element 67Q3 Set the pickup of Level 3 negative sequence overcurrent element equal to the default for the pickup of 32QG Negative Sequence Voltage Polar ized Directional Element which is 50RP Reverse Supervisory Overcurrent Pickup The reverse looking element is 150 percent more sensitive than the for ward looking element 50Q3P 50RP 0 08 INOM 0 ...

Page 442: ...elay 0 000 16000 cycles Set the Level 2 torque control equation to the forward decision from the ground directional element 67Q2TC 32GF Level 2 Torque Control SELOGIC Equation Set the Level 3 torque control equation to the reverse decision from the ground directional element 67Q3TC 32GR Level 3 Torque Control SELOGIC Equation Selectable Operating Quantity Time Overcurrent Element 1 Use inverse tim...

Page 443: ...close in phase to phase fault at the remote station with the parallel cable out of service is 18 67 A secondary The pickup multiple is shown in Equation 6 67 Equation 6 67 Use the parameters of 24 cycles operating time and M 18 67 to choose the curve and time dial settings for the 51S1 element For curve and timing informa tion see Inverse Time Overcurrent Elements on page 5 99 51S1C U3 51S1 Invers...

Page 444: ...onal element I Zero sequence current polarized directional element Set ORDER to Q This setting selects only the negative sequence voltage polar ized directional element You rely on 32QG to provide high speed reliable and sensitive protection during unbalanced faults via the communications channel Cable zero sequence impedance depends on the fault current return path the neg ative sequence impedanc...

Page 445: ... Equation 6 69 to calculate the apparent negative sequence impedance during unbalanced faults Equation 6 69 Equation 6 69 yields a more conservative result for the negative sequence imped ance when the parallel cable is out of service Z2S 2 97 The result of Equation 6 69 is greater than the default setting for Z2R Z2R Z2F 1 2 INOM See Ground Directional Elements on page 1 18 for more information F...

Page 446: ... is a parallel cable application so you must use current reversal guard When the reverse looking elements detect an external fault the relay does not key the transmitter and ignores reception of a permissive signal from the remote terminal The Zone 3 Reverse Block Delay Z3RBD timer extends these two operations after a current reversal occurs and the reverse looking elements drop out Table 6 29 Opt...

Page 447: ... of 3 cycles a communications channel round trip time of 2 cycles and a safety margin of 5 cycles The sum of these times gives a conservative setting of 10 cycles for a three cycle circuit breaker EBLKD 10 000 Echo Block Time Delay OFF 0 000 16000 cycles The echo time delay setting ETDPU makes certain that the reverse looking ele ments at the receiving end have sufficient time to operate and block...

Page 448: ...om ponents Trip equations Trip unlatch options Trip timers Three pole tripping enable Trip Equations Set these three SELOGIC control equations for tripping TR unconditional TRCOMM TRCOMMD communications assisted in this example we use only TRCOMM TRSOTF SOTF TR The TR SELOGIC control equation determines which protection elements cause the relay to trip unconditionally Set TR to the Zone 1 instanta...

Page 449: ...rip SELOGIC control equation to unlatch all three poles Use the default setting to assert ULTR when you push the front panel tar get reset button ULTR TRGTR Unlatch Trip SELOGIC Equation TULO Use TULO Trip Unlatch Option to select the conditions that cause the SEL 421 to unlatch the control outputs that you programmed for tripping Table 6 30 shows the four trip unlatch options for setting TULO Sel...

Page 450: ... Pole Trip Enable to logical 1 to enable the SEL 421 for three pole trip ping only E3PT 1 Three Pole Trip Enable SELOGIC Equation Also set the appropriate three pole tripping SELOGIC control equation for Circuit Breaker BK1 E3PT1 1 Breaker 1 3PT SELOGIC Equation Control Outputs Main Board Use SELOGIC control equations to assign the control output for tripping Use the main board control outputs for...

Page 451: ...ng Y N N BK1TYP Breaker 1 Trip Type Single Pole 1 Three Pole 3 3 Breaker 1 Inputs Breaker Monitoring 52AA1 N O Contact Input BK1 SELOGIC Equation IN101 Line Configuration Group CTRW Current Transformer Ratio Input W 1 50000 200 CTRX Current Transformer Ratio Input X 1 50000 200 PTRY Potential Transformer Ratio Input Y 1 10000 2000 0 VNOMY PT Nominal Voltage L L Input Y 60 300 V secondary 115 PTRZ ...

Page 452: ...ttings Y N Y Mho Phase Distance Element Reach Group Z1MP Zone 1 Reach OFF 0 05 64 secondary 0 38 Z2MP Zone 2 Reach OFF 0 05 64 secondary 0 58 Z3MP Zone 3 Reach OFF 0 05 64 secondary 0 58 Mho Phase Distance Element Time Delay Group Z1PD Zone 1 Time Delay OFF 0 000 16000 cycles OFF Z2PD Zone 2 Time Delay OFF 0 000 16000 cycles OFF Z3PD Zone 3 Time Delay OFF 0 000 16000 cycles OFF Quadrilateral Groun...

Page 453: ...AEND 52A Pole Open Time Delay OFF 0 000 16000 cycles OFF CLOEND CLSMON or Single Pole Open Delay OFF 0 000 16000 cycles 10 000 SOTFD Switch Onto Fault Enable Duration 0 500 16000 cycles 10 000 CLSMON Close Signal Monitor SELOGIC Equation IN102 Phase Instantaneous Overcurrent Pickup Group 50P1P Level 1 Pickup OFF 0 25 100 A secondary 9 57 Phase Overcurrent Definite Time Delay Group 67P1D Level 1 Ti...

Page 454: ...Delay 0 000 16000 cycles 5 000 EBLKD Echo Block Time Delay OFF 0 000 16000 cycles 10 000 ETDPU Echo Time Delay Pickup OFF 0 000 16000 cycles 2 000 EDURD Echo Duration Time Delay 0 000 16000 cycles 4 000 EWFC Weak Infeed Trip Y N SP N PT1 General Permissive Trip Received SELOGIC Equation IN103 Trip Logic Group TR Trip SELOGIC Equation Z1T OR Z2T OR 51S1T TRCOMM Communications Assisted Trip SELOGIC ...

Page 455: ...ee pole tripping in a 500 kV power system Applica tions for single pole tripping are similar Refer to Figure 6 28 for a one line dia gram of the 500 kV system Z2GTSP Zone 2 Ground Distance Time Delay SPT Y N N 67QGSP Zone 2 Dir Negative Sequence Residual Overcur rent Single Pole Trip Y N N TDUR1D SPT Min Trip Duration Time Delay 2 000 8000 cycles 6 000 TDUR3D 3PT Min Trip Duration Time Delay 2 000...

Page 456: ...ble the out of step logic EOOS Y Out of Step Y N You do not need to enable the Advanced Settings for this application example EADVS N Advanced Settings Y N Out of Step Tripping Disable the OST logic for this particular application example EOOST N Out of Step Tripping N I O Phase Distance Element Blocking OSB logic blocks phase distance protection during a swing when the measured positive sequence ...

Page 457: ... reversal guard for the POTT permissive overreaching transfer tripping scheme For example if the OSB logic inhibits the DCB blocking signal during swings that pass behind the local relay over tripping can occur at the remote terminal If a power swing enters both the local reverse looking Zone 3 and the remote overreaching Zone 2 high speed tripping occurs at the remote terminal because OSB logic r...

Page 458: ... margin 20 percent for this example When you set Zone 6 SEL recommends that you assume that Z1ANG is at 90 degrees This allows the user to set the resistive reach of the zone along the x axis Internally the relay will adjust the setting by the line angle Z1ANG when the zone setting is applied Adjusting the setting by Z1ANG allows the resistive reach to be parallel with the line angle as shown in F...

Page 459: ...resistance blinders are parallel to the line characteristic impedance Z1L1 for which the angle is setting Z1ANG Equation 6 72 Rearrange Equation 6 72 and multiply by a safety factor of 90 percent to calcu late R1R7 Equation 6 73 R1R7 15 53 Zone 7 Resistance Right 0 05 140 secondary where A 45 90 Z1ANG b ZL min c setting R1R7 Figure 6 30 Calculating Setting R1R7 A cos c b 4 5 R X b a c O P A ZIL1 B...

Page 460: ...7 right hand resistance blinders NOTE The value for X1T7 must be at least 0 1 greater than that for X1T6 Equation 6 75 X1T7 21 29 Zone 7 Reactance Top 0 05 140 secondary Out of Step Block Time Delay When the Z1 impedance locus initially moves inside Zone 7 the relay starts the OSBD out of step block time delay timer The Z1 impedance trajectory is shown in Figure 6 31 for the case of EA EB EA is th...

Page 461: ...d line represents the trajectory of the power swing perpendicular to line section AB The trajectory passes through the midpoint of line section AB Equation 6 76 Equation 6 77 Figure 6 31 Swing Trajectory to Determine the OSBD Setting where ZT transfer impedance Z1S positive sequence source impedance Z1L1 positive sequence impedance for Line 1 Z1R positive sequence remote impedance B A Minimum Load...

Page 462: ...r swing impedance locus moves outside of Zone 7 and before it comes back inside Zone 7 on its next swing cycle If latched the OSB logic resets one second after the power system stops the out of step Latching the OSB gives you an advantage in that the relay can successfully block uncontrolled distance element operations if a fault occurs when the unstable swing impedance is outside of Zone 7 Relay ...

Page 463: ...nce impedance resides between these blinders for a specific duration OSB logic unblocks The relay calculates this duration UBOSBD each time the power swing enters Zone 7 A short timer setting is adequate for fast swings but the relay needs a longer timer setting for slow power swings For example if the positive sequence impedance passes gradually between the two inner blinders during a slow swing ...

Page 464: ...g for phase distance elements other than Zone 1 elements during unbalanced faults The 50QUBP setting is an advanced setting and must be coordinated with the dis tance protection for the protected line Setting UBD is also an advanced setting set the UBD timer to coordinate clearing times with protection external to the protected line For out of step unblocking on unbalanced faults you must do the f...

Page 465: ...tting the SEL 421 for out of step blocking Analyze your particular power system to determine the appropriate settings for your application Relay Settings Table 6 33 lists the settings that the relay automatically calculates and hides when you set EADVS to N and EOOST to N Table 6 34 and Table 6 35 list the protective relay settings available in this example Table 6 33 Automatically Calculated Hidd...

Page 466: ...ock Zone 1 Y N Y OOSB2 Block Zone 2 Y N Y OOSB3 Block Zone 3 Y N N OSBD Out of Step Block Time Delay 0 500 8000 cycles 1 875 OSBLTCH Latch Out of Step Blocking Y N Y EOOST Out of Step Tripping N I O N X1T7 Zone 7 Reactance Top 0 05 to 140 secondary 21 29 X1T6 Zone 6 Reactance Top 0 05 to 140 secondary 11 52 R1R7 Zone 7 Resistance Right 0 05 to 140 secondary 15 53 R1R6 Zone 6 Resistance Right 0 05 ...

Page 467: ...the settings that the relay automatically calculates and hides when you set EADVS to N You do not need to enable the Advanced Settings for this application example EADVS N Advanced Settings Y N Out of Step Tripping When the positive sequence impedance locus enters Zone 7 both OOS logic tim ers OSBD and OSTD start see Figure 6 33 If OSTD expires before OSBD and Zone 6 asserts the relay declares an ...

Page 468: ...tem collapse Thus the Zone 6 impedance setting differs from Out of Step Blocking on page 6 120 Resistance Blinders If the angle of the power swing Z1 trajectory passes 120 degrees with respect to the transfer impedance the power system cannot recover The transfer impedance is the total impedance of the power system line AB in Figure 6 33 Set the Zone 6 right hand inner resistance blinder R1R6 so A...

Page 469: ...s before the posi tive sequence impedance locus enters Zone 6 The logic declares a tripping con dition if OSTD expires and the positive sequence impedance locus enters Zone 6 prior to OSBD timing out Trip On Way In Trip On Way Out You can select one of two methods to trip during an unstable swing You can enable the relay to trip if OSTD expires and the positive sequence impedance enters Zone 6 thi...

Page 470: ...s of 0 125 cycle round up to the near est valid relay setting OSTD 0 875 Out of Step Trip Delay 0 500 8000 cycles To find the effective slip rate for OOS tripping solve Equation 6 85 for fslip Equation 6 86 where ZT transfer impedance Z1S positive sequence source impedance Z1L1 positive sequence impedance for Line 1 Z1R Positive sequence remote impedance where NOM nominal power system frequency Hz...

Page 471: ...cus crosses Zone 7 and Zone 6 before the OSTD and OSBD timers time out The relay identifies this event as a fault condition Latch Out of Step Blocking Latch out of step blocking to maintain the blocking condition throughout the entire swing cycle OSBLTCH Y Latch Out of Step Blocking Y N Control Outputs For local OOS tripping configure the relay control outputs for tripping and remote notification ...

Page 472: ...ve Sequence Current Supervision 1 00 100 A secondary 50ABCP 0 2 INOM 50QUBP Negative Sequence Current Supervision OFF 0 50 100 A secondary OFF UBD Negative Sequence Current Unblock Delay 0 500 120 cycles 0 500 UBOSBF Out of Step Angle Unblock Rate 1 10 4 Table 6 37 Relay Configuration Group Setting Prompt Entry EOOS Out of Step Y EADVS Advanced Settings Y N N Table 6 38 Out of Step Tripping Blocki...

Page 473: ...ft 0 05 to 140 secondary 5 87 50ABCP Positive Sequence Current Supervision 1 00 100 A secondary 1 00 50QUBP Negative Sequence Current Supervision OFF 0 50 100 A secondary OFF UBD Negative Sequence Current Unblock Delay 0 500 120 cycles 0 500 UBOSBF Out of Step Angle Unblock Rate 1 10 4 50Q1P Level Pickup OFF 0 25 100 Amps sec OFF 67Q1D Level 1 Time Delay 0 000 16000 cycles 0 000 67Q1TC Level 1 Tor...

Page 474: ...t Relay Settings Select the relay settings for this application example Relay Configuration NOTE Setting E79 Y1 is intended for certain double circuit breaker applications Use E79 Y for a single circuit breaker Enable reclosing E79 Y Reclosing Y Y1 N Recloser Closing Select one shot of three pole autoreclose N3PSHOT 1 Number of Three Pole Reclosures N 1 4 Use an external switch to select when Circ...

Page 475: ... equal to 30 cycles 3POID1 30 Three Pole Open Interval 1 Delay 1 99999 cycles There is no need to enable fast three pole autoreclose because we have already used the first and only three pole shot for this purpose 3PFARC NA Three Pole Fast ARC Enable SELOGIC Equation Set the reset time following a three pole autoreclose cycle equal to 900 cycles 3PRCD 900 Three Pole Reclaim Time Delay 1 99999 cycl...

Page 476: ...ing the SEL 421 for one shot of three pole reclosing for a single circuit breaker Analyze your partic ular power system to determine the appropriate settings for your application Relay Settings Table 6 39 provides a list of all the SEL 421 autoreclose settings Those settings that were applied for this particular application appear in boldface Figure 6 36 Potential Sources SEL 421 1 3 Line Disconne...

Page 477: ... 99999 cycles 300 Three Pole Reclose Group 3POID1 Three Pole Open Interval 1 delay 1 99999 cycles 30 3PFARC Three Pole Fast Automatic Reclose Enable SELOGIC Equation NA 3PRCD Three Pole Reclaim Time Delay 1 99999 cycles 900 3PRI Three Pole Reclose Initiation SELOGIC Equation 3PT AND Z1P 79SKP Skip Reclosing Shot SELOGIC Equation NA 3P1CLSa Three Pole BK 1 Reclose Supervision SELOGIC Equation DLLB1...

Page 478: ...osing for both single pole and three pole auto matic reclosing When E79 Y the leader circuit breaker CB1 recloses if the line is dead and Bus 1 is hot If the leader successfully recloses the follower circuit breaker CB2 also attempts a reclose if the synchronism check is successful CB2 can also close if the line is dead and Bus 2 is hot if CB1 is out of service A similar SEL 421 installation would...

Page 479: ... is successful or if Cir cuit Breaker 1 is out of service and the line is dead and Bus 2 is hot Block autoreclose if any of the following events occur Manual trip Time delayed trip Bus trip Circuit breaker failure trip If the SEL 421 detects a loss of potential condition the autoreclose logic drives the autoreclose function to lockout Autoreclose Relay Settings Select the autoreclose relay setting...

Page 480: ...e within 10 seconds after the reclose com mand is received the autoreclose logic goes to lockout for the failed circuit breaker BKCFD 600 Breaker Close Failure Delay OFF 1 99999 cycles You can use a normally closed a auxiliary contact from the Circuit Breaker 1 disconnect switch to denote that this circuit breaker is the leader when in service Use the contact to energize a control input if the dis...

Page 481: ...ose Logic Initiate a single pole autoreclose cycle whenever the SEL 421 single pole trips Autoreclose is blocked if a manual time delayed bus or circuit breaker failure trip occurs None of these events generate a single pole trip see Autoreclose Conditions on page 6 143 Set the single pole open interval time equal to one second SPOID 60 Single Pole Open Interval Delay 1 99999 cycles Set the reclai...

Page 482: ...GIC control equation for this application example 3PRI 3PT AND Z1P OR COMPRM Three Pole Reclose Initiation SELOGIC Equation You can force the autoreclose logic to skip a three pole shot However it is not necessary for this application example 79SKP NA Skip Reclosing Shot SELOGIC Equation Only attempt to reclose Circuit Breaker 1 if Bus 1 is hot and the line is dead The SEL 421 autoreclose logic on...

Page 483: ...threshold for Circuit Breakers 1 and 2 equal to 50 V sec ondary 59BK1P 50 0 Breaker 1 Live Busbar Voltage 1 0 200 V secondary 59BK2P 50 0 Breaker 2 Live Busbar Voltage 1 0 200 V secondary Trip Logic If you want Circuit Breaker 2 to always three pole trip except when Circuit Breaker 2 is the leader program SELOGIC control equation E3PT2 as follows E3PT2 NOT LEADBK2 Breaker 2 3PT SELOGIC Equation Sy...

Page 484: ...sm Check for Breaker 1 Y N Y1 Y2 E25BK2 Y Synchronism Check for Breaker 2 Y N Y1 Y2 Synchronism Check Element Reference Select A Phase voltage from the line source for the synchronism check reference VAY is the reference for the synchronism check because this analog input is con nected to the line potential SYNCP VAY Synch Reference VAY VBY VCY VAZ VBZ VCZ Set the low voltage threshold that superv...

Page 485: ... Breaker 2 ANG2BK2 20 0 Maximum Angle Difference 2 BK2 3 0 80 degrees The relay does not compensate the synchronism check to account for circuit breaker closing time because setting 25SFBK2 is OFF Leave the close time com pensation setting at the default TCLSBK2 1 00 Breaker 2 Close Time 1 00 30 cycles Block the synchronism check if Circuit Breaker 2 is closed BSYNBK2 52AA2 AND 52AB2 AND 52AC2 Blo...

Page 486: ...9 cycles 300 BK2CLSD BK2 Reclose Supervision Delay OFF 1 99999 cycles 300 Single Pole Reclose Group SPOID Single Pole Open Interval Delay 1 99999 cycles 60 SPRCD Single Pole Reclaim Time Delay 1 99999 cycles 900 SPRI Single Pole Reclose Initiation SELOGIC Equation SPT AND Z1G AND COMPRM SP1CLSa Single Pole BK1 Reclose Supervision SELOGIC control equation 1 SP2CLSa Single Pole BK2 Reclose Supervisi...

Page 487: ...age 1 0 200 V secondary 50 0 27BK2P Breaker 2 Dead Busbar Voltage 1 0 200 V secondary 15 0 59BK2P Breaker 2 Live Busbar Voltage 1 0 200 V secondary 50 0 Trip Logic Group E3PT2 Breaker 2 3PT SELOGIC Equation NOT LEADBK2 Relay Configuration Group E25BK1 Synchronism Check for Breaker 1 Y N Y1 Y2 N E25BK2 Synchronism Check for Breaker 2 Y N Y1 Y2 Y Synchronism Check Element Reference Group SYNCP Synch...

Page 488: ...cifies three elements There is one element for each phase A B and C A trip output from the local primary or backup line protection typically initiates the failure to interrupt fault current circuit breaker failure scheme BFI3P1 and BFI 1 for Scheme 1 or BFI 1 for Scheme 2 When initiated the relay starts cir cuit breaker failure timing the time delay is BFPU1 Breaker Failure Time Delay BK1 The SEL ...

Page 489: ...ilosophy is to set the instanta neous overcurrent element 50F 1 to pick up above load current and below the minimum fault current under minimum generation if possible Iload max 50FP1 Iminimum fault Another settings philosophy is to set the threshold to match the line protection sensitivity this increases circuit breaker failure protec tion dependability In the following application examples we use...

Page 490: ...ingle phase breaker failure initiations for example BFIA1 and BFIB1 are asserted Timing Sequence Figure 6 40 and Figure 6 41 illustrate the timing sequence for circuit breaker fail ure schemes Scheme 1 Scheme 1 follows Figure 6 40 Scheme 2 Scheme 2 uses both timing sequences in Figure 6 40 and Figure 6 41 depending on the fault type multiphase fault and single phase fault respectively Figure 6 40 ...

Page 491: ...example for three pole tripping circuit breakers you can also use this scheme for single pole tripping applications For a single pole tripping circuit breaker application example Scheme 2 see Circuit Breaker Failure Protection Example 2 on page 6 161 This example uses a 230 kV power system similar to the system in 230 kV Overhead Distribution Line Example Figure 6 42 shows the SEL 421 at the S ter...

Page 492: ...this application example by no current residual current circuit breaker failure protection see Residual Cur rent Circuit Breaker Failure Protection on page 6 158 This settings philosophy provides security for the circuit breaker failure protection For this power system the maximum load current is 4 95 A secondary and the minimum fault current is 13 0 A secondary 50FP1 120 Iload 120 4 95 A 5 94 A 5...

Page 493: ...rgin from Figure 6 40 Equation 6 89 Use the safety margin result from Equation 6 89 to calculate BFPU1 Equation 6 90 BFPU1 10 000 Breaker Failure Time Delay BK1 0 000 6000 cycles Figure 6 43 Timing Diagram for Setting BFPU1 Scheme 1 Breaker Operate Time tl bk BFPU1 Line Protection Maximum Operate Time Fault Occurs 50FA1 BFI3P1 FBF1 50FA1 Dropout Time t50r Safety Margin Time ts where ts safety marg...

Page 494: ... time delay to zero Disable this fea ture for this application example because this is not a dual circuit breaker scheme BFIDO1 0 000 Breaker Fail Initiate Dropout Delay BK1 0 000 1000 cycles Circuit Breaker Failure Protection Initiation Seal In Delay Set the latch logic circuit breaker failure pickup time delay to zero Disable this feature for this application example Relay Word bit 3PT internall...

Page 495: ...lure Initiate BFIN1 NA No Current Breaker Failure Initiate BK1 SELOGIC Equation Load Current Circuit Breaker Failure Protection Disable load current circuit breaker failure protection for Circuit Breaker BK1 ELCBF1 N Load Current Breaker Failure Logic BK1 Y N Flashover Circuit Breaker Failure Protection Disable flashover current circuit breaker failure protection for Circuit Breaker BK1 EFOBF1 N F...

Page 496: ...terrupt large circuit breaker coil currents There is no TDUR3D 3PT Minimum Trip Duration Time Delay for RT1 the RT1 sig nal can drop out while there is current flowing through the trip coil if the auxil iary circuit breaker contacts have not yet opened OUT101 3PT OUT103 RT1 OUT107 BFTRIP1 Example Completed This completes the application example that describes setting of the SEL 421 for circuit bre...

Page 497: ...ble 6 43 provides the power system parameters Breaker 1 Failure Logic Group 50FP1 Phase Fault Current Pickup BK1 0 50 50 A secondary 5 94 BFPU1 Breaker Failure Time Delay BK1 0 000 6000 cycles 10 000 RTPU1 Retrip Time Delay BK1 0 000 6000 cycles 4 000 BFI3PI Three Pole Breaker Failure Initiate BK1 SELOGIC Equation 3PT BFIA1 A Phase Breaker Failure Initiate BK1 SELOGIC Equation NA BFIB1 B Phase Bre...

Page 498: ...ase fault current pickup greater than maximum load and less than the fault current that flows through Circuit Breaker BK1 IS BK1 Maximum load current IS is 3 25 A secondary Figure 6 45 500 kV Power System for Circuit Breaker Failure Scheme 2 Table 6 43 Secondary Quantities Parameter Value Line impedances Z1L1 Z0L1 3 98 87 6 secondary 14 48 82 1 secondary Source S impedances Z1S Z0S 4 4 88 secondar...

Page 499: ... to set the 50FP1 element for dependability 50FP1 2 10 Phase Fault Current Pickup BK1 0 50 50 A secondary Circuit Breaker Failure Time Delay NOTE This is one method for calculating setting 50FP1 Use your company practices and policies for determining the pickup setting for your particular application BFPU1 Breaker Failure Time Delay BK1 is the time delay on pickup for a circuit breaker trip follow...

Page 500: ...ure 6 40 Equation 6 93 Use the safety margin result from Equation 6 94 to calculate BFPU1 Equation 6 94 BFPU1 10 000 Breaker Failure Time Delay BK1 0 000 6000 cycles Figure 6 47 Timing Diagram for Setting BFPU1 Scheme 2 Breaker Operate Time tl bk BFPU1 SPBFPU1 Line Protection Maximum Operate Time Fault Occurs 50FA1 BFIA1 FBF1 50FA1 Dropout Time t50r Safety Margin Time ts where ts safety margin tt ...

Page 501: ... 6000 cycles A three pole retrip follows a three pole trip The relay should attempt to retrip the protected circuit breaker before a circuit breaker failure trip asserts Apply the default setting for the three pole retrip time delay on pickup RT3PPU1 3 000 Three Pole Retrip Time Delay BK1 0 000 6000 cycles Figure 6 48 compares the complete timing sequence for single pole versus three pole circuit ...

Page 502: ...tion Enable this feature for this application example because you are protecting dual circuit breakers BFIDO1 3 000 Breaker Failure Initiate Dropout Delay BK1 0 000 1000 cycles Circuit Breaker Failure Protection Initiation Seal In Delay Set the circuit breaker failure initiate time delay on pickup for the latch logic to qualify extended circuit breaker failure initiation latch seal in BFISP1 4 000...

Page 503: ...rnally to signal the relay when the circuit breaker failure trip clears the fault successfully BFULTR1 IN104 Breaker Failure Unlatch Trip BK1 SELOGIC Equation Use the same input signal to unlatch the circuit breaker failure trip on Circuit Breaker BK2 Control Outputs Use SELOGIC control equations to assign the control outputs for tripping and retripping Circuit Breaker BK1 and Circuit Breaker BK2 ...

Page 504: ...cation Relay Settings Figure 6 44 lists all protective relay settings applied for this example These set tings are for Circuit Breaker BK1 settings for Circuit Breaker BK2 are similar unless otherwise noted Figure 6 49 Circuit Breaker BK1 DC Connections Two Trip Coils 86 1 86 1 86 1 BFTRIP1 OUT107 DC1 DC2 DC2 DC1 TCA 1 TPA1 OUT101 BK1 TRIP COILS 1 BK1 TRIP COILS 2 TCA 2 52AA1 RTA1 OUT204 TCB 2 52A...

Page 505: ...Breaker Failure Initiate BK1 SELOGIC Equation BFIBT1 OR TPB1 BFIC1 C Phase Breaker Failure Initiate BK1 SELOGIC Equation BFICT1 OR TPC1 BFIDO1 Breaker Fail Initiate Dropout Delay BK1 0 000 1000 cycles 3 000 BFISP1 Breaker Fail Initiate Seal In Delay BK1 0 000 1000 cycles 4 000 ENCBF1 No Current Residual Current Logic BK1 Y N N ELCBF1 Load Current Breaker Failure Logic BK1 Y N N EFOBF1 Flashover Br...

Page 506: ...it breakers followed by the high side MOD at Substation T The SEL 421 Relays replace separate line relays discrete reclosing and synchronism check relays timers latching relays and extensive wiring for this particular example Use the SEL 421 protection freeform SELOGIC control equations in Table 6 48 to automate the following actions at Substation T Restore tapped Substation T to service after a s...

Page 507: ...T with respect to the 230 kV potential is successful for at least four seconds the SEL 421 recloses Circuit Breaker BK1T in five seconds total If the high side MOD is open and the 115 kV system has been energized for at least four seconds the relay recloses Circuit Breaker BK1T in five seconds total Circuit Breaker BK2T If Circuit Breaker BK1T recloses and the synchronism check is successful acros...

Page 508: ...any DTT via MIRRORED BITS communications from any of the two remote 230 kV terminals when the high side MOD is open Low Side Circuit Breaker or Autotransformer Failure The following actions occur if a low side circuit breaker or autotransformer fail ure occurs at Substation T Substation S and R reclose five seconds later Lockout relays at Substation T locks out the high side MOD and low side circu...

Page 509: ...oltage on the 115 kV side and the high side MOD is locked open Recloses Circuit Breaker BK2T five seconds later if there is nominal voltage on the 115 kV side the high side MOD is locked open and Circuit Breaker BK1T reclosed successfully These actions restore station service and low side continuity at Substation T Substation T operates in this configuration until operations or field personnel tak...

Page 510: ...tting Prompt Entry General Global Settings SID Station Identifier Station T RID Relay Identifier SEL 421 NUMBK Number of Breakers in Scheme 2 BID1 Breaker 1 Identifier Circuit Breaker 1 115 kV BID2 Breaker 2 Identifier Circuit Breaker 2 115 kV NFREQ Nominal System Frequency Hz 60 PHROT System Phase Rotation ABC Current and Voltage Source Selection ESS Current and Voltage Source Selection Y LINEI L...

Page 511: ...ees 0 00 25SFBK1 Maximum Slip Frequency BK1 OFF ANG1BK1 Maximum Angle Difference 1 BK1 degrees 20 00 ANG2BK1 Maximum Angle Difference 2 BK1 degrees 20 00 BSYNBK1 Block Synchronism Check BK1 SELOGIC NA Breaker 2 Synchronism Check Group SYNCS2 Synch Source 2 VBZ KS2M Synch Source 2 Ratio Factor 1 00 KS2A Synch Source 2 Angle Shift degrees 0 00 ALTS2 Alternative Synch Source 2 SELOGIC NA 25SFBK2 Maxi...

Page 512: ...sfer trip if MOD closed RMB3A OR RMB3B AND NOT IN103 a This portion of the table shows all of the receive MIRRORED BITS RMBn communications assignments Table 6 47 Group Settings Sheet 2 of 2 Setting Prompt Entry Table 6 48 Protection Freeform SELOGIC Control Equations Sheet 1 of 2 Setting Description Entry Comments PSV01 Protection Comparison 1 PSV01 V1M 119 500 Logical 1 if V1 greater than or equ...

Page 513: ...Protection Counter 1 enable PCN01IN OUT103 Two trips without MOD open PCN02PV Protection Counter 2 preset PCN02PV 2 MOD block close if PCN02R Protection Counter 2 reset PCN02R NOT IN103 PCN02IN Protection Counter 2 enable PCN02IN OUT106 Two closes without MOD closed PCT01PU Protection Conditioning Timer 1 Pickup 240 00 PCT01DO Protection Conditioning Timer 1 Dropout 0 00 PCT01IN Protection Conditi...

Page 514: ...LES 29 PST02R PLT01 30 PST02IN PSV02 AND IN103 31 32 SET SEQUENCING TIMER 3 33 TIMES IF PSV01 IS ASSERTED AND BREAKER 1 AND 2 ARE OPEN 34 RESETS WHEN LATCH 1 IS RESET 35 PST03PT 3600 00 TIMER 3 PICKPUP 3600 CYCLES 36 PST03R NOT PLT01 37 PST03IN PSV01 AND IN101 AND IN102 38 39 SET SEQUENCING TIMER 4 40 TIMES IF PSV01 IS ASSERTED AND BREAKER 1 AND 2 ARE OPEN 41 THE MOD IS OPEN AND LATCH 1 IS NOT SET...

Page 515: ...PCT02PU 240 00 FOUR SECOND PICKUP TIME 72 PCT02DO 0 0 NO DELAY ON DROPOUT 73 PCT02IN NOT IN103 AND 25A1BK2 AND NOT IN101 OR PLT01 AND IN103 AND 59VS2 AND NOT IN101 Figure 6 53 Protection Free Form SELOGIC Control Equations Continued Table 6 49 Control Inputs Input Monitor Condition IN101 115 kV BK1T 52 b contact IN102 115 kV BK2T 52 b contact IN103 230 kV MOD b contact IN104 Circuit breaker and au...

Page 516: ... 6 54 is a logical representation of the freeform protection SELOGIC con trol equations TMB1B Blocking signal Z3P OR Z3G OR DSTRT TMB2B Zone 1 direct underreaching transfer trip Z1P OR Z1G TMB3B Direct transfer trip 86BF or 86T and MOD closed NOT IN103 AND IN104 Table 6 50 Control Outputs SELOGIC Control Equations Sheet 2 of 2 Setting Function Entry ...

Page 517: ...ction Freeform SELOGIC Control Equations V1M 119 500 00 PSV01 V1M 26 500 00 PSV02 IN R PT Q ET PST01 AND OR IN101 PSV02 IN103 IN102 IN101 PSV02 150 IN103 PST01Q IN102 IN R PT Q ET PST02 AND PSV02 IN103 PLT01 780 IN R PV Q CV PCN01 OUT103 IN103 2 IN R PV Q CV PCN02 OUT106 IN103 2 IN R PT Q ET PST03 AND IN101 IN102 PSV01 PLT01 3600 OUT103 AND 120 PCN01Q PST01ET ...

Page 518: ...reeform SELOGIC Control Equations Continued S R PLT01 AND AND PST02Q IN R PT Q ET PST04 AND OR IN101 PSV01 IN103 IN102 IN101 PSV01 330 IN103 PLT01 IN102 PLT01 PST04Q IN PU DO Q PCT01 AND AND OR 25AIBK1 IN103 IN103 PLT01 59VS1 240 0 0 0 AND 300 PST04ET PCN02Q OUT106 IN PU DO Q PCT02 AND OR 59VS2 IN101 PLT01 240 0 0 0 IN103 AND 25AIBK2 IN103 IN101 R_TRIG PST03Q R_TRIG ...

Page 519: ...ction Freeform SELOGIC Control Equations V1M 119 500 PSV01 PSV02 V1M 26 500 OUT103 PST01ET 120 0 R_TRIG IN101 IN102 IN103 IN R PT 150 0 Q ET PST01 PSV02 IN101 IN102 IN103 PSV02 IN R PT 780 PST02 PSV02 IN103 PLT01 IN R PV 2 PCN01 OUT103 IN103 IN R PV 2 PCN02 OUT106 IN103 IN R PT 3600 PST03 PSV01 IN101 IN102 PLT01 S R PLT01 PST02Q PLT01 PLT01 PST03Q PST01Q PCN01Q R_TRIG Q ET Q CV Q CV Q ET ...

Page 520: ... Figure 6 55 Ladder Logic Representation Protection Freeform SELOGIC Control Equations Continued OUT106 PST04ET 300 0 IN101 IN102 IN103 IN R PT 330 Q ET PST04 PSV01 IN101 IN102 IN103 PLT01 PSV01 IN PU 240 0 DO 0 0 Q PCT01 IN103 25AIBK1 PLT01 IN103 59VS1 IN PU 240 0 DO 0 0 Q PCT02 IN103 25AIBK2 IN101 PLT01 IN103 59VS2 IN101 PLT01 PCN02Q PST04Q ...

Page 521: ...ia tions since the last reset Demand metering includes either thermal or rolling analyses of the power system and peak demand metering Energy metering dis plays the megawatt hours imported megawatt hours exported and total mega watt hours Time synchronized metering displays the line voltage and current synchrophasors The SEL 421 processes three sets of current quantities LINE BK1 and BK2 when conf...

Page 522: ...uded RMS phase voltages and currents Real and apparent rms power True power factor Both the fundamental and the rms metered quantities are available for the LINE input The relay also provides both the fundamental and rms circuit breaker cur rents for circuit breakers BK1 and BK2 Table 7 1 MET Command Namea a n is 1 or 2 representing Circuit Breaker 1 and Circuit Breaker 2 respectively Description ...

Page 523: ...condition of the positive power flow convention for example real and reactive power flowing out export is positive and real and reactive power flowing in import is negative see Figure 7 1 For power factor LAG and LEAD refer to whether the current lags or leads the applied voltage The reactive power Q is positive when the voltage angle is greater than the current angle V I which is the case for ind...

Page 524: ... of expected system conditions when monitoring the power factor Relay Word bits SEL does not recommend the use of chattering Relay Word bits in the SER or anything that will trigger an event Figure 7 1 Complex Power P Q Plane Table 7 3 Instantaneous Metering Quantities Power Sheet 1 of 2 Metered Quantity Symbol Fundamental 50 Hz 60 Hz Only RMS Harmonics Included Per phase fundamental real power P ...

Page 525: ...L 400 Series Relays Instruction Manual for a complete description of using and controlling maxi mum minimum metering The SEL 421 provides maximum minimum metering for LINE input rms volt ages rms currents rms powers and frequency it also conveys the maximum minimum rms currents for circuit breakers BK1 and BK2 as well as both dc bat tery voltage maximums and minimums The SEL 421 also records the m...

Page 526: ...tive power 3Q1 Three phase true apparent power 3Urms a Sequence components are maximum values only Table 7 4 Maximum Minimum Metering Quantities Voltages Currents Frequency and Powers Sheet 2 of 2 Metered Quantity Symbol Table 7 5 Demand and Peak Demand Metering Quantities LINE Symbol Units Description I rms A primary Input rms current IGrms a a IG 3I0 IA IB IC A primary Residual ground rms curren...

Page 527: ...Section 9 Reporting in the SEL 400 Series Relays Instruction Manual This section describes reporting characteristics that are unique to the SEL 421 Duration of Data Captures and Event Reports The SEL 421 stores high resolution raw data and filtered data The number of stored high resolution raw data captures and event reports is a function of the quantity of data contained in each capture Table 7 7...

Page 528: ...13 TLED_14 TLED_15 TLED_16 TLED_17 TLED_18 TLED_19 TLED_20 TLED_21 TLED_22 TLED_23 TLED_24 SPOA SPOB SPOC FSA FSB FSC Z1P Z2P Z3P Z4P Z5P Z123PFL 67Q1 67Q2 67Q3 67Q4 51S1 51S2 51S3 Z1G Z2G Z3G Z4G Z5G Z123GFL 67G1 67G2 67G3 67G4 RMBnA TMBnA RMBnB TMBnB ROKA RBADA CBADA LBOKA ROKB RBADB CBADB LBOKB TRIP TPx1 TPx2 52xCL1 52xCL2 BK1CL BK2CL n 1 8 x A B C Table 7 7 Event Report Nonvolatile Storage Cap...

Page 529: ... in Obtaining RMS Phasors From 4 Sam ples Cycle Event Reports on page 9 17 Figure 9 7 on page 9 18 and Figure 9 8 on page 9 20 in the SEL 400 Series Relays Instruction Manual Relay 1 Date 03 15 2001 Time 23 30 49 026 Station A Serial Number 2001001234 FID SEL 421 R101 V0 Z001001 D20010315 Event Number 10007 CID 0x3425 Header Firmware ID in bold Currents Amps Pri Voltages kV Pri IA IB IC IG VA VB V...

Page 530: ...eries Relays Instruction Manual for details In the digital portion of the event report the relay indicates deasserted elements with a period and asserted elements with an asterisk character The element and digital information labels are single character columns Read these columns from top to bottom The trigger row includes a character follow ing immediately after the last digital element column to...

Page 531: ... aligned on the last character For example if the first digital section elements are IN101 RMBA5 Z2P LOKA OUT203 OUT204 and HALARM the header appears as in Figure 7 4 If the Relay Word bits included in the header were assigned aliases the alias names appear in the report 22 B B C 55 F F VZ S 66 66 55 O BBBBBB AA T T MMM ZZZ PL 3333 O5 666 77 666 77 511 Z M KKKKKK 11 RFRF TTT MMMM 234 ZZZZ 234 OOL ...

Page 532: ...nt report shown in Figure 7 3 The sample digital event report shows seven cycles of 4 samples cycle data for a BCG fault that trips a single pole capable circuit breaker In this particular report the mho phase distance elements Z1P and Z2P pick up in the first sample of Cycle 7 The relay asserts the tripping Relay Word bits TPA TPB and TPC when the distance elements operate because of pro gramming...

Page 533: ... 8892 8727 5586 11403 361 421 218 687 214 239 321 083 Fault Data ANG DEG 17 0 167 3 24 8 95 6 94 4 0 1 129 9 126 7 0 7 L C R L C R B B B R B B B R O A A O O A A O K D D K K D D K MB 8 1 RMBA TMBA RMBB TMBB A A A A B B B B TRIG 00000000 00000000 00000000 00000000 0 0 0 0 0 0 0 0 MIRRORED BITS Channel Status Figure 7 5 Summary Section of the Event Report Relay 1 Date 03 15 2001 Time 23 30 49 026 Sta...

Page 534: ...ver indeterminate fault events For example you can trigger an event when there is no fault condition on the power system by using the TRI command In this case when there is no fault the relay reports the event type as TRIG Event History The event history gives you a quick look at recent relay activity The relay labels each new event with a unique number from 10000 to 42767 At 42767 the top of the ...

Page 535: ... history You will also see the display if the fault location enable setting EFLOC is N The event types in the event history are the same as the event types in the event summary see Table 7 10 for event types Figure 7 7 Sample Event History Relay 1 Date 03 16 2001 Time 11 57 27 803 Station A Serial Number 2001001234 DATE TIME EVENT LOCAT CURR GRP TARGETS 10007 03 15 2001 23 30 49 026 BCG T 48 17 88...

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Page 537: ...otection and automation see the examples in Section 6 Protection Applications Examples The section contains informa tion on the following settings classes Alias Settings on page 8 1 Automation Freeform SELOGIC Control Equations on page 8 34 Bay Settings on page 8 39 Breaker Monitor Settings on page 8 9 DNP3 Settings Custom Maps on page 8 39 Front Panel Settings on page 8 35 Global Settings on page...

Page 538: ...ion Table 8 13 Synchronized Phasor Measurement Table 8 14 Time and Date Measurement Table 8 19 Data Reset Controls Table 8 20 DNP Table 8 21 Table 8 3 General Global Settings Setting Prompt Default Value SID Station Identifier 40 characters Station A RID Relay Identifier 40 characters Relay 1 NUMBK Number of Breakers in Scheme 1 2 1 BID1 Breaker 1 Identifier 40 characters Breaker 1 BID2 Breaker 2 ...

Page 539: ...6 for 48 125 Vdc rated power supply and 85 for 125 240 Vdc rated power supply See Control Inputs on page 2 6 for setting guidelines 1 GINDFa c c Setting applies to all direct coupled contact inputs independent of EICIS set to Y or N Input Dropout Level 10 100 of pickup level 80 1 IN1XXDd d Setting applies to all the main board input contacts Main Board Debounce Time 0 0000 5 cyc 0 1250 0 0001 IN2X...

Page 540: ...0 5 cycc 0 1250d 0 0001 IN2mmPUe e mm is the number of available input contacts on the interface board Input IN2mme Pickup Delay 0 0000 5 cycc 0 1250d 0 0001 IN2mmDOe Input IN2mme Dropout Delay 0 0000 5 cycc 0 1250d 0 0001 Table 8 9 Interface Board 2 Control Inputs Setting Prompt Default Value Increment IN301Pa a Setting is not available for interface boards INT2 INT4 INT7 and INT8 Set to Global s...

Page 541: ... VCY VAZ VBZ VCZ VAY VF02 Local Frequency Source 2 ZERO VAY VBY VCY VAZ VBZ VCZ VBY VF03 Local Frequency Source 3 ZERO VAY VBY VCY VAZ VBZ VCZ VCY VF11 Alternate Frequency Source 1 ZERO VAY VBY VCY VAZ VBZ VCZ ZERO VF12 Alternate Frequency Source 2 ZERO VAY VBY VCY VAZ VBZ VCZ ZERO VF13 Alternate Frequency Source 3 ZERO VAY VBY VCY VAZ VBZ VCZ ZERO Table 8 12 Time Error Calculation Setting Prompt ...

Page 542: ...Settings Setting Prompt Default MFRMT Message Format C37 118 FM C37 118 MRATEa a Only available in MFRMT C37 118 Messages per Second 1 2 4 5 10 12 15 20 30 60 b b If NFREQ 50 then the range is 1 2 5 10 25 50 2 PMAPP PMU Application F N 1 c c Option 1 is available only if MRATE 60 N PMLEGCYa Synchrophasor Legacy Settings Y N N NUMPHDCa d d Only available if PMLEGCY N Number of Data Configurations 1...

Page 543: ...sor Digitals in Data Configuration q Maximum 64 Digitals Relay Word Bit Name or Alias This is a freeform setting category with one argument Specify the Relay Word bit name or its alias that you need to include in the synchrophasor data stream q See Section 11 Relay Word Bits for a list of Relay Word bits that the PMU sup ports You can configure the PMU for as many as 64 unique digitals for each da...

Page 544: ... 15 5 8 BEG_DSTc c The BEG_DST and END_DST daylight saving time setting consists of four fields or OFF hh local time hour 0 23 defines when daylight saving time begins n the week of the month when daylight saving time begins 1 3 L occurs in either the 1st 2nd 3rd or last week of the month d day of week 1 7 Sunday is the first day of the week mm month 1 12 OFF hides the daylight saving time setting...

Page 545: ...8 Breaker 1 Mechanical Operating Time and Breaker 2 Mechanical Operating Time Table 8 29 Breaker 1 Pole Scatter and Pole Discrepancy and Breaker 2 Pole Scatter and Pole Discrepancy Table 8 30 Breaker 1 Inactivity Time Elapsed and Breaker 2 Inactivity Time Elapsed Table 8 31 Breaker 1 Motor Running Time Breaker 2 Motor Running Time Table 8 32 Breaker 1 Current Interrupted Breaker 2 Current Interrup...

Page 546: ...er 2 settings Prompt Default Value BM1TRPA Breaker Monitor Trip BK1 SELOGIC Equation b b This setting for three pole trip applications when setting BK1TYP 3 TPA1 BM1TRPA Breaker Monitor A Phase Trip BK1 SELOGIC Equation c c This setting for single pole trip applications when setting BK1TYP 1 TPA1 BM1TRPB Breaker Monitor B Phase Trip BK1 SELOGIC Equation c BM1TRPA BM1TRPC Breaker Monitor C Phase Tr...

Page 547: ...r 2 settings Prompt Default Value B1PSTRT Pole Scatter Trip Alarm Threshold BK1 1 999 ms 20 B1PSCLT Pole Scatter Close Alarm Threshold BK1 1 999 ms 20 B1PDD Pole Discrepancy Time Delay BK1 1 9999 ms 1400 E1PDCS Pole Discrepancy Current Supervision BK1 Y N N Table 8 31 Breaker 1 Inactivity Time Elapsed and Breaker 2 Inactivity Time Elapsed Setting a a Replace 1 with 2 in the setting and prompt for ...

Page 548: ...esidual Ground Instantaneous Overcurrent Pickup Table 8 52 Residual Ground Definite Time Overcurrent Time Delay Table 8 53 Residual Ground Instantaneous Definite Time Overcurrent Torque Control Table 8 54 Negative Sequence Instantaneous Overcurrent Pickup Table 8 55 Negative Sequence Definite Time Overcurrent Time Delay Table 8 56 Negative Sequence Instantaneous Definite Time Overcurrent Torque Co...

Page 549: ...W secondary 5 A 0 25 1275 W secondary 1 A 7 80 39 00 0 01 Z1ANG Positive Sequence Line Impedance Angle 5 00 90 degrees 84 00 84 00 0 01 Z0MAG Zero Sequence Line Impedance Magnitude 0 05 255 W secondary 5 A 0 25 1275 W secondary 1 A 24 80 124 00 0 01 Z0ANG Zero Sequence Line Impedance Angle 5 00 90 degrees 81 50 81 50 0 01 EFLOC Fault Location Y N Y Y LL Line Length 0 10 999 100 00 100 00 0 01 Tabl...

Page 550: ...COMM Communications Assisted Tripping N DCB POTT POTT2 POTT3 DCUB1 DCUB2 POTT EBFL1 Breaker 1 Failure Logic N 1 2 Y1 Y2 N EBFL2 Breaker 2 Failure Logic N 1 2 Y1 Y2 N E25BK1 Synchronism Check for Breaker 1 Y N Y1 Y2 N E25BK2 Synchronism Check for Breaker 2 Y N Y1 Y2 N E79 Reclosing Y Y1 N Y EMANCL Manual Closing Y N Y ELOP Loss of Potential Y Y1 N Y1 EDEM Demand Metering N THM ROL N VMEMCa Memory V...

Page 551: ...8 Quadrilateral Phase Distance Element Reach Sheet 1 of 2 Setting Prompt Default Value Increment 5 A 1 A XP1 Zone 1 Reactance ohms secondary OFF 0 05 64 secondary 5 A OFF 0 25 320 secondary 1 A OFF OFF 0 01 RP1 Zone 1 Resistance ohms secondary OFF 0 05 50 secondary 5 A OFF 0 25 250 secondary 1 A 12 48 62 40 0 01 XP2 Zone 2 Reactance ohms secondary OFF 0 05 64 secondary 5 A OFF 0 25 320 secondary 1...

Page 552: ...rompt Default Value Increment Z1PD Zone 1 Time Delay OFF 0 000 16000 cycles 0 000 0 125 Z2PD Zone 2 Time Delay OFF 0 000 16000 cycles 20 000 0 125 Z3PD Zone 3 Time Delay OFF 0 000 16000 cycles 60 000 0 125 Z4PD Zone 4 Time Delay OFF 0 000 16000 cycles OFF 0 125 Z5PD Zone 5 Time Delay OFF 0 000 16000 cycles OFF 0 125 Table 8 40 Mho Ground Distance Element Reach Setting Prompt Default Value Incremen...

Page 553: ... 0 01 RG2 Zone 2 Resistance 0 05 50 secondary 5 A 0 25 250 secondary 1 A 18 72 93 6 0 01 XG3 Zone 3 Reactance OFF 0 05 64 secondary 5 A OFF 0 25 320 secondary 1 A OFF OFF 0 01 RG3 Zone 3 Resistance 0 05 50 secondary 5 A 0 25 250 secondary 1 A 3 64 18 2 0 01 XG4 Zone 4 Reactance OFF 0 05 64 secondary 5 A OFF 0 25 320 secondary 1 A OFF OFF 0 01 RG4 Zone 4 Resistance 0 05 150 secondary 5 A 0 25 750 s...

Page 554: ... k0A1 Zone 1 Zero Sequence Compensation Factor Angle 180 0 to 180 0 degrees 3 69 0 01 k0Ma a Setting only available when Group setting EADVS Y Forward Zones Zero Sequence Compensation Factor Magnitude 0 000 10 0 726 0 001 k0Aa Forward Zones Zero Sequence Compensation Factor Angle 180 0 to 180 0 degrees 3 69 0 01 k0MRa Reverse Zones Zero Sequence Compensation Factor Magnitude 0 000 10 0 726 0 001 k...

Page 555: ...F 0 000 16000 cycles OFF 0 125 SOTFD Switch Onto Fault Enable Duration 0 500 16000 cycles 10 000 0 125 CLSMON Close Signal Monitor SELOGIC Equation NA Table 8 47 Out of Step Tripping Blocking Sheet 1 of 2 Setting Prompt Default Value Increment 5 A 1 A OOSB1 Block Zone 1 Y N Y Y OOSB2 Block Zone 2 Y N Y Y OOSB3 Block Zone 3 Y N Y Y OOSB4 Block Zone 4 Y N N N OOSB5 Block Zone 5 Y N N N OSBD Out of S...

Page 556: ...e Current Supervision OFF 0 50 100 A secondary 5 A OFF 0 10 20 A secondary 1 A OFF OFF 0 01 UBDa Negative Sequence Current Unblock Delay 0 500 120 cycles 0 500 0 500 0 125 UBOSBFa Out of Step Angle Unblock Rate 1 10 4 4 1 OOSPSC Number of Pole Slips Before Tripping 1 10 1 1 1 a Setting only available when Group setting EADVS Y Table 8 48 Load Encroachment Setting Prompt Default Value Increment 5 A...

Page 557: ...1 50P2P Level 2 Pickup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 50P3P Level 3 Pickup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 50P4P Level 4 Pickup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 Table 8 50 Phase Definite Time Overcurrent Time Delay Setting Prompt Default Value Increment 67P1D Level 1 Time Delay 0 000 1...

Page 558: ...p OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 50G2P Level 2 Pickup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 50G3P Level 3 Pickup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 50G4P Level 4 Pickup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 Table 8 53 Residual Ground Definite Time Overcurrent Ti...

Page 559: ...ckup OFF 0 25 100 A secondary 5 A OFF 0 05 20 A secondary 1 A OFF OFF 0 01 Table 8 56 Negative Sequence Definite Time Overcurrent Time Delay Setting Prompt Default Value Increment 67Q1D Level 1 Time Delay 0 000 16000 cycles 0 000 0 125 67Q2D Level 2 Time Delay 0 000 16000 cycles 0 000 0 125 67Q3D Level 3 Time Delay 0 000 16000 cycles 0 000 0 125 67Q4D Level 4 Time Delay 0 000 16000 cycles 0 000 0 ...

Page 560: ... ICn IMAXn I1L 3I2L 3I0n a a Parameter n L for line 1 for BK1 2 for BK2 3I2L 3I2L 51S2P 51S2 Overcurrent Pickup 0 25 16 A secondary 5 A 0 05 3 2 A secondary 1 A 5 00 1 00 51S2C 51S2 Inverse Time Overcurrent Curve U1 U5 US C1 C5 IEC U3 U3 51S2TD 51S2 Inverse Time Overcurrent Time Dial 0 50 15 00 0 05 1 00 IEC 1 0 1 0 51S2RS 51S2 Inverse Time Overcurrent Electromagnetic Reset Y N N N 51S2TCb b This ...

Page 561: ...is 1 E81 Level n Pickup 40 01 69 99 Hz 61 81DnDa Level n Time Delay 0 04 400 s 2 Table 8 62 Under Voltage 27 Element ea a Where e is 1 E27 Setting Prompt Default Value 27Oe Under Voltage e Operating Quantity V1F1M 27PeP1 Under Voltage e Level 1 Pickup 2 00 300 V sec 20 27TCe Under Voltage e Torque Control SELOGIC Equation 1 27PeD1 Under Voltage e Level 1 Delay 0 00 16000 cycles 10 27PeP2 Under Vol...

Page 562: ...A 0 25 0 05 0 01 Z2Fa Forward Directional Z2 Threshold 64 00 to 64 00 secondary 5 A 320 00 to 320 00 secondary 1 A 0 30 1 50 0 01 Z2Ra Reverse Directional Z2 Threshold 64 00 to 64 00 secondary 5 A 320 00 to 320 00 secondary 1 A 0 30 1 50 0 01 a2a Positive Sequence Restraint Factor I2 I1 0 02 0 50 0 10 0 10 0 01 k2a Zero Sequence Restraint Factor I2 I0 0 10 1 20 0 20 0 20 0 01 Z0Fa Forward Directio...

Page 563: ...2 000 0 125 EDURD Echo Duration Time Delay 0 000 16000 cycles 4 000 0 125 EWFC Weak Infeed Trip Y N SP N 27PWI Weak Infeed Phase Undervoltage Pickup 1 0 200 V secondary 47 0 1 27PPW Weak Infeed Phase to Phase Undervoltage Pickup 1 0 300 V secondary 80 0 1 59NW Weak Infeed Zero Sequence Overvoltage Pickup 1 0 200 V secondary 5 0 1 PT1 General Permissive Trip Received SELOGIC Equation IN102 AND PLT0...

Page 564: ...0 6000 cycles 3 000 3 000 0 125 RT3PPU1b Three Pole Retrip Time Delay BK1 0 000 6000 cycles 3 000 3 000 0 125 BFI3P1 Three Pole Breaker Failure Initiate BK1 SELOGIC Equation NA NA BFIA1 A Phase Breaker Failure Initiate BK1 SELOGIC Equation NA NA BFIB1 B Phase Breaker Failure Initiate BK1 SELOGIC Equation NA NA BFIC1 C Phase Breaker Failure Initiate BK1 SELOGIC Equation NA NA BFIDO1 Breaker Fail In...

Page 565: ...Value Increment 5 A 1 A Table 8 71 Synchronism Check Element Reference Setting Prompt Default Value Increment SYNCP Synchronism Reference VAY VBY VCY VAZ VBZ VCZ VAY 25VL Voltage Window Low Threshold 20 0 200 V secondary 55 0 0 1 25VH Voltage Window High Threshold 20 0 200 V secondary 70 0 0 1 Table 8 72 Breaker 1 Synchronism Check Setting Prompt Default Value Increment SYNCS1 Synchronism Source 1...

Page 566: ...etting TCLSBK2 in 0 25 cycle steps Table 8 74 Recloser and Manual Closinga Sheet 1 of 2 Setting Prompt Default Value Increment NSPSHOT Number of Single Pole Reclosures N 1 2 N ESPR1 Single Pole Reclose Enable BK1 SELOGIC Equation NA ESPR2 Single Pole Reclose Enable BK2 SELOGIC Equation NA N3PSHOT Number of Three Pole Reclosures N 1 4 2 E3PR1 Three Pole Reclose Enable BK1 SELOGIC Equation PLT06 E3P...

Page 567: ...Single Pole Open Interval Supervision Delay OFF 1 99999 cycles 1 1 SPOID Single Pole Open Interval Delay 1 99999 cycles 60 1 SPRCD Single Pole Reclaim Time Delay 1 99999 cycles 900 1 SPRI Single Pole Reclose Initiation SELOGIC Equation SPT SP1CLS Single Pole BK1 Reclose Supervision SELOGIC Equation b 1 SP2CLS Single Pole BK2 Reclose Supervision SELOGIC Equation b 1 Table 8 76 Three Pole Reclose Se...

Page 568: ...ents Setting Prompt Default Value Increment EVCK Reclosing Voltage Check Y N N 27LP Dead Line Voltage 1 0 200 V secondary 14 0 0 1 59LP Live Line Voltage 1 0 200 V secondary 53 0 0 1 27BK1P Breaker 1 Dead Busbar Voltage 1 0 200 V secondary 14 0 0 1 59BK1P Breaker 1 Live Busbar Voltage 1 0 200 V secondary 53 0 0 1 27BK2P Breaker 2 Dead Busbar Voltage 1 0 200 V secondary 14 0 0 1 59BK2P Breaker 2 Li...

Page 569: ...Fault Trip SELOGIC Equation 50P1 OR Z2P OR Z2G DTA Direct Transfer Trip A Phase SELOGIC Equation NA DTB Direct Transfer Trip B Phase SELOGIC Equation NA DTC Direct Transfer Trip C Phase SELOGIC Equation NA BK1MTR Breaker 1 Manual Trip BK1 SELOGIC Equation 8 pushbuttons OC1 OR PB8_PUL 12 pushbuttons OC1 OR PB12PUL 12 pushbuttons and auxiliary TRIP CLOSE pushbuttons OC1 BK2MTR Breaker 2 Manual Trip ...

Page 570: ...0 Series Relays Instruction Manual for a description of automation SELOGIC control equations The SEL 421 4 supports a single block of 100 lines the SEL 421 5 supports 10 blocks of 100 lines Notes Settings Use the Notes settings like a text pad to leave notes about the relay in Notes area of the relay See Notes Settings on page 12 24 in the SEL 400 Series Relays Instruction Manual for additional in...

Page 571: ...ble 8 82 Main Board Default Values Setting Default Value OUT101 3PT OR TPA1 AND NOT PLT04 THREE POLE TRIP OUT102 3PT OR TPA1 AND NOT PLT04 THREE POLE TRIP OUT103 BK1CL AND NOT PLT04 BREAKER CLOSE COMMAND OUT104 KEY AND PLT02 AND NOT PLT04 KEY TX OUT105 NA OUT106 NA OUT107 PLT04 RELAY TEST MODE OUT108 NOT SALARM OR HALARM Table 8 83 Front Panel Settings Defaults Sheet 1 of 4 Setting Default Value F...

Page 572: ...LED_3 T1LEDL Y T1LEDC RO T2_LED Z2PT OR Z2GT OR Z3PT OR Z3GT OR Z4PT OR Z4GT AND NOT TLED_1 OR TLED_3 OR TLED_4 T2LEDL Y T2LEDC RO T3_LED COMPRM AND NOT Z1P OR Z1G OR TLED_1 OR SOTFT T3LEDL Y T3LEDC RO T4_LED SOTFT T4LEDL Y T4LEDC RO T5_LED Z1P OR Z1G AND NOT TLED_6 OR TLED_7 OR TLED_8 T5LEDL Y T5LEDC RO T6_LED Z2P OR Z2G AND NOT Z1P OR Z1G OR TLED_5 T6LEDL Y T6LEDC RO T7_LED Z3P OR Z3G AND NOT Z1...

Page 573: ...3 OR 50G4 T13LEDL Y T13LEDC RO T14_LED 51S1T OR 51S2T OR 51S3T T14LEDL Y T14LEDC RO T15_LED BK1RS T15LEDL N T15LEDC RO T16_LED BK1LO T16LEDL N T16LEDC RO T17_LEDb 79CY1 OR 79CY3 T17LEDLb N T17LEDCb RO T18_LEDb 25A1BK1 T18LEDLb N T18LEDCb RO T19_LEDb BK1CL T19LEDLb N T19LEDCb RO T20_LEDb BFTRIP1 T20LEDLb N T20LEDCb RO T21_LEDb OSB T21LEDLb N T21LEDCb RO T22_LEDb LOP T22LEDLb N T22LEDCb RO T23_LEDb ...

Page 574: ...1 67Q2 67Q3 67Q4 51S1 51S2 51S3 Z1G Z2G Z3G Z4G Z5G 67G1 67G2 67G3 67G4 RMBnA TMBnA RMBnB TMBnB ROKA RBADA CBADA LBOKA ROKB RBADB CBADB LBOKB TRIP TP 1 TP 2 52 CL1 52 CL2 BK1CL BK2CL n 1 8 A B C For row descriptions see Section 11 Relay Word Bits Port Settings The SEL 421 port settings are as described in Port Settings on page 12 6 in the SEL 400 Series Relays Instruction Manual The fast message r...

Page 575: ...Lya 523_ALM NA DrHMINc Disconnect m HMI Name max 17 pixels 3 4 characters d SW m DrCTLNc Disconnect m Control Scr Name max 15 char d BB m 89AMrc Disconnect m N O Contact SELOGIC Equation d 1 89BMrc Disconnect m N C Contact SELOGIC Equation d 0 89ALPrc Disconnect m Alarm Pickup Delay 1 99999 cyc d 300 89CCNrc Dis m Remote Close Control SELOGIC Equation d 89CCr 89OCNrc Dis m Remote Open Control SELO...

Page 576: ...ion Manual Date Code 20171021 Settings Bay Settings MDSCAne Scale Format s 1 LOCAL Local Control SELOGIC Equation PLT06 a y 1 3 b z 1 2 c r 01 10 d m 1 10 e n 1 24 Table 8 85 Bay Settings Sheet 2 of 2 Setting Prompt Default Value ...

Page 577: ...riables that you determine based on the application for example circuit breaker number n 1 or 2 remote bit number nn 01 32 and level Command options appear with brief explanations about the command function Refer to the references listed with the commands for more information on the relay function corresponding to the command or examples of the relay response to the command You can simplify the ta...

Page 578: ...2 CAL CAL on page 14 5 CASCII CASCII on page 14 5 CBREAKER CBREAKER on page 14 6 The SEL 421 supports two circuit breakers designated 1 and 2 CEVENT CEVENT on page 14 6 In the SEL 421 CEV L provides an 8 samples cycle large resolution event report CFG CTNOM i CFG CTNOM on page 14 10 In the SEL 421 the nominal current choices are 1 and 5 for 1 A nom inal and 5 A nominal CT inputs CFG NFREQ f CFG NF...

Page 579: ...ge 14 41 MET SYN See MET SYN on page 9 5 in this section MET T MET T on page 14 41 OACCESS OACCESS on page 14 41 OPEN n OPEN n on page 14 42 The SEL 421 supports two circuit breakers designated 1 and 2 PACCESS PACCESS on page 14 42 PASSWORD PASSWORD on page 14 42 PING PING on page 14 43 PORT PORT on page 14 44 PROFILE PROFILE on page 14 45 PULSE PULSE on page 14 45 QUIT QUIT on page 14 46 RTC RTC ...

Page 580: ...ring data Specify Circuit Breaker 1 and Circuit Breaker 2 by using the BK1 and BK2 command options respectively Some situations require that you repeatedly monitor the power system for a brief period specify a number after any MET command to automatically repeat the command TEST DB2 TEST DB2 on page 14 56 TEST FM TEST FM on page 14 57 TIME TIME on page 14 59 TRIGGER TRIGGER on page 14 61 VECTOR VE...

Page 581: ...unction the relay responds with Synchronism Check Element Is Not Available Enable synchronism check with the Global settings E25BK1 E25BK2 and NUMBK see Synchronism Check on page 5 158 Table 9 3 MET E Command Command Description Access Level MET E Display Line energy metering data 1 B P A O 2 MET E k Display Line energy metering data successively for k times 1 B P A O 2 MET RE Reset Line energy me...

Page 582: ...ings beginning at the first setting in this class for instance 1 P A O 2 SET D instance Set the DNP3 remapping settings beginning at the first setting of instance P A O 2 SET F Set the front panel relay settings beginning at the first set ting in this class P A O 2 SET G Set the Global relay settings beginning at the first setting in this class P A O 2 SET La Set the Protection SELOGIC control equ...

Page 583: ... P A O 2 SHO D instance Show the DNP3 remapping settings for instance P A O 2 SHO F Show the front panel relay settings beginning at the first setting in this class 1 B P A O 2 SHO G Show the Global relay settings beginning at the first setting in this class 1 B P A O 2 SHO La Show the Protection SELOGIC control equation relay settings for the active group 1 B P A O 2 SHO L na Show the Protection ...

Page 584: ...This page intentionally left blank ...

Page 585: ...cribed in Table 10 1 Use the MAP and VIEW commands to display maps and contents of the database regions See Section 9 ASCII Command Reference for more information on the MAP and VIEW commands Data within the regions are available for access by external devices via the SEL Fast Message protocol The LOCAL region contains the device FID SID and RID It will also provide appropriate status points This ...

Page 586: ...or okay 1 for failure Table 10 3 SEL 421 Database Structure METER Region Sheet 1 of 3 Address Hex Name Type Description 1000 _YEAR int 4 digit year when data were sampled 1001 DAY_OF_YEAR int 1 366 day when data were sampled 1002 TIME ms long int Time of day in ms when data were sampled 0 86 400 00 1004 FREQ float System frequency 1006 VDC1 float Battery 1 voltage 1008 VDC2 float Battery 2 voltage...

Page 587: ...lip with respect to VP in HZ 105C ANG2_DIF float VS2 and VP angle difference in degrees 105E VS2_SLIP float VS2 frequency slip with respect to VP in HZ 1060 PA float A Phase real power 1062 PB float B Phase real power 1064 PC float C Phase real power 1066 P float Total real power 1068 QA float A Phase reactive power 106A QB float B Phase reactive power 106C QC float C Phase reactive power 106E Q f...

Page 588: ...nt 200C I2 float 2 sequence demand current 200E PA float A Phase demand real power 2010 PB float B Phase demand real power 2012 PC float C Phase demand real power 2014 P float Total demand real power 2016 SA float A Phase demand apparent power 2018 SB float B Phase demand apparent power 201A SC float C Phase demand apparent power 201C S float Total demand apparent power 201E PK_IA float A Phase de...

Page 589: ...sampled 3002 TIME ms long int Time of day in ms when data were sampled 0 86 400 000 3004 TARGET char 240 Entire Relay Word with bit labels Table 10 6 SEL 421 Database Structure HISTORY Region Address Hex Name Type Description 4000 _YEAR int Four digit year when data were sampled 4001 DAY_OF_YEAR int 1 366 day when data were sampled 4002 TIME ms long int Time of day in ms when data were sample 0 86...

Page 590: ...C Phase accumulated current kA 5016 CURA2 float Breaker 2 A Phase accumulated current kA 5018 CURB2 float Breaker 2 B Phase accumulated current kA 501A CURC2 float Breaker 2 C Phase accumulated current kA 501C NOPA1 long int Breaker 1 A Phase number of operations 501E NOPB1 long int Breaker 1 B Phase number of operations 5020 NOPC1 long int Breaker 1 C Phase number of operations 5022 NOPA2 long in...

Page 591: ...t 5 Volt power supply voltage 6025 PS_N5 V float 5 Volt regulated voltage 6027 PS15 V float 15 Volt power supply voltage 6029 PS_N15 V float 15 Volt power supply voltage 602B PS_WARN char 8 Power supply warning string 6033 PS_FAIL char 8 Power supply failure string 603B HW_FAIL char 40 Hardware failure strings 6063 CC_STA char 40 Comm card status strings 608B PORT_STA char 160 Serial port status s...

Page 592: ...nt TIME ms 1002h int 2 FREQ 1004h float VDC1 1006h float VDC2 1008h float IA1 100ah float 2 IB1 100eh float 2 IC1 1012h float 2 I0_1 1016h float 2 I1_1 101ah float 2 I2_1 101eh float 2 IA2 1022h float 2 IB2 1026h float 2 IC2 102ah float 2 IA3 102eh float 2 IB3 1032h float 2 IC3 1036h float 2 VA 103ah float 2 VB 103eh float 2 VC 1042h float 2 V0 1046h float 2 V1 104ah float 2 V2 104eh float 2 VP 10...

Page 593: ...1 02 LDATPFW Leading true power factor A Phase Terminal W 1 if leading 0 if lagging or zero 01 02 LDBTPFW Leading true power factor B Phase Terminal W 1 if leading 0 if lagging or zero 01 02 LDCTPFW Leading true power factor C Phase Terminal W 1 if leading 0 if lagging or zero 01 02 LD3TPFW Leading true power factor three phase Terminal W 1 if leading 0 if lagging or zero 01 02 Relay Word Relay Wo...

Page 594: ...eaker 2 B Phase 20 22 BKR2OPC Number of breaker operations on Circuit Breaker 2 C Phase 20 22 ACN01CV ACN32CV Automation SELOGIC Counter value 1 32 20 22 PCN01CV PCN32CV Protection SELOGIC Counter value 1 32 20 22a b KWHAOUT Positive A Phase energy export kWh 20 22a b KWHBOUT Positive B Phase energy export kWh 20 22a b KWHCOUT Positive C Phase energy export kWh 20 22a b KWHAIN Negative A Phase ene...

Page 595: ... reactive power in MVAR 30 32 QB_Fe B Phase reactive power in MVAR 30 32 QC_Fe C Phase reactive power in MVAR 30 32 3Q_Fe Three phase reactive power in MVAR 30 32 SA_Fe A Phase apparent power in MVA 30 32 SB_Fe B Phase apparent power in MVA 30 32 SC_Fe C Phase apparent power in MVA 30 32 3S_Fe Three phase apparent power in MVA 30 32 DPFAf A Phase power factor 30 32 DPFBf B Phase power factor 30 32...

Page 596: ...power MW 30 32 3QDe Three phase demand reactive power MW 30 32 UAD UBD UCDe A Phase B Phase and C Phase demand apparent power MW 30 32 3UDe Three phase demand apparent power MW 30 32 MWHAIN MWHAOUTe A Phase total energy in and out MWh 30 32 MWHBIN MWHBOUTe B Phase total energy in and out MWh 30 32 MWHCIN MWHCOUTe C Phase total energy in and out MWh 30 32 MWHATc Total A Phase energy MWh 30 32 MWHBT...

Page 597: ...single pole recloses 30 32 SHOT1_2g Total number of 2nd shot single pole recloses 30 32 SHOT1_Tg Total number of single pole reclosing shots issued 30 32 SHOT3_1g Total number of 1st shot three pole recloses 30 32 SHOT3_2g Total number of 2nd shot three pole recloses 30 32 SHOT3_3g Total number of 3rd shot three pole recloses 30 32 SHOT3_4g Total number of 4th shot three pole recloses 30 32 SHOT3_...

Page 598: ...ECPLM and dead band ANADBM f Default scale factor of 100 and dead band ANADBM g Default scale factor of 1 and dead band ANADBM h Event data shall be generated for all Event Summary Analog Inputs if any of them change beyond their dead band after scaling i Default dead band of 0 j In milliseconds 30000 time 30000 Relay Word bit PLDTE asserts for approximately 1 5 cycles after this value is written ...

Page 599: ...Reset min max meter data for breaker 1 No action Reset min max meter data for breaker 1 No action RSTMMB2 Reset min max meter data for breaker 2 Reset min max meter data for breaker 2 Reset min max meter data for breaker 2 No action Reset min max meter data for breaker 2 No action RST_BK1 Reset breaker monitor 1 data Reset breaker monitor 1 data Reset breaker monitor 1 data No action Reset breaker...

Page 600: ... phase fault will set bits 0 1 and 2 for a decimal value of 7 If this event caused a trip the upper byte would also have bit 2 set for a total decimal value of 1031 0407 in hexadecimal Default Data Map Table 10 14 shows the SEL 421 default DNP3 data map The default data map is an automatically generated subset of the reference map All data maps are initial ized to the default values If the default...

Page 601: ...Circuit Breaker 2 Pole B status 01 02 23 52AC2 Circuit Breaker 2 Pole C status 01 02 24 52AAL2 Circuit Breaker 2 Pole A alarm 01 02 25 52BAL2 Circuit Breaker 2 Pole B alarm 01 02 26 52CAL2 Circuit Breaker 2 Pole C alarm 01 02 27 TLED_1 Front panel target LED 1 01 02 28 TLED_2 Front panel target LED 2 01 02 29 TLED_3 Front panel target LED 3 01 02 30 TLED_4 Front panel target LED 4 01 02 31 TLED_5 ...

Page 602: ... 01 02 63 ASV002 Automation SELOGIC Variable 2 01 02 64 ASV003 Automation SELOGIC Variable 3 01 02 65 ASV004 Automation SELOGIC Variable 4 01 02 66 ASV005 Automation SELOGIC Variable 5 01 02 67 ASV006 Automation SELOGIC Variable 6 01 02 68 ASV007 Automation SELOGIC Variable 7 01 02 69 ASV008 Automation SELOGIC Variable 8 01 02 70 OUT101 Main board Output 1 01 02 71 OUT102 Main board Output 2 01 02...

Page 603: ...Reset Breaker 2 monitor data 10 12 61 RSTTRGT Reset front panel targets 10 12 62 RSTMML Reset min max metering data for the line 10 12 63 RSTDNPE Reset clear DNP3 event summary analog inputs Binary Counters 20 22 0 ACTGRP Active settings group 20 22 1 BKR1OPA Number of breaker operations on Circuit Breaker 1 A Phase 20 22 2 BKR1OPB Number of breaker operations on Circuit Breaker 1 B Phase 20 22 3 ...

Page 604: ...magnitude amperes and angle 30 32 18 19 VAFM VAFA Line A Phase voltage magnitude kV and angle 30 32 20 21 VBFM VBFA Line B Phase voltage magnitude kV and angle 30 32 22 23 VCFM VCFA Line C Phase voltage magnitude kV and angle 30 32 24 VPM Polarizing voltage magnitude volts 30 32 25 NVS1M Synchronizing Voltage 1 magnitude volts 30 32 26 NVS2M Synchronizing Voltage 2 magnitude volts 30 32 27 28 LIGM...

Page 605: ...current amperes 30 32 75 3I2PKD Peak negative sequence demand current amperes 30 32 76 PAPKD A Phase peak demand power MW 30 32 77 PBPKD B Phase peak demand power MW 30 32 78 PCPKD C Phase peak demand power MW 30 32 79 3PPKD Three phase peak demand power MW 30 32 80 82 B1BCWPA B1BCWPB B1BCWPC Circuit Breaker 1 contact wear percentage multiplied by 100 30 32 83 85 B2BCWPA B2BCWPB B2BCWPC Circuit Br...

Page 606: ...ment Functional Constraint CO BKR1CSWI1 Pos Oper ctlVal CC1 OC1 Circuit Breaker 1 close open command BKR2CSWI2 Pos Oper ctlVal CC2 OC2 Circuit Breaker 2 close open command DC10CSWI10 Pos Oper ctlVal 89CC10 89OC10 ASCII Close Open Disconnect 10 command DC1CSWI1 Pos Oper ctlVal 89CC01 89OC01 ASCII Close Open Disconnect 1 command DC2CSWI2 Pos Oper ctlVal 89CC02 89OC02 ASCII Close Open Disconnect 2 co...

Page 607: ...2 Pole C closed BKR1CSWI1 OpCls general CC1a Circuit Breaker 1 close command BKR1CSWI1 OpOpn general OC1a Circuit Breaker 1 open command BKR1CSWI1 Pos stVal 52ACL1 1 2a Circuit Breaker 1 Pole A closed BKR1PTRC2 Tr general CSV06 TPA1 OR TPB1 OR TPC1 BKR1PTRC2 Tr phsA TPA1a Circuit Breaker 1 Trip A BKR1PTRC2 Tr phsB TPB1a Circuit Breaker 1 Trip B BKR1PTRC2 Tr phsC TPC1a Circuit Breaker 1 Trip C BKR2...

Page 608: ...and DC9CSWI9 OpOpn general 89OC09a ASCII Open Disconnect 9 command DC9CSWI9 Pos stVal 89CL09 89OPN09 0 1 2 3a Disconnect 9 status DCBPSCH2 Op general RXPRMa Receiver trip permission DCBPSCH2 RxPrm1 general BTXa Block extension picked up DCBPSCH2 TxBlk general Z3RBa Current reversal guard asserted DCBPSCH2 TxPrm general CSV01 DSTRT OR NSTRT DCUBPSCH3 EchoWei stVal EKEYa Echo received permissive tri...

Page 609: ...ion OSB5RPSB6 Str general OSBa Out of step block OSTRPSB1 Op general OSTa Out of step tripping P1PIOC1 Op general 50P1a Level 1 phase overcurrent element P1PTOC1 Op general 67P1Ta Level 1 phase delayed directional overcurrent element P1PTOC1 Str general 67P1a Level 1 phase directional overcurrent element P2PIOC4 Op general 50P2a Level 2 phase overcurrent element P2PTOC4 Op general 67P2Ta Level 2 p...

Page 610: ...eclaration S1PTOC13 Op general 51S1Ta Inverse Time Overcurrent Element 1 timed out S1PTOC13 Str general 51S1a Inverse Time Overcurrent Element 1 pickup S2PTOC14 Op general 51S2Ta Inverse Time Overcurrent Element 2 timed out S2PTOC14 Str general 51S2a Inverse Time Overcurrent Element 2 pickup S3PTOC15 Op general 51S3Ta Inverse Time Overcurrent Element 3 timed out S3PTOC15 Str general 51S3a Inverse ...

Page 611: ...2 Vol instMag f DC2 Filtered Station Battery DC Voltage 2 DMDMDST1 A phsA instCVal mag f IAD Demand A Phase current DMDMDST1 A phsB instCVal mag f IBD Demand B Phase current DMDMDST1 A phsC instCVal mag f ICD Demand C Phase current DMDMDST1 SeqA c1 instMag f 3I2D Demand negative sequence current DMDMDST1 SeqA c2 instMag f 3I2D Demand negative sequence current DMDMDST1 SeqA c3 instMag f IGD Demand ...

Page 612: ...ent magnitude Breaker 2 METMMXU1 Hz instMag f FREQ Tracking frequency METMMXU1 PF phsA instCVal mag f DPFA A Phase displacement power factor METMMXU1 PF phsB instCVal mag f DPFB B Phase displacement power factor METMMXU1 PF phsC instCVal mag f DPFC C Phase displacement power factor METMMXU1 PhV phsA instCVal ang f VAFA A Phase 10 cycle average fundamental phase voltage angle METMMXU1 PhV phsA inst...

Page 613: ...emand C Phase real power SEQMSQI1 SeqA c1 instCVal ang f LI1A 10 cycle average positive sequence current angle SEQMSQI1 SeqA c1 instCVal mag f LI1M 10 cycle average positive sequence current magnitude SEQMSQI1 SeqA c2 instCVal ang f L3I2A 10 cycle average negative sequence current angle SEQMSQI1 SeqA c2 instCVal mag f L3I2M 10 cycle average negative sequence current magnitude SEQMSQI1 SeqA c3 inst...

Page 614: ... the order of synchrophasors inside the data packet when operating in legacy mode LEGACY Y Table 10 17 Voltage Synchrophasor Names Phasor Name Phasor Enable Conditions PT Ratio V1YPM PHDVq V1 or ALL AND Terminal Y included PTRY VAYPM PHDVq PH or ALL AND Terminal Y included PTRY VBYPM PHDVq PH or ALL AND Terminal Y included PTRY VCYPM PHDVq PH or ALL AND Terminal Y included PTRY V1ZPM PHDVq V1 or A...

Page 615: ...ate values are sent when PHFMT P Rectangularc c Rectangular real and imaginary values are sent when PHFMT R Magnitude Angle Real Imaginary V1mPMMd d Where m Y if PHVOLT includes Y m Z if PHVOLT includes Z V1mPMA V1mPMR V1mPMI PHDATAV V1 or ALL VAmPMM VAmPMA VAmPMR VAmPMI VBmPMM VBmPMA VBmPMR VBmPMI PHDATAV PH or ALL VCmPMM VCmPMA VCmPMR VCmPMI I1nPMMe e Where n W if PHCURR includes W n X if PHCURR...

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Page 617: ...it Breaker 1 Angle 1 within Window 1 38 25W1BK2 Circuit Breaker 2 Angle 1 within Window 1 40 25W2BK1 Circuit Breaker 1 Angle 2 within Window 2 38 25W2BK2 Circuit Breaker 2 Angle 2 within Window 2 40 271P1 Undervoltage Element 1 Level 1 asserted 384 271P1T Undervoltage Element 1 Level 1 timed out 384 271P2 Undervoltage Element 1 Level 2 asserted 384 272P1 Undervoltage Element 2 Level 1 asserted 384...

Page 618: ...29 32QE 32Q internal enable 29 32QF Forward negative sequence overcurrent directional declaration 28 32QGE 32QG internal enable 29 32QR Reverse negative sequence overcurrent directional declaration 28 32SPOF Forward open pole directional declaration 28 32SPOR Reverse open pole directional declaration 28 32VE 32V internal enable 29 3P1CLS Three pole Circuit Breaker 1 reclose supervision SELOGIC con...

Page 619: ...d exceeded 68 50LCA2 Circuit Breaker 2 A Phase load current threshold exceeded 74 50LCB1 Circuit Breaker 1 B Phase load current threshold exceeded 68 50LCB2 Circuit Breaker 2 B Phase load current threshold exceeded 74 50LCC1 Circuit Breaker 1 C Phase load current threshold exceeded 68 50LCC2 Circuit Breaker 2 C Phase load current threshold exceeded 74 50P1 50P4 Level 1 4 phase overcurrent element ...

Page 620: ...lement 1 Level 1 asserted 387 591P1T Overvoltage Element 1 Level 1 timed out 387 591P2 Overvoltage Element 1 Level 2 asserted 387 592P1 Overvoltage Element 2 Level 1 asserted 387 592P1T Overvoltage Element 2 Level 1 timed out 387 592P2 Overvoltage Element 2 Level 2 asserted 387 593P1 Overvoltage Element 3 Level 1 asserted 388 593P1T Overvoltage Element 3 Level 1 timed out 388 593P2 Overvoltage Ele...

Page 621: ... 32 67P4 Level 4 phase directional overcurrent element 31 67P4T Level 4 phase delayed directional overcurrent element 32 67Q1 Level 1 negative sequence directional overcurrent element 34 67Q1T Level 1 negative sequence delayed directional overcurrent element 35 67Q2 Level 2 negative sequence directional overcurrent element 34 67Q2T Level 2 negative sequence delayed directional overcurrent element ...

Page 622: ... 6 overfrequency element pick up 395 81D6T Level 6 definite time frequency element delay 395 81D6UDR Level 6 underfrequency element pick up 395 89AL Any disconnect alarm 332 89AL01 Disconnect 1 alarm 332 89AL02 Disconnect 2 alarm 333 89AL03 Disconnect 3 alarm 334 89AL04 Disconnect 4 alarm 335 89AL05 Disconnect 5 alarm 336 89AL06 Disconnect 6 alarm 337 89AL07 Disconnect 7 alarm 338 89AL08 Disconnec...

Page 623: ... Close Disconnect 1 command 344 89CC02 ASCII Close Disconnect 2 command 346 89CC03 ASCII Close Disconnect 3 command 348 89CC04 ASCII Close Disconnect 4 command 350 89CC05 ASCII Close Disconnect 5 command 352 89CC06 ASCII Close Disconnect 6 command 354 89CC07 ASCII Close Disconnect 7 command 356 89CC08 ASCII Close Disconnect 8 command 358 89CC09 ASCII Close Disconnect 9 command 360 89CC10 ASCII Clo...

Page 624: ...nect 01 close immobility timer reset 364 89CIR02 Disconnect 02 close immobility timer reset 366 89CIR03 Disconnect 03 close immobility timer reset 368 89CIR04 Disconnect 04 close immobility timer reset 370 89CIR05 Disconnect 05 close immobility timer reset 372 89CIR06 Disconnect 06 close immobility timer reset 374 89CIR07 Disconnect 07 close immobility timer reset 376 89CIR08 Disconnect 08 close i...

Page 625: ...se seal in timer timed out 366 89CSI03 Disconnect 03 close seal in timer timed out 368 89CSI04 Disconnect 04 close seal in timer timed out 370 89CSI05 Disconnect 05 close seal in timer timed out 372 89CSI06 Disconnect 06 close seal in timer timed out 374 89CSI07 Disconnect 07 close seal in timer timed out 376 89CSI08 Disconnect 08 close seal in timer timed out 378 89CSI09 Disconnect 09 close seal ...

Page 626: ...46 89OCN03 Open Disconnect 3 348 89OCN04 Open Disconnect 4 350 89OCN05 Open Disconnect 5 352 89OCN06 Open Disconnect 6 354 89OCN07 Open Disconnect 7 356 89OCN08 Open Disconnect 8 358 89OCN09 Open Disconnect 9 360 89OCN10 Open Disconnect 10 362 89OIM01 Disconnect 01 open immobility timer timed out 365 89OIM02 Disconnect 02 open immobility timer timed out 367 89OIM03 Disconnect 03 open immobility ti...

Page 627: ...bility timer reset 378 89OIR09 Disconnect 09 open immobility timer reset 380 89OIR10 Disconnect 10 open immobility timer reset 382 89OPE01 Disconnect Open 1 output 344 89OPE02 Disconnect Open 2 output 346 89OPE03 Disconnect Open 3 output 348 89OPE04 Disconnect Open 4 output 350 89OPE05 Disconnect Open 5 output 352 89OPE06 Disconnect Open 6 output 354 89OPE07 Disconnect Open 7 output 356 89OPE08 Di...

Page 628: ...unter 1 8 output 194 ACN09Q ACN16Q Automation Counter 9 16 output 195 ACN17Q ACN24Q Automation Counter 17 24 output 196 ACN25Q ACN32Q Automation Counter 25 32 output 197 ACN01R ACN08R Automation Counter 1 8 reset 198 ACN09R ACN16R Automation Counter 9 16 reset 199 ACN17R ACN24R Automation Counter 17 24 reset 200 ACN25R ACN32R Automation Counter 25 32 reset 201 AFRTEXA Automation SELOGIC control eq...

Page 629: ...SELOGIC Variable 89 96 161 ASV097 ASV104 Automation SELOGIC Variable 97 104 162 ASV105 ASV112 Automation SELOGIC Variable 105 112 163 ASV113 ASV120 Automation SELOGIC Variable 113 120 164 ASV121 ASV128 Automation SELOGIC Variable 121 128 165 ASV129 ASV136 Automation SELOGIC Variable 129 136 166 ASV137 ASV144 Automation SELOGIC Variable 137 144 167 ASV145 ASV152 Automation SELOGIC Variable 145 152 ...

Page 630: ...C Phase open 77 B2PDAL Circuit Breaker 2 pole discrepancy alarm 86 B2PSAL Circuit Breaker 2 pole scatter alarm 86 BADPASS Invalid password attempt alarm 206 BFI3P1 Circuit Breaker 1 three pole circuit breaker failure initiation 65 BFI3P2 Circuit Breaker 2 three pole circuit breaker failure initiation 71 BFI3PT1 Circuit Breaker 1 extended three pole extended circuit breaker failure initiation 65 BF...

Page 631: ...icates Circuit Breaker 2 breaker failure trip 224 BK2CFT Circuit Breaker 2 close failure delay timed out 46 BK2CL Circuit Breaker 2 close command 44 BK2CLSS Circuit Breaker 2 in close supervision state 46 BK2CLST Circuit Breaker 2 close supervision timer timed out 46 BK2EXT Circuit Breaker 2 closed externally 50 BK2LO Circuit Breaker 2 in lockout state 44 BK2RCIP Circuit Breaker 2 reclaim in progr...

Page 632: ...rcuit Breaker 2 41 BTX Block extension picked up 60 CBADA Unavailability threshold exceeded for MIRRORED BITS Communications Channel A 229 CBADB Unavailability threshold exceeded for MIRRORED BITS Communications Channel B 230 CC1 Circuit Breaker 1 close command 91 CC2 Circuit Breaker 2 close command 91 CHSG Settings group change 100 CNR1AG Control A Phase composite current polarized right blinder ...

Page 633: ...ime pending 294 DSTRT Directional start element picked up 60 DTA Direct transfer trip A Phase SELOGIC control equation 57 DTB Direct transfer trip B Phase SELOGIC control equation 57 DTC Direct transfer trip C Phase SELOGIC control equation 57 DTR Direct transfer trip received 53 E3PT Three pole trip enable 53 E3PT1 Circuit Breaker 1 three pole trip enable 53 E3PT2 Circuit Breaker 2 three pole tri...

Page 634: ... failure 67 FBFC2 Circuit Breaker 2 C Phase circuit breaker failure 73 FIDEN Fault identification logic enabled 51 FOA1 Circuit Breaker 1 A Phase flashover detected 69 FOA2 Circuit Breaker 2 A Phase flashover detected 75 FOB1 Circuit Breaker 1 B Phase flashover detected 69 FOB2 Circuit Breaker 2 B Phase flashover detected 75 FOBF1 Circuit Breaker 1 flashover detected 70 FOBF2 Circuit Breaker 2 fla...

Page 635: ...RPSW Pulsed alarm for group switches 206 HALARM Hardware alarm 206 HALARMA Pulse stream for unacknowledged diagnostic warnings 206 HALARML Latched alarm for diagnostic failures 206 HALARMP Pulsed alarm for diagnostic warnings 206 HSDGF Ground fault high speed forward directional element 285 HSDGR Ground fault high speed reverse directional element 285 HSDQF Phase to phase fault high speed forward ...

Page 636: ...ion SELOGIC Equation 305 LB_SP17 LB_SP24 Local Bit 17 24 supervision SELOGIC Equation 306 LB_SP25 LB_SP32 Local Bit 25 32 supervision SELOGIC Equation 307 LB01 LB08 Local Bit 1 8 92 LB09 LB16 Local Bit 9 16 93 LB17 LB24 Local Bit 17 24 94 LB25 LB32 Local Bit 25 32 95 LBOKA Normal MIRRORED BITS Communications Channel A status while in loopback mode 229 LBOKB Normal MIRRORED BITS Communications Chan...

Page 637: ...M2PT Zone 2 Mho phase distance time delayed 19 M3P Zone 3 Mho phase distance element 19 M3PT Zone 3 Mho phase distance time delayed 19 M4P Zone 4 Mho phase distance element 19 M4PT Zone 4 Mho phase distance time delayed 19 M5P Zone 5 Mho phase distance element 19 M5PT Zone 5 Mho phase distance time delayed 19 MAB1 Zone 1 Mho A B phase element 8 MAB1F Zone 1 filtered Mho A B phase element 274 MAB1H...

Page 638: ...ed Zone 3 Mho B C phase element 282 MBC4 Zone 4 Mho B C phase element 9 MBC4F Zone 4 filtered Mho B C phase element 276 MBC5 Zone 5 Mho B C phase element 10 MBC5F Zone 5 filtered Mho B C phase element 277 MBG1 Zone 1 Mho B Phase to ground element 13 MBG1F Zone 1 filtered Mho B Phase to ground element 270 MBG1H High speed Zone 1 Mho BG ground element 278 MBG2 Zone 2 Mho B Phase to ground element 13...

Page 639: ...und element 14 MCG4F Zone 4 filtered Mho C Phase to ground element 272 MCG5 Zone 5 Mho C Phase to ground element 15 MCG5F Zone 5 filtered Mho C Phase to ground element 273 NBF1 Circuit Breaker 1 no current circuit breaker failure 68 NBF2 Circuit Breaker 2 no current circuit breaker failure 74 NBK0 No circuit breakers active in reclose scheme 45 NBK1 One circuit breaker active in reclose scheme 45 ...

Page 640: ... Pushbutton 9 12 pulse on for one processing interval when button is pushed 303 PCN01Q PCN08Q Protection Counter 1 8 output 142 PCN09Q PCN16Q Protection Counter 9 16 output 143 PCN17Q PCN24Q Protection Counter 17 24 output 144 PCN25Q PCN32Q Protection Counter 25 32 output 145 PCN01R PCN08R Protection Counter 1 8 reset 146 PCN09R PCN16R Protection Counter 9 16 reset 147 PCN17R PCN24R Protection Cou...

Page 641: ...PSV16 Protection SELOGIC Variable 9 16 117 PSV17 PSV24 Protection SELOGIC Variable 17 24 118 PSV25 PSV32 Protection SELOGIC Variable 25 32 119 PSV33 PSV40 Protection SELOGIC Variable 33 40 120 PSV41 PSV48 Protection SELOGIC Variable 41 48 121 PSV49 PSV56 Protection SELOGIC Variable 49 56 122 PSV57 PSV64 Protection SELOGIC Variable 57 64 123 PT Permissive trip received 58 PTA A Phase permissive tri...

Page 642: ...stance blinder 24 RMB1A RMB8A Channel A receive MIRRORED BITS 1 8 225 RMB1B RMB8B Channel B receive MIRRORED BITS 1 8 227 ROKA Normal MIRRORED BITS Communications Channel A status while not in loopback mode 229 ROKB Normal MIRRORED BITS Communications Channel B status while not in loopback mode 230 RR6 Positive sequence resistance within Zone 6 right resistance blinder 24 RR7 Positive sequence res...

Page 643: ...d aligned RTC data available on Channel A 291 RTCROKB Valid aligned RTC data available on Channel B 291 RTCSEQA RTC configuration complete Channel A 290 RTCSEQB RTC configuration complete Channel B 290 RTD01ST RTD08ST RTD status for Channel 1 8 87 RTD09ST RTD12ST RTD status for Channel 9 12 88 RTDCOMF RTD communication failure 88 RTDFL RTD device failure 88 RTDIN State of RTD contact input 88 RTS3...

Page 644: ...LOW1 fs1 fp 39 SLOW2 fs2 fp 41 SOTFE Switch onto fault enable 51 SOTFT Switch onto fault trip 53 SP1CLS Single pole Circuit Breaker 1 reclose supervision SELOGIC control equation 45 SP2CLS Single pole Circuit Breaker 2 reclose supervision SELOGIC control equation 45 SPARC Single pole reclose initiate qualified 42 SPCER1 Synchrophasor configuration error on Port 1 298 SPCER2 Synchrophasor configura...

Page 645: ... 2 TLED_17 TLED_24 Target LED 17 24 300 TMB1A TMB8A Channel A transmit MIRRORED BITS 1 8 226 TMB1B TMB8B Channel B transmit MIRRORED BITS 1 8 228 TOP Trip during open pole timer is asserted 56 TPA Trip A 55 TPA1 Circuit Breaker 1 Trip A 55 TPA2 Circuit Breaker 2 Trip A 56 TPB Trip B 55 TPB1 Circuit Breaker 1 Trip B 55 TPB2 Circuit Breaker 2 Trip B 56 TPC Trip C 55 TPC1 Circuit Breaker 1 Trip C 56 ...

Page 646: ...TC offset if TUTCS is asserted add otherwise 293 UBB Block permissive trip Receiver 1 or 2 59 UBB1 Blocks permissive trip Receiver 1 59 UBB2 Blocks permissive trip Receiver 2 59 UBOSB Unblock out of step blocking 21 ULCL1 Unlatch closing for Circuit Breaker 1 SELOGIC control equation 46 ULCL2 Unlatch closing for Circuit Breaker 2 SELOGIC control equation 46 ULMTR1 Circuit Breaker 1 unlatch manual ...

Page 647: ...n detected 59 X6ABC Impedance inside Zone 6 out of step 21 X6T Positive sequence reactance within Zone 6 reactance blinder 24 X7ABC Impedance inside Zone 7 out of step 21 X7T Positive sequence reactance within Zone 7 reactance blinder 24 XAB1 Zone 1 quad A B phase element 10 XAB1F Zone 1 quad A B phase element 274 XAB1H High speed Zone 1 high speed quad A B phase element 283 XAB2 Zone 2 quad A B p...

Page 648: ... High speed Zone 3 high speed quad B C phase element 284 XBC4 Zone 4 quad B C phase element 12 XBC4F Zone 4 quad B C phase element 276 XBC5 Zone 5 quad B C phase element 12 XBC5F Zone 5 quad B C phase element 277 XBG1 Zone 1 quad B Phase to ground element 16 XBG1F Zone 1 quad B Phase to ground element 270 XBG1H High speed Zone 1 quad B G ground element 279 XBG2 Zone 2 quad B Phase to ground elemen...

Page 649: ...al add 1 if asserted 292 YEAR10 IRIG B year information binary coded decimal add 10 if asserted 292 YEAR2 IRIG B year information binary coded decimal add 2 if asserted 292 YEAR20 IRIG B year information binary coded decimal add 20 if asserted 292 YEAR4 IRIG B year information binary coded decimal add 4 if asserted 292 YEAR40 IRIG B year information binary coded decimal add 40 if asserted 292 YEAR...

Page 650: ... distance time delayed 7 Z5G Zone 5 ground distance element 5 Z5GT Zone 5 ground distance time delayed 6 Z5P Zone 5 phase distance element 3 Z5PT Zone 5 phase distance time delayed 4 Z5T Zone 5 phase or ground distance time delayed 7 ZLIN Load encroachment load in element 51 ZLOAD ZLOUT or ZLIN element picked up 51 ZLOUT Load encroachment load out element 51 Table 11 2 Relay Word Bits Enable and T...

Page 651: ...ho B C phase element 8 MCA1 Zone 1 Mho C A phase element 8 Reserved 8 MAB2 Zone 2 Mho A B phase element 8 MBC2 Zone 2 Mho B C phase element 8 MCA2 Zone 2 Mho C A phase element 8 Reserved 9 MAB3 Zone 3 Mho A B phase element 9 MBC3 Zone 3 Mho B C phase element 9 MCA3 Zone 3 Mho C A phase element 9 Reserved 9 MAB4 Zone 4 Mho A B phase element 9 MBC4 Zone 4 Mho B C phase element 9 MCA4 Zone 4 Mho C A ...

Page 652: ...ground element 13 MBG1 Zone 1 Mho B Phase to ground element 13 MCG1 Zone 1 Mho C Phase to ground element 13 Reserved 13 MAG2 Zone 2 Mho A Phase to ground element 13 MBG2 Zone 2 Mho B Phase to ground element 13 MCG2 Zone 2 Mho C Phase to ground element 13 Reserved 14 MAG3 Zone 3 Mho A Phase to ground element 14 MBG3 Zone 3 Mho B Phase to ground element 14 MCG3 Zone 3 Mho C Phase to ground element 1...

Page 653: ... B Phase to ground element 18 XCG5 Zone 5 quad C Phase to ground element 18 CVTBLH CCVT transient blocking logic active high speed elements Note The SEL 421 4 does not provide high speed distance elements so the CVTBLH Relay Word bit is unavailable 18 CVTBL CCVT transient blocking logic active 18 VPOLV Polarizing voltage valid 18 M1P M2P Zone 1 2 Mho phase distance element 19 M3P M5P Zone 3 5 Mho ...

Page 654: ...23 Reserved 23 Reserved 23 Reserved 24 X6T Positive sequence reactance within Zone 6 reactance blinder 24 R6T Positive sequence resistance within Zone 6 resistance blinder 24 RR6 Positive sequence resistance within Zone 6 right resistance blinder 24 RL6 Positive sequence resistance within Zone 6 left resistance blinder 24 X7T Positive sequence reactance within Zone 7 reactance blinder 24 R7T Posit...

Page 655: ...QF Forward negative sequence overcurrent directional declaration 28 32QR Reverse negative sequence overcurrent directional declaration 28 32SPOF Forward open pole directional declaration 28 32SPOR Reverse open pole directional declaration 29 50QF Forward negative sequence supervisory current element 29 50QR Reverse negative sequence supervisory current element 29 50GF Forward zero sequence supervi...

Page 656: ...e Overcurrent Element 1 timed out 36 51S1R Inverse time Overcurrent Element 1 reset 36 Reserved 36 51S2 Inverse time Overcurrent Element 2 pickup 36 51S2T Inverse time Overcurrent Element 2 timed out 36 51S2R Inverse time Overcurrent Element 2 reset 36 Reserved 37 51S3 Inverse time Overcurrent Element 3 pickup 37 51S3T Inverse time Overcurrent Element 3 timed out 37 51S3R Inverse time Overcurrent ...

Page 657: ...k for Circuit Breaker 2 41 59VDIF2 Circuit Breaker 2 synchronizing voltage difference less than limit 41 Reserved 41 Reserved 41 Reserved 41 Reserved Table 11 9 Relay Word Bits Reclosing Elements Sheet 1 of 3 Row Name Description 42 SPRI Single pole reclose initiation SELOGIC control equation 42 SPARC Single pole reclose initiate qualified 42 SPLSHT Single pole reclose last shot 42 SPOBK1 Single p...

Page 658: ...ion 46 BK1CFT Circuit Breaker 1 close failure delay timed out 46 BK2CFT Circuit Breaker 2 close failure delay timed out 46 BK1CLSS Circuit Breaker 1 in close supervision state 46 BK2CLSS Circuit Breaker 2 in close supervision state 46 BK1CLST Circuit Breaker 1 close supervision timer timed out 46 BK2CLST Circuit Breaker 2 close supervision timer timed out 46 ULCL1 Unlatch closing for Circuit Break...

Page 659: ...scellaneous Elements Row Name Description 51 SOTFE Switch onto fault enable 51 ILOP Internal loss of potential from ELOP setting 51 LOP Loss of potential detected 51 ZLOAD ZLOUT or ZLIN element picked up 51 ZLIN Load encroachment load in element 51 ZLOUT Load encroachment load out element 51 FIDEN Fault identification logic enabled 51 FSA A Phase sector fault AG or BCG fault 52 FSB B Phase sector ...

Page 660: ...A or Trip B or Trip C 55 3PT Three pole trip 55 SPT Single pole trip 55 TPA1 Circuit Breaker 1 Trip A 55 TPB1 Circuit Breaker 1 Trip B 56 TPC1 Circuit Breaker 1 Trip C 56 TPA2 Circuit Breaker 2 Trip A 56 TPB2 Circuit Breaker 2 Trip B 56 TPC2 Circuit Breaker 2 Trip C 56 TOP Trip during open pole timer is asserted 56 ULTR Unlatch all protection trips 56 ULMTR1 Circuit Breaker 1 unlatch manual trip 5...

Page 661: ... phase and ground short delay element 60 67QG2S Negative sequence and residual directional overcurrent short delay element 60 DSTRT Directional start element picked up 60 NSTRT Nondirectional start element picked up 60 STOP Stop element picked up 60 BTX Block extension picked up 61 Z3RBA A Phase current reversal guard asserted ECOMM POTT3 61 Z3RBB B Phase current reversal guard asserted ECOMM POTT...

Page 662: ...CT1 Circuit Breaker 1 C Phase extended circuit breaker failure initiation 66 50FA1 Circuit Breaker 1 A Phase current threshold exceeded 66 50FB1 Circuit Breaker 1 B Phase current threshold exceeded 66 50FC1 Circuit Breaker 1 C Phase current threshold exceeded 66 RT3P1 Circuit Breaker 1 three pole retrip 66 RTA1 Circuit Breaker 1 A Phase retrip 66 RTB1 Circuit Breaker 1 B Phase retrip 66 RTC1 Circu...

Page 663: ...eaker failure unlatch trip Circuit Breaker 1 SELOGIC control equation 70 Reserved 70 Reserved Table 11 15 Relay Word Bits Breaker 2 Failure Sheet 1 of 2 Row Name Description 71 BFI3P2 Circuit Breaker 2 three pole circuit breaker failure initiation 71 BFIA2 Circuit Breaker 2 A Phase circuit breaker failure initiation 71 BFIB2 Circuit Breaker 2 B Phase circuit breaker failure initiation 71 BFIC2 Cir...

Page 664: ...shover current threshold exceeded 75 50FOC2 Circuit Breaker 2 C Phase flashover current threshold exceeded 75 BLKFOA2 Circuit Breaker 2 block A Phase flashover detection 75 BLKFOB2 Circuit Breaker 2 block B Phase flashover detection 75 BLKFOC2 Circuit Breaker 2 block C Phase flashover detection 75 FOA2 Circuit Breaker 2 A Phase flashover detected 75 FOB2 Circuit Breaker 2 B Phase flashover detecte...

Page 665: ... 1 Pole A alarm 80 52BAL1 Circuit Breaker 1 Pole B alarm 80 52CAL1 Circuit Breaker 1 Pole C alarm 80 52AA1 Circuit Breaker 1 Pole A status 80 52AB1 Circuit Breaker 1 Pole B status 81 52AC1 Circuit Breaker 1 Pole C status 81 Reserved 81 52ACL2 Circuit Breaker 2 Pole A closed 81 52BCL2 Circuit Breaker 2 Pole B closed 81 52CCL2 Circuit Breaker 2 Pole C closed 81 52AAL2 Circuit Breaker 2 Pole A alarm ...

Page 666: ...rcuit Breaker 1 interrupted current alarm 85 BM2TRPA Circuit breaker monitor A Phase trip Circuit Breaker 2 SELOGIC control equation 85 BM2TRPB Circuit breaker monitor B Phase trip Circuit Breaker 2 SELOGIC control equation 85 BM2TRPC Circuit breaker monitor C Phase trip Circuit Breaker 2 SELOGIC control equation 85 BM2CLSA Circuit breaker monitor A Phase close Circuit Breaker 2 SELOGIC control eq...

Page 667: ...Metering Elements Row Name Description 90 PDEM Phase current demand picked up 90 QDEM Negative sequence demand current picked up 90 GDEM Zero sequence demand current picked up 90 Reserved 90 Reserved 90 Reserved 90 Reserved 90 Reserved Table 11 21 Relay Word Bits Open and Close Row Name Description 91 CC2 Circuit Breaker 2 close command 91 OC2 Circuit Breaker 2 open command 91 CC1 Circuit Breaker ...

Page 668: ...l I O board Input 1 8 if installed 109 IN209 IN216 First optional I O board Input 9 16 if installed 110 IN217 IN224 First optional I O board Input 17 24 if installed 111 Reserved 112 IN301 IN308 Second optional I O board Input 1 8 if installed 113 IN309 IN316 Second optional I O board Input 9 16 if installed 114 IN317 IN324 Second optional I O board Input 17 24 if installed 115 Reserved Table 11 2...

Page 669: ...35 PST09Q PST16Q Protection Sequencing Timer 9 16 output 136 PST17Q PST24Q Protection Sequencing Timer 17 24 output 137 PST25Q PST32Q Protection Sequencing Timer 25 32 output 138 PST01R PST08R Protection Sequencing Timer 1 8 reset 139 PST09R PST16R Protection Sequencing Timer 9 16 reset 140 PST17R PST24R Protection Sequencing Timer 17 24 reset 141 PST25R PST32R Protection Sequencing Timer 25 32 re...

Page 670: ...SELOGIC Counters Row Name Description 194 ACN01Q ACN08Q Automation Counter 1 8 output 195 ACN09Q ACN16Q Automation Counter 9 16 output 196 ACN17Q ACN24Q Automation Counter 17 24 output 197 ACN25Q ACN32Q Automation Counter 25 32 output 198 ACN01R ACN08R Automation Counter 1 8 reset 199 ACN09R ACN16R Automation Counter 9 16 reset 200 ACN17R ACN24R Automation Counter 17 24 reset 201 ACN25R ACN32R Aut...

Page 671: ... A user is logged in at Access Level B or above 207 ACCESSP Pulsed alarm for logins to Access Level B or above 208 Reserved 208 Reserved 208 Reserved 208 Reserved 208 Reserved 208 Reserved 208 PASSDIS Asserted to indicate PW disable 208 BRKENAB Asserted to indicate breaker control enable Table 11 38 Relay Word Bits Time and Date Management and Frequency Estimation Sheet 1 of 2 Row Name Description...

Page 672: ... SER_SET Asserts when the serial IRIG B source is the qualified high accuracy time source 212 SER_RST Asserts when the serial IRIG B source is disqualified as the high accuracy time source 212 BNC_SET Asserts when the BNC IRIG B source is the qualified high accuracy time source 212 BNC_RST Asserts when the BNC IRIG B source is disqualified as the high accuracy time source 212 BNC_OK Asserts when a...

Page 673: ...Breaker 2 SELOGIC control equation 222 RST_BK1 Reset Circuit Breaker 1 monitor 222 RST_BK2 Reset Circuit Breaker 2 monitor 223 RST_BAT Reset battery monitoring SELOGIC control equation 223 RSTFLOC Reset fault locator SELOGIC control equation 223 RSTDNPE Reset DNP fault summary data SELOGIC control equation 223 RST_79C Reset recloser shot count accumulators SELOGIC control equation 223 RSTTRGT Targ...

Page 674: ...nel B status while not in loopback mode 230 RBADB Outage too long on MIRRORED BITS Communications Channel B 230 CBADB Unavailability threshold exceeded for MIRRORED BITS Communications Channel B 230 LBOKB Normal MIRRORED BITS Communications Channel B status while in loopback mode 230 ANOKB Analog transfer OK on MIRRORED BITS Communications Channel B 230 DOKB Normal MIRRORED BITS Communications Cha...

Page 675: ...072 Virtual Bits 065 072 256 VB057 VB064 Virtual Bits 057 064 257 VB049 VB056 Virtual Bits 049 056 258 VB041 VB048 Virtual Bits 041 048 259 VB033 VB040 Virtual Bits 033 040 260 VB025 VB032 Virtual Bits 025 032 261 VB017 VB024 Virtual Bits 017 024 262 VB009 VB016 Virtual Bits 009 016 263 VB001 VB008 Virtual Bits 001 008 Table 11 47 Relay Word Bits Ethernet Switch Sheet 1 of 2 Row Name Description 2...

Page 676: ...al Port 1 268 FSERP2 Fast SER enabled for Serial Port 2 268 FSERP3 Fast SER enabled for Serial Port 3 268 FSERPF Fast SER enabled for Serial Port F 268 FSERP5 Fast SER enabled for EN and FO ports 268 Reserved 268 Reserved 268 Reserved Table 11 50 Relay Word Bits Source Selection Elements Row Name Description 269 ALTI Alternate current source SELOGIC control equation 269 ALTV Alternate voltage sour...

Page 677: ...t 271 MCG2F Zone 2 filtered Mho C Phase to ground element 272 XCG4F Zone 4 quad C Phase to ground element 272 XBG4F Zone 4 quad B Phase to ground element 272 XAG4F Zone 4 quad A Phase to ground element 272 MCG4F Zone 4 filtered Mho C Phase to ground element 272 MBG4F Zone 4 filtered Mho B Phase to ground element 272 MAG4F Zone 4 filtered Mho C Phase to ground element 272 XCG3F Zone 3 quad C Phase ...

Page 678: ...d 277 XCA5F Zone 5 quad CA phase element 277 XBC5F Zone 5 quad BC phase element 277 XAB5F Zone 5 quad AB phase element 277 MCA5F Zone 5 filtered Mho CA phase element 277 MBC5F Zone 5 filtered Mho BC phase element 277 MAB5F Zone 5 filtered Mho AB phase element Table 11 53 Relay Word Bits High Speed Mho and Quad Ground Distance Sheet 1 of 2 Row Name Description 278 MBG3H High speed Zone 3 Mho BG gro...

Page 679: ...AB2H High speed Zone 2 Mho AB phase element 282 MCA1H High speed Zone 1 Mho CA phase element 282 MBC1H High speed Zone 1 Mho BC phase element 282 MAB1H High speed Zone 1 Mho AB phase element 283 XAB3H High speed Zone 3 high speed quad AB phase element 283 XCA2H High speed Zone 2 high speed quad CA phase element 283 XBC2H High speed Zone 2 high speed quad BC phase element 283 XAB2H High speed Zone ...

Page 680: ...IC Equations RTC Synchrophasors Status Bits Sheet 1 of 2 Row Name Description 288 PMTRIG Trigger SELOGIC control equation 288 TREA1 TREA4 Trigger Reason Bit 1 4 SELOGIC Equation 288 FROKPM Synchrophasor frequency 288 PMTEST Synchrophasor test mode 288 Reserved 289 Reserved 290 Reserved 290 Reserved 290 Reserved 290 Reserved 290 RTCSEQB RTC configuration complete Channel B 290 RTCSEQA RTC configura...

Page 681: ...rs from UTC time binary add 2 if asserted 293 TUTC1 IRIG B Offset hours from UTC time binary add 1 if asserted 293 TUTCS IRIG B Offset hours sign from UTC time subtract the UTC offset if TUTCS is asserted add otherwise 294 DST Daylight saving time 294 DSTP IRIG B Daylight saving time pending 294 LPSEC Direction of the upcoming leap second During the time that LPSECP is asserted if LPSEC is asserte...

Page 682: ...B12 Pushbutton 9 12 301 Reserved 301 Reserved 301 PB_TRIP Auxiliary TRIP pushbutton 301 PB_CLSE Auxiliary CLOSE pushbutton 302 PB9_LED Pushbutton 9 LED 302 PB10LED Pushbutton 10 LED 302 PB11LED Pushbutton 11 LED 302 PB12LED Pushbutton 12 LED 302 Reserved 302 Reserved 302 Reserved 302 Reserved 303 PB9_PUL Pushbutton 9 pulse on for one processing interval when button is pushed 303 PB10PUL Pushbutton...

Page 683: ... Bit 9 16 Table 11 64 Relay Word Bits Fast Operate Transmit Bits Row Name Description 316 FOPF_01 FOPF_08 Fast operate output control bits for Port F Bit 1 8 317 FOPF_09 FOPF_16 Fast operate output control bits for Port F Bit 9 16 318 FOPF_17 FOPF_24 Fast operate output control bits for Port F Bit 17 24 319 FOPF_25 FOPF_32 Fast operate output control bits for Port F Bit 25 32 320 FOP1_01 FOP1_08 F...

Page 684: ...rved 333 89OIP Any Disconnect operation in progress 334 89AM03 Disconnect 3 N O auxiliary contact 334 89BM03 Disconnect 3 N C auxiliary contact 334 89CL03 Disconnect 3 closed 334 89OPN03 Disconnect 3 open 334 89OIP03 Disconnect 3 operation in progress 334 89AL03 Disconnect 3 alarm 334 Reserved 334 LOCAL Local front panel control 335 89AM04 Disconnect 4 N O auxiliary contact 335 89BM04 Disconnect 4...

Page 685: ...Disconnect 8 N C auxiliary contact 339 89CL08 Disconnect 8 closed 339 89OPN08 Disconnect 8 open 339 89OIP08 Disconnect 8 operation in progress 339 89AL08 Disconnect 8 alarm 339 Reserved 339 Reserved 340 89AM09 Disconnect 9 N O auxiliary contact 340 89BM09 Disconnect 9 N C auxiliary contact 340 89CL09 Disconnect 9 closed 340 89OPN09 Disconnect 9 open 340 89OIP09 Disconnect 9 operation in progress 3...

Page 686: ...1 Disconnect Close 1 output 344 89OCN01 Open Disconnect 1 344 89CCN01 Close Disconnect 1 345 Reserved 346 89OC02 ASCII Open Disconnect 2 command 346 89CC02 ASCII Close Disconnect 2 command 346 89OCM02 Mimic Disconnect 2 open control 346 89CCM02 Mimic Disconnect 2 close control 346 89OPE02 Disconnect Open 2 output 346 89CLS02 Disconnect Close 2 output 346 89OCN02 Open Disconnect 2 346 89CCN02 Close...

Page 687: ...ntrol 354 89CCM06 Mimic Disconnect 6 close control 354 89OPE06 Disconnect Open 6 output 354 89CLS06 Disconnect Close 6 output 354 89OCN06 Open Disconnect 6 354 89CCN06 Close Disconnect 6 355 Reserved 356 89OC07 ASCII Open Disconnect 7 command 356 89CC07 ASCII Close Disconnect 7 command 356 89OCM07 Mimic Disconnect 7 open control 356 89CCM07 Mimic Disconnect 7 close control 356 89OPE07 Disconnect O...

Page 688: ...ol Disconnect Timers and Breaker Status Sheet 1 of 5 Row Name Description 364 89CBL01 Disconnect 01 close block 364 89OSI01 Disconnect 01 open seal in timer timed out 364 89CSI01 Disconnect 01 close seal in timer timed out 364 89OIR01 Disconnect 01 open immobility timer reset 364 89CIR01 Disconnect 01 close immobility timer reset 364 89OBL01 Disconnect 01 open block 364 89ORS01 Disconnect 01 open ...

Page 689: ...ty timer reset 368 89OBL03 Disconnect 03 open block 368 89ORS03 Disconnect 03 open reset 368 89CRS03 Disconnect 03 close reset 369 89OIM03 Disconnect 03 open immobility timer timed out 369 89CIM03 Disconnect 03 close immobility timer timed out 369 Reserved 369 Reserved 369 Reserved 369 Reserved 369 Reserved 369 Reserved 370 89CBL04 Disconnect 04 close block 370 89OSI04 Disconnect 04 open seal in t...

Page 690: ...connect 06 close block 374 89OSI06 Disconnect 06 open seal in timer timed out 374 89CSI06 Disconnect 06 close seal in timer timed out 374 89OIR06 Disconnect 06 open immobility timer reset 374 89CIR06 Disconnect 06 close immobility timer reset 374 89OBL06 Disconnect 06 open block 374 89ORS06 Disconnect 06 open reset 374 89CRS06 Disconnect 06 close reset 375 89OIM06 Disconnect 06 open immobility tim...

Page 691: ...onnect 08 open reset 378 89CRS08 Disconnect 08 close reset 379 89OIM08 Disconnect 08 open immobility timer timed out 379 89CIM08 Disconnect 08 close immobility timer timed out 379 Reserved 379 Reserved 379 Reserved 379 Reserved 379 Reserved 379 Reserved 380 89CBL09 Disconnect 09 close block 380 89OSI09 Disconnect 09 open seal in timer timed out 380 89CSI09 Disconnect 09 close seal in timer timed o...

Page 692: ...t 1 Level 1 timed out 384 271P2 Undervoltage Element 1 Level 2 asserted 384 27TC1 Undervoltage Element 1 torque control 384 272P1 Undervoltage Element 2 Level 1 asserted 384 272P1T Undervoltage Element 2 Level 1 timed out 384 272P2 Undervoltage Element 2 Level 2 asserted 384 27TC2 Undervoltage Element 2 torque control 385 273P1 Undervoltage Element 3 Level 1 asserted 385 273P1T Undervoltage Elemen...

Page 693: ...ent 4 Level 1 asserted 388 594P1T Overvoltage Element 4 Level 1 timed out 388 594P2 Overvoltage Element 4 Level 2 asserted 388 59TC4 Overvoltage Element 4 torque control 389 595P1 Overvoltage Element 5 Level 1 asserted 389 595P1T Overvoltage Element 5 Level 1 timed out 389 595P2 Overvoltage Element 5 Level 2 asserted 389 59TC5 Overvoltage Element 5 torque control 389 596P1 Overvoltage Element 6 Le...

Page 694: ... 81D6OVR Level 6 overfrequency element pickup 395 81D6UDR Level 6 underfrequency element pickup 395 Reserved 395 Reserved 395 Reserved 395 Reserved Table 11 71 Full Cycle Mho and Quad Distance Sheet 1 of 2 Row Name Description 396 ENX2AG Enable A Phase Ipa polarized reactance element 396 ENX2BG Enable B Phase Ipb polarized reactance element 396 ENX2CG Enable C Phase Ipc polarized reactance element...

Page 695: ...403 IO300OK Communications status of Interface Board 300 when installed or commissioned 403 IO400OK Communications status of Interface Board 400 when installed or commissioned 403 IO500OK Communications status of Interface Board 500 when installed or commissioned Reserved Reserved Reserved Reserved Reserved Table 11 74 Additional Inputs and Outputs Row Name Description 404 IN401 408 Optional I O B...

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Page 697: ...ltered current real component Amperes A secondary 3I2D Demand negative sequence current Amperes A secondary 3I2PKD Peak demand negative sequence current Amperes A primary 3IA2WFA Terminal W negative sequence filtered current angle Degrees 180 3IA2WFI Terminal W negative sequence filtered current imaginary component Amperes A secondary 3IA2WFM Terminal W negative sequence filtered current magnitude...

Page 698: ...iltered voltage magnitude Volts V secondary 3V0ZFR Terminal Z zero sequence filtered voltage real component Volts V secondary 3V2A 10 cycle average negative sequence voltage angle Degrees 180 3V2FIA Negative sequence instantaneous voltage angle Degrees 180 3V2FIM Negative sequence instantaneous voltage magnitude Volts V secondary 3V2M 10 cycle average negative sequence voltage magnitude Kilo volts...

Page 699: ...es A secondary B2IAFM B2IBFM B2ICFM 10 cycle average fundamental phase current magnitude Breaker 2 Amperes A primary B2IARMS B2IARMS B2IARMS 10 cycle average rms phase current Breaker 2 Amperes A primary B2IGFIM Breaker 2 zero sequence instantaneous current magnitude Amperes A secondary B2IMAXM Breaker 2 maximum filtered instantaneous breaker phase current magnitude Amperes A secondary BNCDSJI BNC...

Page 700: ...Amperes A primary I1SPMID Positive sequence synchrophasor current imaginary component Terminal S delayed for RTC alignment Amperes A primary I1SPMM Positive sequence synchrophasor current magnitude Terminal S Amperes A primary I1SPMMD Positive sequence synchrophasor current magnitude Terminal S delayed for RTC alignment Amperes A primary I1SPMR Positive sequence synchrophasor current real componen...

Page 701: ...inal X positive sequence filtered current magnitude Amperes A secondary IA1XFR Terminal X positive sequence filtered current real component Amperes A secondary IAD IBD ICD Demand phase current Amperes A primary IAPKD IBPKD ICPKD Peak demand phase current Amperes A primary IASPMA IBSPMA ICSPMA Synchrophasor current angle Terminal S Degrees 180 IASPMAD IBSPMAD ICSPMAD Synchrophasor current angle Ter...

Page 702: ... alignment Degrees 180 IAXPMI IBXPMI ICXPMI Synchrophasor current imaginary component Terminal X Amperes A primary IAXPMID IBXPMID ICXPMID Synchrophasor current imaginary component Terminal X delayed for RTC alignment Amperes A primary IAXPMM IBXPMM ICXPMM Synchrophasor current magnitude Terminal X Amperes A primary IAXPMMD IBXPMMD ICXPMMD Synchrophasor current magnitude Terminal X delayed for RTC...

Page 703: ...FIM Positive sequence instantaneous current magnitude Amperes A secondary LI1M 10 cycle average positive sequence current magnitude line Amperes A primary LIAFA LIBFA LICFA 10 cycle average fundamental current angle line Degrees 180 LIAFIA LIBFIA LICFIA Filtered instantaneous current angles Degrees 180 LIAFIM LIBFIM LICFIM Filtered instantaneous phase current magnitude Amperes A secondary LIAFM LI...

Page 704: ... PTPOTJF Fast converging PTP ON TIME marker jitter in µs coarse accuracy µs PTPOFST Raw clock offset between PTP master and relay time ns PTPPORT Active PTP port number N A PTPTBTW Time between PTP 100PPS pulses in µs µs PTPSTEN PTP Port State enumerated value N A PTRY Y Potential transformer ratio setting divided by 1000 N A PTRZ Z Potential transformer ratio setting divided by 1000 N A QA_F QB_F...

Page 705: ...T3_3 Total number of 3rd shot three pole recloses N A SHOT3_4 Total number of 4th shot three pole recloses N A SHOT3_T Total number of three pole recloses N A SLIP1 SLIP2 Slip fs1 2 fp Hertz Hz SODPM Second of day of the synchrophasor data packet Seconds s SODPMD Second of day of the synchrophasor data packet delayed for RTC alignment Seconds s SPSHOT Present value of single pole shot counter N A ...

Page 706: ...hasor voltage angle Terminal Z Degrees 180 V1ZPMAD Positive sequence Synchrophasor voltage angle Terminal Z delayed for RTC alignment Degrees 180 V1ZPMI Positive sequence synchrophasor voltage imaginary component Terminal Z Kilo Volts kV primary V1ZPMID Positive sequence synchrophasor voltage imaginary component Terminal Z delayed for RTC alignment Kilo Volts kV primary V1ZPMM Positive sequence sy...

Page 707: ...imary VAYPMID VBYPMID VCYPMID Synchrophasor voltage imaginary component Terminal Y delayed for RTC alignment Kilo Volts kV primary VAYPMM VBYPMM VCYPMM Synchrophasor voltage magnitude Terminal Y Kilo Volts kV primary VAYPMMD VBYPMMD VCYPMMD Synchrophasor voltage magnitude Terminal Y delayed for RTC alignment Kilo Volts kV primary VAYPMR VBYPMR VCYPMR Synchrophasor voltage real component Terminal Y...

Page 708: ...ent Volts V secondary VCZFM C Phase Terminal Z filtered voltage magnitude Volts V secondary VCZFR C Phase Terminal Z filtered voltage real component Volts V secondary VNMAXF Instantaneous filtered maximum phase to neutral voltage magnitude Volts V secondary VNMINF Instantaneous filtered minimum phase to neutral voltage magnitude Volts V secondary VPM VP voltage magnitude Volts V secondary VPMAXF I...

Page 709: ...IA Negative sequence instantaneous voltage angle Degrees 180 3V0FIA Zero sequence instantaneous voltage angle Degrees 180 LI1FIA Positive sequence instantaneous current angle Degrees 180 Z1FA Positive sequence instantaneous impedance angle Degrees 180 Real and Imaginary Analog Quantities IAWFR IBWFR ICWFR A Phase B Phase C Phase Terminal W filtered current real component Amperes A secondary IAXFR ...

Page 710: ...al component Volts V secondary 3V0YFI Terminal Y zero sequence filtered voltage imaginary component Volts V secondary 3V0ZFI Terminal Z zero sequence filtered voltage imaginary component Volts V secondary IAWFM IBWFM ICWFM A Phase B Phase C Phase Terminal W filtered current magnitude Amperes A secondary IAXFM IBXFM ICXFM A Phase B Phase C Phase Terminal X filtered current magnitude Amperes A secon...

Page 711: ...fore Source Selection IAWM IBWM ICWM Filtered instantaneous current magnitude Terminal W Amperes A secondary IAXM IBXM ICXM Filtered instantaneous current magnitude Terminal X Amperes A secondary VAYM VBYM VCYM Filtered instantaneous voltage magnitude Terminal Y Volts V secondary VAZM VBZM VCZM Filtered instantaneous voltage magnitude Terminal Z Volts V secondary 10 Cycle Averaged Fundamental Curr...

Page 712: ...y VPMINF Instantaneous filtered minimum phase to phase voltage magnitude Volts V secondary 3V2M 10 cycle average negative sequence voltage magnitude Kilo volts kV primary 3V2A 10 cycle average negative sequence voltage angle Degrees 180 3V0M 10 cycle average zero sequence voltage magnitude Kilo volts kV primary 3V0A 10 cycle average zero sequence voltage angle Degrees 180 Apparent Real and Reactiv...

Page 713: ...QPKD Peak demand three phase reactive power Megavars MVAr primary UAPKD UBPKD UCPKD Peak demand phase apparent power Megavolt amperes MVA primary 3UPKD Peak demand three phase apparent power Megavolt amperes MVA primary IAD IBD ICD Demand phase current Amperes A primary 3I2D Demand negative sequence current Amperes A primary IGD Demand zero sequence current Amperes A primary PAD PBD PCD Demand pha...

Page 714: ...n SELOGIC counter current value N A PCN01PV PCN32PV Protection SELOGIC counter preset value N A AMV001 AMV256 Automation SELOGIC math variable N A AST01ET AST32ET Automation SELOGIC math sequencing timer elapsed time Seconds s AST01PT AST32PT Automation SELOGIC sequencing timer preset time Seconds s ACN01CV ACN32CV Automation SELOGIC counter current value N A ACN01PV ACN32PV Automation SELOGIC cou...

Page 715: ...tities 0 0 255 0 A D Counts IN301A IN308A Digital input values available as floating point quantities 0 0 255 0 A D Counts IN201V IN208V Contact input A D counts converted to calibrated voltage V IN301V IN308V Contact input A D counts converted to calibrated voltage V RTD RTD01 RTD12 Instantaneous temperatures from external SEL 2600 C degrees Celsius IRIG B Control Function Bits for Synchrophasor ...

Page 716: ...kV primary VAZYPMR VBZPMR VCZPMR Synchrophasor voltage real component Terminal Z Kilo Volts kV primary VAYPMI VBYPMI VCYPMI Synchrophasor voltage imaginary component Terminal Y Kilo Volts kV primary VAZYPMI VBZPMI VCZYPMI Synchrophasor voltage imaginary component Terminal Z Kilo Volts kV primary V1YPMM Positive sequence synchrophasor voltage magnitude Terminal Y Kilo Volts kV primary V1ZPMM Positi...

Page 717: ...equence synchrophasor current angle Terminal W Degrees 180 I1XPMA Positive sequence synchrophasor current angle Terminal X Degrees 180 I1SPMA Positive sequence synchrophasor current angle Terminal S Degrees 180 I1WPMR Positive sequence synchrophasor current real component Terminal W Amperes A primary I1XPMR Positive sequence synchrophasor current real component Terminal X Amperes A primary I1SPMR ...

Page 718: ...yed for RTC alignment Kilo Volts kV primary V1YPMID Positive sequence synchrophasor voltage imaginary component Terminal Y delayed for RTC alignment Kilo Volts kV primary V1ZPMID Positive sequence synchrophasor voltage imaginary component Terminal Z delayed for RTC alignment Kilo Volts kV primary IAWPMMD IBWPMMD ICWPMMD Synchrophasor current magnitude Terminal W delayed for RTC alignment Amperes A...

Page 719: ...for RTC alignment Amperes A primary I1XPMID Positive sequence synchrophasor current imaginary component Terminal X delayed for RTC alignment Amperes A primary I1SPMID Positive sequence synchrophasor current imaginary component Terminal S delayed for RTC alignment Amperes A primary SODPMD Second of day of the synchrophasor data packet delayed for RTC alignment Seconds s FOSPMD Fraction of second of...

Page 720: ...Hz FREQP Frequency for under overfrequency elements Hertz Hz Remote Analogs RA001 RA256 Remote analogs N A RAO01 RAO64 Remote analog output N A Out Of Step SCV Unfiltered swing center voltage Per unit pu Relay Temperature RLYTEMP Relay temperature temperature of the enclosure C degrees Celsius Table 12 2 Analog Quantities Sorted by Function Sheet 13 of 13 Labels Description Unit ...

Page 721: ...ndard release adds new functionality to the firmware beyond the specifica tions of the existing version A point release is reserved for modifying firmware functionality to conform to the specifications of the existing version A standard release is identified by a change in the R number of the device FID number Existing firmware FID SEL 421 x R100 V0 Z001001 Dxxxxxxxx Standard release firmware FID ...

Page 722: ...te an enabled or disable transition of the IEC 61850 Buffer Report Control Block BRCB by sending an over flow flag on the next report sent after the transition Modified IEEE 1588 PTP power profile to be supported in Parallel Redundancy Protocol PRP mode Modified firmware to only reset breaker monitor data for the breaker selected In prior firmware some data were being reset for all breakers Modifi...

Page 723: ...20171021 SEL 421 5 R321 V2 Z023013 D20171021 Includes all the functions of SEL 421 4 R321 V1 Z023013 D20170820 and SEL 421 5 R321 V1 Z023013 D20170820 with the following addition Enhanced memory read diagnostics 20171021 SEL 421 4 R321 V1 Z023013 D20170820 SEL 421 5 R321 V1 Z023013 D20170820 Includes all the functions of SEL 421 4 R321 V0 Z023013 D20160624 and SEL 421 5 R321 V0 Z023013 D20160624 w...

Page 724: ... 20160111 SEL 421 4 R319 V2 Z021013 D20170820 SEL 421 5 R319 V2 Z021013 D20170820 Includes all the functions of SEL 421 4 R319 V1 Z021013 D20160506 and SEL 421 5 R319 V1 Z021013 D20160506 with the following addition Resolved an issue where certain Ethernet traffic could cause diagnostic restarts 20170820 SEL 421 4 R319 V1 Z021013 D20160506 SEL 421 5 R319 V1 Z021013 D20160506 Includes all the funct...

Page 725: ...nsmitted Telnet messages Updated the profile and compressed profile commands PRO and CPRO respectively to display the available analog signal profiling records regardless of the state of the signal profile enable SPEN set ting Changed the result of a SELOGIC control equation math error from NAN not a number to the previously stored valid result Improved Port 5 functionality to disable auto message...

Page 726: ...R316 V0 Z019013 D20130627 SEL 421 5 R316 V0 Z019013 D20130627 Increased the pickup timer for the dSCV1_S comparison logic in the relay three phase fault detector DTF logic to 20 cycles to ensure proper operation during very slow power swings Added a VMEMC setting that selects between short or medium length memory voltage as the polarizing quantity in distance calculations The relay uses the medium...

Page 727: ...al elements to supervise pilot tripping elements Made mho calculation analogs available to the Event Report Enhanced the fault identification logic to be secure during weak infeed conditions Implemented multiple updates to the DNP3 control point operation SEL 421 4 R312 V0 Z016013 D20120919 SEL 421 5 R312 V0 Z016013 D20120919 Changed the default Group Setting ARESE from Y to N 20120919 SEL 421 4 R...

Page 728: ...the DNP Fault Time values so they can no longer report incor rect time stamps Added over and under voltage elements SEL 421 4 R309 V0 Z014013 D20110923 SEL 421 5 R309 V0 Z014013 D20110923 Improved performance of the Ethernet port Reduced DNP current magnitude zeroing from 5 to 0 5 of INOM 20110923 SEL 421 4 R307 V0 Z014013 D20110628 SEL 421 5 R307 V0 Z014013 D20110628 Fixed the relay file system t...

Page 729: ...sent the ICD ClassFileVersion e g 004 The ClassFileVersion increments when there is a major addition or change to the IEC 61850 implementation of the relay Table A 3 lists the ICD file versions a description of modifications and the instruction manual date code that corresponds to the versions The most recent version is listed first NOTE All revisions of SELBOOT listed in this table are compatible...

Page 730: ...9 FC d Minimum Relay Firmware and Class File Version e g 311005 RD Release Date Code e g 20150219 a The configVersion can be determined for the IED by performing an ID ASCII command from a terminal connection b The FC in this configVersion does not have a meaningful value c This is the ICD file revision number not IED firmware revision number d FC consists of six digits The first three following t...

Page 731: ...ance reach for quadrilateral phase distance elements in Table 5 56 Quadrilateral Phase Distance Element Settings Section 6 Modified the range of the resistance reach for the quadrilateral distance elements in the examples Modified the range of the blinders R1 for the conventional out of step elements Section 7 Updated Table 7 8 Event Report Nonvolatile Storage Capability when ERDIG S Added Table 7...

Page 732: ...te Code 20171021 Firmware ICD File and Manual Versions Instruction Manual Command Summary Added COM PTP CFG CTNOM and CFG NFREQ 20160615 Initial version Table A 4 Instruction Manual Revision History Sheet 3 of 3 Date Code Summary of Revisions ...

Page 733: ... 2 3 to an SEL 421 4 5 Relay Word Bit Changes Relay Word bits are used in SELOGIC control equations and many other settings The SEL 421 4 5 relays offer the following protection functions in addition to the proven protection elements of the SEL 421 2 3 relays SEL 421 4 Zero setting out of step power swing element Standard phase quadrilateral distance elements SEL 421 5 Zero setting out of step pow...

Page 734: ...d the new Y and Z quanti ties Table B 2 Analog Quantity Differences Sheet 1 of 2 Old Line Name New Y Terminal Name New Z Terminal Name VALPMMD VAYPMMD VAZPMMD VBLPMMD VBYPMMD VBZPMMD VALPMM VAYPMM VAZPMM VBLPMM VBYPMM VBZPMM VCLPMM VCYPMM VCZPMM VALPMA VAYPMA VAZPMA VBLPMA VBYPMA VBZPMA VCLPMA VCYPMA VCZPMA VALPMR VAYPMR VAZPMR VBLPMR VBYPMR VBZPMR VCLPMR VCYPMR VCZPMR VALPMI VAYPMI VAZPMI VBLPMI ...

Page 735: ...uantity Differences Sheet 2 of 2 Old Line Name New Y Terminal Name New Z Terminal Name Table B 3 Global Settings Differences Previous SEL 421 Relays SEL 421 4 5 Notes IN101P NA The SEL 421 4 5 does not support these inputs IN102P NA IN103P NA IN104P NA IN105P NA IN106P NA IN107P NA VCOMP VYCOMP VZCOMP Replaced VCOMP with VYCOMP and VZCOMP Table B 4 Group Settings Differences Previous SEL 421 Relay...

Page 736: ...enabled Table B 6 Ethernet Port Settings Differences Sheet 1 of 2 Old SEL 421 Settings New SEL 421 Settings Notes IPADDR SUBNETM IPADDR This setting now operates using CIDR rules which consolidates the old SUB NETM setting into the IPADDR setting FAILOVER NETMODE A FAILOVER of N is equivalent to a NETMODE of FIXED A FAILOVER of Y is equivalent to a NETMODE of FAILOVER NETMODE also has a SWITCHED o...

Page 737: ...SSB CLASSB1 CLASSB6 Old setting allowed 0 3 New setting has OFF 1 3 Old setting 0 is equivalent to new setting OFF ECLASSC CLASSC1 CLASSC6 Old setting allowed 0 3 New setting has OFF 1 3 Old setting 0 is equivalent to new setting OFF DECPL DECPLA1 DECPLA6 DECPLV1 DECPLV6 DECPLM1 DECPLM6 ANADB ANADBA1 ANADBA6 ANADBV1 ANADBV6 ANADBM1 ANADBM6 16BIT AIVAR1 AIVAR6 The old setting let one pick between 1...

Page 738: ...ta The new DNP3 mapping uses labels The following tables show the relationships between the old numeric references and the labels Binary Inputs MAPSEL B For numeric references 0 799 and 800 1599 see Table 6 11 from the SEL 421 0 1 2 3 Reference Manual The labels from this table will work in the SEL 421 4 5 with the exception of those noted in the Relay Word bit mapping Table B 7 Indexes that corre...

Page 739: ...002 etc References 266 271 are reserved and can map to hard 0 References 272 and above map to the Relay Word starting at bit 0 with the exception of those noted in Table B 8 See Section 11 Relay Word Bits for the Relay Word Binary Outputs Table B 8 Binary Inputs Point Mapping for MAPSEL E Numeric Reference Label Reference Notes 0 RLYDIS 1 STFAIL 2 STWARN 3 UNRDEV 4 STSET 5 11 0 12 No equivalent 13...

Page 740: ...B10 29 RB11 RB12 30 RB13 RB14 31 RB15 RB16 32 OC1 CC1 33 OC2 CC2 34 35 NOOP 36 RST_DEM 37 RST_PDM 38 RST_ENE 39 Operated both RST_BK1 and RST_BK2 40 RSTTRGT 41 NXTEVE 42 Operated RST MML RSTMMB1 and RSTMMB2 43 NOOP 44 RB17 45 RB18 46 RB19 47 RB20 48 RB21 49 RB22 50 RB23 51 RB24 52 RB25 53 RB26 54 RB27 55 RB28 56 RB29 57 RB30 58 RB31 59 RB32 Table B 9 Binary Outputs Point Mapping Sheet 2 of 3 Numer...

Page 741: ...Table B 9 Binary Outputs Point Mapping Sheet 3 of 3 Numeric Reference Label Reference Notes Table B 10 Counters Point Mapping Numeric Reference Label Reference Notes 0 ACTGRP 1 0 2 0 3 No equivalent defined 4 BKR1OPA 5 BKR1OPB 6 BKR1OPC 7 BKR2OPA 8 BKR2OPB 9 BKR2OPC Table B 11 Analog Inputs Point Mapping Sheet 1 of 5 Numeric Reference Label Reference Notes 0 LIAFM 1 LIAFA 2 LIBFM 3 LIBFA 4 LICFM 5...

Page 742: ... B2IBFM 19 B2IBFA 20 B2ICFM 21 B2ICFA 22 35 0 36 VAFM 37 VAFA 38 VBFM 39 VBFA 40 VCFM 41 VCFA 42 VPM 43 0 44 NVS1M 45 0 46 NVS2M 47 0 48 LIGM 49 LIGA 50 LI1M 51 LI1A 52 L3I2M 53 L3I2A 54 71 0 72 3V0M 73 3V0A 74 V1M 75 V1A 76 3V2M 77 3V2A 78 83 0 84 PA_F 85 PB_F 86 PC_F 87 3P_F 88 QA_F Table B 11 Analog Inputs Point Mapping Sheet 2 of 5 Numeric Reference Label Reference Notes ...

Page 743: ...9 0 100 DC1 101 0 102 DC2 103 0 104 FREQ 105 0 106 MWHAIN 107 MWHAOUT 108 MWHBIN 109 MWHBOUT 110 MWHCIN 111 MWHCOUT 112 3MWHIN 113 3MWHOUT 114 121 0 122 IAD 123 IBD 124 ICD 125 IGD 126 3I1D 127 0 128 PAD 129 PBD 130 PCD 131 3PD 132 143 0 144 IAPKD 145 IBPKD 146 ICPKD 147 IGPKD 148 3I2PKD 149 0 150 PAPKD Table B 11 Analog Inputs Point Mapping Sheet 3 of 5 Numeric Reference Label Reference Notes ...

Page 744: ...BCWPB 171 B2BCWPC 172 175 0 176 FTYPE 177 FTAR1 178 FSLOC 179 FCURR 180 FFREQ 181 FGRP 182 FTAR2 183 0 184 FTIMEH 185 FTIMEM 186 FTIMEL 187 0 188 FSHOT2 189 195 0 196 AMV001 197 AMV002 198 AMV003 199 AMV004 200 AMV005 201 AMV006 202 AMV007 203 AMV008 204 AMV009 205 AMV010 206 AMV011 207 AMV012 208 AMV013 209 AMV014 210 AMV015 211 AMV016 Table B 11 Analog Inputs Point Mapping Sheet 4 of 5 Numeric R...

Page 745: ...mat looked like 1 addr bit If addr is 3004h or greater but not greater than 4000h then the bits can be associated with the old Relay Word Address 3004h corresponds to Relay Word 0 3005h to Row 1 etc The bits are simply references in the range 0 7 and match the bits within the Relay Word row Thus the Relay Word bits can be mapped to labels by using the old Relay Word table and correcting for any la...

Page 746: ...to remote bits Table B 13 describes the mapping for the remaining bits Table B 13 Binary Outputs Mapping for DNP3 LAN WAN Sheet 1 of 2 Numeric Reference Label Reference Notes 128 RB01 129 RB02 130 RB03 131 RB04 132 RB05 133 RB06 134 RB07 135 RB08 136 RB09 137 RB10 138 RB11 139 RB12 140 RB13 141 RB14 142 RB15 143 RB16 144 RB17 145 RB18 146 RB19 147 RB20 148 RB21 149 RB22 150 RB23 151 RB24 152 RB25 ...

Page 747: ...0 1 2 3 analog outputs were referenced by index 0 255 These mapped to remote analogs RA001 RA256 In the SEL 421 4 5 these same remote analogs are available So if previously Index 0 was referenced the new reference is RA001 Similarly Index 1 goes to RA002 etc 163 RB07 RB08 164 RB09 RB10 165 RB11 RB12 166 RB13 RB14 167 RB15 RB16 168 RB17 RB18 169 RB19 RB20 170 RB21 RB22 171 RB23 RB24 172 RB25 RB26 1...

Page 748: ...Analog outputs also available RAO01 RAO64 SER Time stamps SER quality time stamps available only for LNs included in the SER dataset Any points in the SER list will have SER quality time stamps Otherwise accuracy is within 500 ms Controls Normal Security Only Enhanced Security and Select before operate SBO available Table B 15 Default Dataset Differences Default Dataset SEL 421 0 1 2 3 SEL 421 4 5...

Page 749: ...O21 RB21 CON RBGGIO1 CO SPCSO22 RB22 RBGGIO3 CO SPCSO22 RB22 CON RBGGIO1 CO SPCSO23 RB23 RBGGIO3 CO SPCSO23 RB23 CON RBGGIO1 CO SPCSO24 RB24 RBGGIO3 CO SPCSO24 RB24 CON RBGGIO1 CO SPCSO25 RB25 RBGGIO4 CO SPCSO25 RB25 CON RBGGIO1 CO SPCSO26 RB26 RBGGIO4 CO SPCSO26 RB26 CON RBGGIO1 CO SPCSO27 RB27 RBGGIO4 CO SPCSO27 RB27 CON RBGGIO1 CO SPCSO28 RB28 RBGGIO4 CO SPCSO28 RB28 CON RBGGIO1 CO SPCSO29 RB29...

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Page 751: ... c B is channel B c M is either enabled single channel COM RTC Display statistics for synchrophasor client channels COM PTP Display a report on PTP data sets and statistics CONTROL nn Set clear or pulse an internal remote bit nn is the remote bit number from 01 32 COPY m n Copy settings between instances in the same class m and n are instance numbers for example m 1 is Group 1 n 2 is Group 2 CPR D...

Page 752: ...s SER View Sequential Events Recorder report SET Set or modify relay settings SHOW Display relay settings SNS Display Sequential Events Recorder settings name strings Fast SER STATUS Report or clear relay status and SELOGIC control equation errors SUMMARY Display a summary event report TARGET Display relay elements for a row in the Relay Word table TEC Display time error estimate display or modify...

Page 753: ... c B is channel B c M is either enabled single channel COM RTC Display statistics for synchrophasor client channels COM PTP Display a report on PTP data sets and statistics CONTROL nn Set clear or pulse an internal remote bit nn is the remote bit number from 01 32 COPY m n Copy settings between instances in the same class m and n are instance numbers for example m 1 is Group 1 n 2 is Group 2 CPR D...

Page 754: ...s SER View Sequential Events Recorder report SET Set or modify relay settings SHOW Display relay settings SNS Display Sequential Events Recorder settings name strings Fast SER STATUS Report or clear relay status and SELOGIC control equation errors SUMMARY Display a summary event report TARGET Display relay elements for a row in the Relay Word table TEC Display time error estimate display or modify...

Page 755: ...Instruction Manual PM400 01 NB SEL 400 Series Relays Instruction Manual 20171006 ...

Page 756: ...gn patents Schweitzer Engineering Laboratories Inc reserves all rights and benefits afforded under federal and international copyright and patent laws in its products including without limitation software firmware and documentation The information in this document is provided for informational use only and is subject to change without notice Schweitzer Engineering Laboratories Inc has approved onl...

Page 757: ...11 Making Simple Settings Changes 3 15 Examining Metering Quantities 3 35 Examining Relay Elements 3 43 Reading Oscillograms Event Reports and SER 3 48 Operating the Relay Inputs and Outputs 3 61 Configuring Timekeeping 3 75 Readying the Relay for Field Application 3 77 Section 4 Front Panel Operations Front Panel Layout 4 1 Front Panel Menus and Screens 4 14 Front Panel Automatic Messages 4 31 Op...

Page 758: ... 6 Duration of Data Captures and Event Reports 9 7 Oscillography 9 9 Event Reports Event Summaries and Event Histories 9 13 Sequential Events Recorder SER 9 28 Signal Profiling 9 31 Section 10 Testing Troubleshooting and Maintenance Testing Philosophy 10 1 Testing Features and Tools 10 5 Test Methods 10 7 Relay Self Tests 10 15 Relay Troubleshooting 10 18 Maintenance 10 22 TiDL Module Replacement ...

Page 759: ...TD Module Operation 15 39 Direct Networking Example 15 40 Section 16 DNP3 Communication Introduction to DNP3 16 1 DNP3 in the Relay 16 7 DNP3 Documentation 16 12 DNP3 Serial Application Example 16 26 DNP3 LAN WAN Application Example 16 31 Section 17 IEC 61850 Communication Introduction to IEC 61850 17 2 IEC 61850 Operation 17 3 Sampled Values 17 15 Simulation Mode 17 21 IEC 61850 Configuration 17 ...

Page 760: ...Link TiDL Firmware Upgrade B 15 Troubleshooting B 17 Technical Support B 18 Appendix C Cybersecurity Features Ports and Services C 1 Authentication and Authorization Controls C 2 Malware Protection Features C 3 Logging Features C 3 Physical Access Security C 4 Configuration Control Support C 4 Backup and Restore C 5 Decommissioning C 5 Vulnerability Notification Process C 5 Glossary ...

Page 761: ... 24 Table 5 5 Three Position Disconnect Switch Control Screen Status and Control Options 5 26 Table 5 6 Application Example Bay Control Settings for Bus 1 Bus 2 and Transfer Bus Bay With Ground Switch Application 5 41 Table 5 7 Application Example Front Panel Settings 5 42 Table 5 8 Application Example Output Settings Output SELOGIC Control Equations 5 43 Table 6 1 Autoreclose Logical States for C...

Page 762: ...51S1 Test Settings 10 10 Table 10 5 Alarm Relay Word Bits 10 15 Table 10 6 Troubleshooting Procedures 10 19 Table 10 7 Troubleshooting for Relay Self Test Warnings and Failures 10 20 Table 11 1 Relay Timekeeping Modes 11 2 Table 11 2 CUR_SRC Encoding 11 5 Table 11 3 Time Quality Encoding PTP Default Profile or IRIG 11 5 Table 11 4 Time Quality Encoding PTP Power Profile 11 6 Table 11 5 Date Time L...

Page 763: ...C Control Equation Math Variable Quantities 13 11 Table 13 7 Latch Bit Quantities 13 12 Table 13 8 Latch Bit Parameters 13 13 Table 13 9 Conditioning Timer Quantities 13 16 Table 13 10 Conditioning Timer Parameters 13 16 Table 13 11 Sequencing Timer Quantities 13 19 Table 13 12 Sequencing Timer Parameters 13 20 Table 13 13 Counter Quantities 13 22 Table 13 14 Counter Parameters 13 22 Table 13 15 O...

Page 764: ...4 14 Table 14 37 COM RTC Command 14 16 Table 14 38 COM RTC c C and COM RTC c R Command 14 16 Table 14 39 CON nn Command 14 16 Table 14 40 COPY Command 14 17 Table 14 41 CPR Command 14 17 Table 14 42 CSE Command 14 18 Table 14 43 CSE TERSE Command 14 19 Table 14 44 CST Command 14 19 Table 14 45 CSU Command 14 20 Table 14 46 CEV ACK Command 14 20 Table 14 47 CSU MB Command 14 20 Table 14 48 CSU N Co...

Page 765: ... Table 14 96 OPEN n Command 14 42 Table 14 97 PAC Command 14 42 Table 14 98 PAS level New_Password Command 14 42 Table 14 99 PAS level DISABLE Command 14 43 Table 14 100 PING Command 14 43 Table 14 101 PORT p Command 14 44 Table 14 102 PORT KILL n Command 14 44 Table 14 103 PRO Command 14 45 Table 14 104 PUL OUTnnn Command 14 45 Table 14 105 QUIT Command 14 46 Table 14 106 RTC Command 14 46 Table ...

Page 766: ...1 Table 15 14 EVENTS Directory Files for Event 10001 15 21 Table 15 15 SYNCHROPHASORS Directory File Sample 15 22 Table 15 16 Supported Serial Command Sets 15 22 Table 15 17 Selected ASCII Control Characters 15 24 Table 15 18 Typical Compressed ASCII Commands 15 25 Table 15 19 Fast Commands and Response Descriptions 15 28 Table 15 20 Fast Operate Command Types 15 29 Table 15 21 Fast Message Comman...

Page 767: ...Statement 17 48 Table 17 24 GetNamedVariableListAttributes Conformance Statement 17 49 Table 17 25 DeleteNamedVariableList Conformance Statement 17 49 Table 17 26 GOOSE Conformance 17 49 Table 17 27 Basic Conformance Statement 17 50 Table 17 28 ACSI Models Conformance Statement 17 50 Table 17 29 ACSI Service Conformance Statement 17 52 Table 18 1 Synchrophasor Analog Quantities Frequency 18 6 Tabl...

Page 768: ...t of Tables Table 18 24 Synchrophasor Client Status Bits 18 37 Table 18 25 Remote Synchrophasor Data Bits 18 38 Table 18 26 PMU Recording Settings 18 43 Table A 1 Instruction Manual Revision History A 1 Table B 1 Firmware Upgrade Files B 3 Table C 1 IP Port Numbers C 1 ...

Page 769: ...nic Analysis Event Waveform Screen 2 25 Figure 2 26 Sample Event Report Summary Screen 2 25 Figure 2 27 Sample Event Waveform Settings Screen 2 26 Figure 2 28 Combine Time Synchronized Events Submenu Screen 2 27 Figure 2 29 Selection of the First Event Report 2 28 Figure 2 30 First Event of the Analysis 2 28 Figure 2 31 Screen After Reading All Three Events 2 29 Figure 2 32 Screen for Selecting An...

Page 770: ...ickSet 3 50 Figure 3 42 Relay Event History Dialog Box 3 51 Figure 3 43 Sample HIS Command Output in the Terminal 3 52 Figure 3 44 EVENTS Folder Files 3 53 Figure 3 45 Relay Event History Dialog Box in QuickSet 3 54 Figure 3 46 QuickSet Event Waveform Window 3 54 Figure 3 47 Sample Event Oscillogram 3 55 Figure 3 48 Selecting SER Points and Aliases Settings in QuickSet 3 57 Figure 3 49 SER Points ...

Page 771: ...29 Figure 4 34 Relay STATUS Screens 4 30 Figure 4 35 DISPLAY TEST Screens 4 30 Figure 4 36 RESET ACCESS LEVEL Screen 4 31 Figure 4 37 One Line Diagram Screen 4 31 Figure 4 38 Sample Status Warning and Trip EVENT SUMMARY Screens 4 32 Figure 4 39 Sample Status Warning in the LCD Message Area 4 32 Figure 4 40 SEL 451 Factory Default Front Panel Target Areas 16 or 24 LEDs 4 33 Figure 4 41 SEL 451 Defa...

Page 772: ...Y 6 31 Figure 6 14 Two Circuit Breakers Single Pole Cycle State 79CY1 When E79 Y1 6 33 Figure 6 15 Two Circuit Breakers Three Pole Cycle State 79CY3 When E79 Y 6 35 Figure 6 16 Two Circuit Breakers Three Pole Cycle State 79CY3 When E79 Y1 6 38 Figure 6 17 Manual Close Logic 6 42 Figure 6 18 Voltage Check Element Applications 6 44 Figure 6 19 Voltage Check Element Logic 6 45 Figure 7 1 Complex Powe...

Page 773: ...5 I O Board Jumper Configuration 10 26 Figure 10 16 Screw Terminal Connector Receptacles 10 27 Figure 10 17 Screw Terminal Connector Keying 10 27 Figure 10 18 Screw Terminal Connector With Webs 10 28 Figure 10 19 I O Board Installation Error Message in the Terminal Window 10 29 Figure 10 20 Axion Notch Alignment 10 30 Figure 10 21 Axion Retaining Screw 10 31 Figure 11 1 PTP Time Synchronization Ov...

Page 774: ...6 26 Figure 16 6 DNP3 Application Network Diagram 16 26 Figure 16 7 SEL 421 Example DNP Map Settings 16 28 Figure 16 8 DNP3 LAN WAN Application Example Ethernet Network 16 31 Figure 16 9 Add Binary Inputs to SER Point List 16 33 Figure 17 1 MMS Client View of the CON Logical Device 17 7 Figure 17 2 Relay Predefined Reports 17 10 Figure 17 3 GOOSE Quality Attributes 17 13 Figure 17 4 Independent Bu...

Page 775: ...ith TiDL 19 2 Figure 19 3 Axion Chassis 19 3 Figure 19 4 SEL 2243 Power Coupler 19 3 Figure 19 5 SEL 2244 2 Digital Input Module 19 4 Figure 19 6 SEL 2244 5 Fast High Current Digital Output Module 19 4 Figure 19 7 SEL 2245 42 AC Analog Input Module 19 5 Figure 19 8 Example SV Network 19 6 Figure 19 9 Example Architect SV Publication Configuration 19 8 Figure 19 10 SEL 421 7 SV Subscriber Relay 4U ...

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Page 777: ...and communicating with the relay set ting and viewing passwords checking relay status viewing metering data reading event reports and Sequential Events Recorder SER records operating relay control outputs and control inputs and using relay features to make relay commissioning easier Section 4 Front Panel Operations Describes the LCD display messages and menu screens Shows you how to use front pane...

Page 778: ...ncludes details about Ethernet IP protocols SEL ASCII SEL Compressed ASCII SEL Fast Meter SEL Fast Operate SEL Fast SER and enhanced MIRRORED BITS communications Section 16 DNP3 Communication Describes the DNP3 communications proto col and how to apply this protocol to substation integration and automa tion Provides a Job Done example for implementing DNP3 in a substation Section 17 IEC 61850 Comm...

Page 779: ...atif Instruction manual Manuel d instructions General Safety Marks CAUTION There is danger of explosion if the battery is incorrectly replaced Replace only with Ray O Vac no BR2335 or equivalent recommended by manufacturer See Owner s Manual for safety instructions The battery used in this device may present a fire or chemical burn hazard if mis treated Do not recharge disassemble heat above 100 C...

Page 780: ...aintenance ou le test des ports optiques utilisez exclusivement des équipements de test homologués comme produits de type laser de Classe 1 WARNING Incorporated components such as LEDs and transceivers are not user serviceable Return units to SEL for repair or replacement AVERTISSEMENT Les composants internes tels que les leds diodes électroluminescentes et émetteurs récepteurs ne peuvent pas être...

Page 781: ...AUTION Do not install a jumper on positions A or D of the main board J21 header Relay misoperation can result if you install jumpers on positions J21A and J21D ATTENTION Ne pas installer de cavalier sur les positions A ou D sur le connecteur J21 de la carte principale Une opération intempestive du relais pourrait résulter suite à l installation d un cavalier entre les positions J21A et J21D CAUTIO...

Page 782: ...matting attributes The following table lists these conventions Example Description STATUS Commands command options and command variables typed at a command line interface on a PC n SUM n Variables determined based on an application in bold if part of a command Enter Single keystroke on a PC keyboard Ctrl D Multiple combination keystroke on a PC keyboard Start Settings PC software dialog boxes and ...

Page 783: ...ickup value Y is a time delay dropout value B asserts time X after input A asserts B will not assert if A does not remain asserted for time X If X is zero B will assert when A asserts If Y is zero B will deassert when A deasserts Rising edge of A starts timers Output B will assert time X after the rising edge of A B will remain asserted for time Y If Y is zero B will assert for a single processing...

Page 784: ...ical Support We appreciate your interest in SEL products and services If you have questions or comments please contact us at Schweitzer Engineering Laboratories Inc 2350 NE Hopkins Court Pullman WA 99163 5603 U S A Tel 1 509 338 3838 Fax 1 509 332 7990 Internet selinc com support Email info selinc com ...

Page 785: ...w and configure IEC 61850 settings via a GUI Most relays support synchrophasor measurement Synchrophasor measurements are available when a high accuracy time source is connected to the relay The relay supports the IEEE C37 118 Standard for Synchrophasors for Power Sys tems Most relays feature bay control functionality The mimic display selected is dis played on the front panel screen in one line d...

Page 786: ...s fer Protocol FTP for high speed data collection Time Domain Link TiDL Reduce costs with TiDL technology With this sim ple to configure solution the relay ac inputs and most of its digital inputs and outputs are distributed using SEL 2240 Axion modules The Axion modules are connected to the relay through use of direct fiber connec tions By placing the Axion modules near the primary equipment you ...

Page 787: ...files to and from relays Analyze events Use the integrated waveform single event reports analysis tools Control the relay Command relay operation through use of a GUI environment Execute relay serial port commands in terminal mode Configure the serial port and passwords SEL provides QuickSet for easier more efficient configuration of the relay set tings However you do not have to use QuickSet to c...

Page 788: ...mpass software will automatically check for updates on a specified schedule and facilitate the update process The Update icon on the QuickSet startup screen starts SEL Compass and checks for updates The Install Devices button on the Settings Editor Selection window starts SEL Compass and presents a menu of available drivers Check for updates in the Help menu starts SEL Compass and checks for updat...

Page 789: ...telephone number in the Phone Number text box Ethernet Card Use the optional Ethernet card for FTP and Telnet network communications FTP Setup Step 1 Access the Network dialog box from the Active Connection Type drop down menu Step 2 Click the FTP File Transfer Option button to select FTP as the net work communications protocol Step 3 Enter the IP address of the relay Ethernet port as the Host IP ...

Page 790: ...c terminal emulation Many third party terminal emulation programs are available with file transfer encoding schemes Step 1 Click the QuickSet Communication menu Step 2 Click Terminal to start the terminal window Another convenient method to start the terminal is to press Ctrl T Terminal Logging When you select the Terminal Logging check box in the Communication menu QuickSet records communications...

Page 791: ... operating characteristics that describe the relay settings including the protection scheme settings and communications settings Step 3 Highlight one of the relays listed in Settings Step 4 Click Copy to create a new collection of relay settings QuickSet prompts you to provide a new name Copy Move Relays Between Databases You can create multiple relay databases with the Database Manager these data...

Page 792: ...w Database Step 1 To create and copy an existing database of relays to a new database select the File Database Manager menu Step 2 Select Copy Move Relays Between Databases on the Database Manager dialog box QuickSet opens the last active database and assigns it as Database A see Figure 2 3 Step 3 Click on the ellipsis next to Settings Database B QuickSet prompts you for a file location Step 4 Typ...

Page 793: ...tring The Z number helps determine the proper QuickSet relay settings driver version when creating or editing relay settings files Step 3 View the QuickSet settings driver information at the bottom of the Settings Editor window The first portion of the Z number is the QuickSet settings driver version number see Figure 2 4 Step 4 Compare the QuickSet driver number and the relay FID number This Quic...

Page 794: ...line Open Open existing settings stored in a Relay Database RDB file Close Close settings instance that is open in the QuickSet window Save Save As Save settings instance that is open in the QuickSet window to the active Relay Database RDB file Print Device Settings Print standard or custom settings reports Read Read settings from a connected device and display the settings in the QuickSet window ...

Page 795: ...e file Merge Merge the settings instance that is open in the QuickSet window with another settings instance in the Relay Database file Part Number Change the current part number for the settings instance that is open in the QuickSet window Communications Connect Request QuickSet to attempt to connect to a device using the current Connection Parameters Parameters Modify the Communications Parameter...

Page 796: ...own in Figure 2 7 for the SEL 487B Step 3 Use the arrows inside the text boxes to match corresponding portions of the Device Part Number dialog box to your relay Alternatively click Edit in the lower left corner of the Device Part Number screen and paste in the desired part number Figure 2 6 Retrieving the Device Part Number Figure 2 7 Setting the Relay Part Number in QuickSet ...

Page 797: ... such as the SEL 487E have multiple setting combinations The QuickSet settings for the SEL 487E CURSTU and CURWXY are shown in Figure 2 9 and are used instead of SECINC For more information on the set tings options review the CFG CTNOM command operation in Section 2 Instal lation of the product specific instruction manual If at the time the relay settings are transferred the QuickSet settings SECI...

Page 798: ...example of relay settings categories in the Settings Editor tree view QuickSet shows all of the settings categories in the settings tree view When you enable and disable settings categories the tree view remains constant but when you click on the tree view to access the settings in a disabled category the dis abled settings are dimmed For example try the following steps Step 1 Select Global Statio...

Page 799: ...2 13 Date Code 20171006 Instruction Manual SEL 400 Series Relays PC Software Create and Manage Relay Settings Figure 2 11 Station DC Settings Figure 2 12 Enable EDCMON in Global Settings ...

Page 800: ...2 14 SEL 400 Series Relays Instruction Manual Date Code 20171006 PC Software Create and Manage Relay Settings Figure 2 13 DC Monitor Settings Enabled ...

Page 801: ... the Settings Tree View see Figure 2 14 Step 2 Click the circle buttons to select the settings class instance and cate gory that you want to change Step 3 Use the Tab key to move to the setting text book and from setting to setting when entering and editing Step 4 The right click mouse button allows access to two special functions when you are editing settings Previous Value and Default Value It a...

Page 802: ...t includes a feature called an ellipsis button see Figure 2 15 The ellipsis button is a square button with three dots as shown in Figure 2 16 Use the ellipsis button to build expressions or assist with entering settings in the relay Whether the ellipsis button is an expression builder or a setting assistant depends on the selected relay function and is preprogrammed in the relay For example Figure...

Page 803: ...es relay elements analog quan tities and SELOGIC control equation variables and focuses your equation deci sion making Expression Builder Organization The Expression Builder dialog box is organized into two main parts represent ing the left side LVALUE and right side RVALUE of the SELOGIC control equation The LVALUE is fixed for all settings except Protection Free Form SELOGIC and Automation Free ...

Page 804: ...Variables On the right side of the equation RVALUE you can select broad categories of relay elements analog quantities counters timers latches Boolean variables and math variables Step 2 Select a category in the RVALUE tree view The Expression Builder displays all elements for that category in the list box at the bottom right side Directly underneath the right side of the equation you can choose o...

Page 805: ...s the HMI window and downloads the interface data The HMI can also be accessed using the HMI icon QuickSet HMI Features Table 2 2 lists typical functions in the HMI tree view and a brief explanation of each function The specific options available for any specific relay depend on the features available in that relay Figure 2 18 Virtual Relay Front Panel Table 2 2 QuickSet HMI Tree View Functions Sh...

Page 806: ... values Automation Math Vari ables View the automation math variable values MIRRORED BITS Commu nications View the MIRRORED BITS communications analog quantities Through Faults View the through fault data Thermal Monitoring View the most recent saved thermal report of the transformer s monitored by the device Breaker n Monitoring n can be S T U W or X View a comprehensive circuit breaker report th...

Page 807: ... other HMI branches including fundamental metering contact input output status and front panel LED status The Device Overview colors and text can be customized White LED symbols indicate a deasserted condition and LED symbols with any other color indicate an asserted condition Click an LED symbol to change its assert color HMI Control Window Select the Control Window branch to reset metering value...

Page 808: ...Default check box Analyze Events QuickSet has integrated analysis tools that help you retrieve information about protection system operations quickly and easily Use the protection system event information that relays store to evaluate the performance of a protection system Event Waveforms Relays record power system events for all trip situations and for other operating conditions programmed with S...

Page 809: ...ram occurrences These function keys and related functions help in event analysis F2 go to trigger F3 Cursor 1 F4 Cursor 2 The display shows the time difference between Cursor 1 and Cursor 2 To see high accuracy time stamp information on the event oscillogram click the Pref button at the bottom of the oscillogram select Time under Time Units Starting Ending Row and click OK Click on any point in a ...

Page 810: ...uickSet also presents a harmonic analysis of power system data for raw data event captures From the View menu click Harmonic Analysis The window will be similar to Figure 2 25 On the left side of the Harmonic Analysis screen choose the relay voltage and current channels to monitor for harmonic content Click the arrows of the Data Scroll box or the Cycles box to change the data analysis range Figur...

Page 811: ... Click Summary Data on the View menu to see event summary information and to confirm that you are viewing the correct event Figure 2 26 shows a sample QuickSet Event Report Summary screen Figure 2 25 Sample Harmonic Analysis Event Waveform Screen Figure 2 26 Sample Event Report Summary Screen ...

Page 812: ... type eventSettings screen Aligning Events There are times when it is desirable to look at data from multiple device event reports simultaneously This is especially valuable with the SEL 487B when a set of three relays are acting as single phase relays on a single system Once you have the event reports retrieved and saved you can view them together using the following procedure Figure 2 27 Sample ...

Page 813: ... lines also appear at the bottom of the screen where they show the relative overall time relationship between the events the trigger time of each event and the number of cycles of each event The event time control lines are color coded with red Event 1 on top green Event 2 in the center and blue Event 3 at the bottom A flashing arrow points to a button for Event 1 Step 2 Click the button for Event...

Page 814: ...2 30 Notice that the actual event control line of the first events now appears at the bot tom of the screen and becomes the reference time position All other events must overlap the reference time position by at least one data point The software posi tions the subsequent events relative to the position of the first event Figure 2 29 Selection of the First Event Report Figure 2 30 First Event of th...

Page 815: ... steps for Event 3 Figure 2 31 shows the screen after reading all three events The information displayed at the bottom of the screen shows that we have opened three events but have not yet selected any analog channels or digital Relay Word bits from these events Step 7 Click on the Select Channels tab to select analog channels and digi tal Relay Word bits Figure 2 32 shows the screen for selecting...

Page 816: ...el 1_ FDR _1 from the Event Analogs window to the Combine Analogs window Alternatively select the channels to be removed and press the Delete key Drag and drop is similarly supported for digital channels Step 15 Select a channel Step 16 Drop the selection into the Event Analogs or Event Digitals window to remove channels from the Combined Analogs or Combined Dig itals windows Figure 2 33 shows the...

Page 817: ...e values of interest from the Analogs window Step 19 Drop these selections in any one of the six available Axis windows You can select as many as 12 analog channels Figure 2 34 shows an example after selecting all three analog channels on Axis 1 for analysis Step 20 Click OK to view the report The software displays the three traces on the same graph as shown in Figure 2 35 Figure 2 34 Data From Th...

Page 818: ...ays to access help are shown in Table 2 3 Table 2 3 Accessing QuickSet Help Help Description General ACSELERATOR QuickSet Select Help Contents from the main menu bar HMI Application Select Help HMI Help from the main menu bar Relay Settings Select Help Settings Help from the from the main menu bar Database Manager Select Help from the bottom of the Database Manager window Communications Parameters...

Page 819: ...3 75 Readying the Relay for Field Application on page 3 77 Perform these tasks to gain a good understanding of relay operation be able to confirm that the relay is properly connected and be more effective when using the relay To work through the examples in this section you need to install the relay either in a final installation or in a laboratory configuration See Section 2 Installation in the p...

Page 820: ...se this page for ordering a relay For ordering information refer to the relay Model Option Table available at selinc com or contact your SEL Sales Representatives Figure 3 1 shows a serial number label for an SEL 451 with additional I O in a 4U horizontal chassis This example serial number label is for a 5 A per phase secondary CT input relay For information on CT and PT inputs Do not use this pag...

Page 821: ...com municate with the relay Front panel control of relay functions involves use of a menu system that you access through the LCD and the six navigational pushbuttons shown in Figure 3 2 For complete instructions on using the front panel menu system see Front Panel Menus and Screens on page 4 14 Fast and efficient communication with the relay is available through communica tions ports such as PORT ...

Page 822: ...erial cables to connect to the relay Use an SEL C234A cable to connect a 9 pin computer serial port to the relay Use an SEL C227A cable to connect a 25 pin computer serial port to the relay For computers with USB ports use an SEL C662 USB to serial cable to connect to the relay See Section 15 Communications Interfaces for further information on serial communications connections These and other cab...

Page 823: ...net protocol with the SET P 5 command using any of the serial ports Command SET P 5 accesses settings for all Ethernet ports on the relay Make the following settings using the SET P 5 command EPORT Y IPADDR IP Address assigned by network administrator in CIDR notation DEFRTR Default router gateway IP Address assigned by network administrator NETMODE SWITCHED ETELNET Y NOTE Telnet works with other ...

Page 824: ...browser and browse to http IPADDR where IPADDR is the Port 5 setting IPADDR e g http 192 168 1 2 The relay responds with a login screen as shown in Figure 3 4 Choose ACC for the username type in the relay Access Level 1 password and click Submit The only username allowed is ACC The relay responds with the homepage shown in Figure 3 5 While you remain logged in to the relay the web page displays th...

Page 825: ...tory default passwords pro grammed in the relay Setting unique passwords for the relay access levels increases the security of your substation and the power system This subsection begins with information on the access level password system in SEL 400 relays and includes an example of changing the default passwords Access Levels Access levels control whether you can perform different operations wit...

Page 826: ...hat level Table 3 3 lists the access level com mands with corresponding passwords Figure 3 6 Access Level Structure Table 3 2 SEL 400 Series Relay Access Levels Access Level Prompt Allowed Operations 0 Log in to Access Level 1 1 View data and status information B Access Level 1 functions plus breaker control and data P P Access Level B functions plus protection settings A A Access Level B function...

Page 827: ... Access Level 1 To enter Access Levels B P A O and 2 you must enter a correct password from Access Level 1 The front panel LCD displays a password prompt when you attempt to control the relay at any access level higher than Access Level 1 For more information on entering passwords from the front panel see PASSWORD on page 14 42 The front panel MAIN MENU item RESET ACCESS LEVEL returns the relay to...

Page 828: ...a tions from the front panel Passwords are case sensitive This device is shipped with default passwords Default passwords should be changed to private passwords at installation Failure to change each default password to a private pass word may allow unauthorized access SEL shall not be responsible for any damage resulting from unauthorized access It is important that you change all of the password...

Page 829: ...on entering that access level If you forget a password or encounter difficulty changing the default passwords you can temporarily disable password verification See Section 2 Installation in the product specific instruction manual for information on the password disable jumper Checking Relay Status With continual self testing the relay monitors the internal operation of all cir cuits to verify opti...

Page 830: ...0 Checking Relay Status in QuickSet You can use QuickSet to check relay status Use the HMI Meter Control menu to view status conditions The procedure in the following steps assumes that you have successfully estab lished communication with the relay see Making an EIA 232 Serial Port Con nection on page 3 4 In addition you must be familiar with relay access levels and passwords see Changing the Def...

Page 831: ...QuickSet window says Connected Step 2 Confirm that you have loaded the correct passwords in QuickSet a Enter your Access Level 1 password in the Level One Password text box and your Access Level 2 password in the Level Two Password text box b Click OK to accept changes and close the dialog box Step 3 Click Tools in the top toolbar and select the HMI menu to start the QuickSet operator interface St...

Page 832: ... 2 Press the ENT pushbutton to display the MAIN MENU as shown in Figure 3 10 Step 3 View the relay status a Press the Up Arrow and Down Arrow navigation pushbuttons to highlight the RELAY STATUS action item see Figure 3 10 b Press the ENT pushbutton You will see the RELAY STATUS screen the second screen of Figure 3 10 Step 4 Press the ESC pushbutton to return to the MAIN MENU Step 5 Press ESC push...

Page 833: ...n the active settings Unused relay elements and inactive settings are dimmed grayed in the QuickSet menus See Section 2 PC Software for more information on QuickSet Settings Structure SEL 400 series relays use a settings structure that assigns each relay setting to a specific location based on the setting type A top down organization allocates relay settings into these layers Class Instance Catego...

Page 834: ...ing Load Encroachment Load Encroachment ZLF ZLF ZLR ZLR Setting Setting Table 3 4 SEL 451 Settings Classes and Instances Sheet 1 of 2 Class Description Instance Description ASCII Command Access Level Global Relay wide applications settings Global SET G P A O 2 Group Individual scheme settings Group 1 Group 6 Group 1 settings Group 6 settings SET 1 SET S 1 SET 6 SET S 6 P 2 Breaker Monitor Circuit ...

Page 835: ... prompts for the Group 6 settings Alias Settings Although the relay provides extensive programming facilities and opportunity for comments troubleshooting customized programs is sometimes difficult Aliases provide an opportunity to assign more meaningful names to the generic variable names in order to improve the readability of the program Front Panel Front panel HMI settings Front Panel SET F P A...

Page 836: ...mmunications terminal b Type the Access Level 1 password and press Enter You will see the Access Level 1 prompt c Type 2AC Enter d Type the correct password to go to Access Level 2 You will see the prompt Step 2 Type SET T Enter to access the alias settings Figure 3 13 shows a representative computer terminal screen Step 3 Type Enter for the relay to display the first line that you can edit Step 4...

Page 837: ...input by presenting an action prompt You have many options for navigating the settings at the prompt Table 3 5 lists the operations possible from a settings action prompt SET T Enter Alias Relay Aliases RW Bit or Analog Qty 7 Character Alias 0 9 A Z _ 1 EN RLY_EN Enter 2 PMV01 THETA Enter 3 PMV02 TAN Enter 4 END Enter Alias Relay Aliases RW Bit or Analog Qty 7 Character Alias 0 9 A Z _ 1 EN RLY_EN...

Page 838: ...the setting name and Enter To start at the beginning of the Global settings simply type SET G Enter without a set tings name Step 1 Prepare to control the relay at Access Level 2 a Using a communications terminal type ACC Enter b Type the Access Level 1 password and press Enter You will see the Access Level 1 prompt Figure 3 15 Components of SET Commands Table 3 5 Actions at Settings Prompts Actio...

Page 839: ...ction prompt Note that SELOGIC control equation settings such as FAULT in Figure 3 16 can appear on multiple lines b If you make a mistake or want to go backward through the settings type the character on most computer keyboards this is a shifted numeral 6 and Enter Refer to Table 3 5 for this and other navigational aids Step 5 End the settings session a Type END Enter at the FAULT action prompt T...

Page 840: ...ms per line After you enter each line the relay checks the validity of the setting If the entered setting is invalid the relay responds with an error message and prompts you again for the setting Making Text Edit Mode Settings Changes The procedure in the following steps familiarizes you with basic text edit mode line editing Table 3 6 Actions at Text Edit Mode Prompts Action Relay Response Enter ...

Page 841: ...ll see the Access Level 1 prompt c Type 2AC Enter d Type the Access Level 2 password and press Enter You will see the Access Level 2 prompt Step 2 Access the display point settings a Type SET F Enter to modify the front panel settings b Advance through the front panel settings repeatedly type and then Enter until you reach the Display Points category Figure 3 17 shows a representative terminal scr...

Page 842: ...ith setting EICIS To change the input conditioning enter the following settings EICIS Y Enable Independent Control Input Settings Y N IN105PU 0 3750 Pickup Delay for Contact Input IN105 0 0000 5 cyc IN105DO 0 3750 Dropout Delay for Contact Input IN105 0 0000 5 cyc Use the appropriate interface hardware to connect the fan running sensor to IN105 Choose any relay input that conforms to your requirem...

Page 843: ...ccess Level 2 a Using a communications terminal type ACC Enter b Type the Access Level 1 password and press Enter You will see the Access Level 1 prompt c Type 2AC Enter d Type the correct password to go to Access Level 2 You will see the Access Level 2 prompt Step 2 Access the Notes settings a Type SET N Enter to access the Notes settings b At the Line 1 settings prompt type the Line 1 text shown...

Page 844: ... a previously used display point In the SET F command at the Display Points and Aliases prompt use the text edit mode line editing commands to set and delete the display points This proce dure shows two previously programmed display points that indicate on the front panel LCD the status of Circuit Breaker 1 and Circuit Breaker 2 Relay control inputs IN101 and IN102 are the Relay Word bits for the ...

Page 845: ...r to examine the remaining display points Former Display Point 2 is eliminated and Display Point 3 moves up to position 2 The relay returns to Line 2 followed by the settings prompt Example 3 3 Deleting a Display Point Continued Display Points Boolean RWB Name Label Set String Clear String Text Size Analog Analog Quantity Name User Text and Formatting Text Size 1 IN101 CB1 CLOSED OPEN S LIST Enter...

Page 846: ...r with relay access levels and passwords see Changing the Default Passwords in the Terminal on page 3 10 to change the default access level passwords You should also be familiar with QuickSet see Section 2 PC Software and Checking Relay Status in QuickSet on page 3 12 Step 1 Start QuickSet and establish a connection with the relay See Step 1 and Step 2 of Checking Relay Status in QuickSet on page ...

Page 847: ... Value Right click in the setting dialog box and select Previous Value if you want to revert to the setting value before you made a change Right click in the setting dialog box and select Default Value if you want to restore the factory default setting value Step 5 Save the new settings in QuickSet a In the File menu click Save b Specify a Settings Name c Click OK Step 6 Upload the new settings to...

Page 848: ... g long SELOGIC control equations However if you need to make a quick correc tion or have no faster means to make settings settings functions are available at the front panel For more information on making settings changes from the front panel see Set Show on page 4 25 Entering DATE and TIME From the Front Panel The purpose of the procedure in the following steps is to familiarize you with enterin...

Page 849: ...rrow and Down Arrow navigation pushbuttons to highlight the DATE TIME action item Figure 3 23 second screen b Press the ENT pushbutton The relay next displays the DATE TIME submenu the third screen of Figure 3 23 Figure 3 23 DATE and TIME Settings From Front Panel LCD a b METER EVENTS BREAKER MONITOR RELAY ELEMENTS LOCAL CONTROL SET SHOW RELAY STATUS VIEW CONFIGURATION DISPLAY TEST RESET ACCESS LE...

Page 850: ...nel as in the previous exam ple press the ESC key repeatedly until you see the MAIN MENU b If the relay is displaying the ROTATING DISPLAY press the ENT pushbutton to display the MAIN MENU Figure 3 24 a shows the MAIN MENU at the beginning of the front panel settings process Step 2 View the settings screens a Press the Up Arrow and Down Arrow navigation pushbuttons to highlight the SET SHOW action...

Page 851: ...t a different speed d Once you have selected a data speed press the ENT pushbutton NOTE Once you have changed communications parameters you must change the corresponding parameters in your terminal emulation program to communicate with the relay via a communications port Step 6 End the settings session a The relay returns to the previous category settings list screen Press ESC to return to the cat...

Page 852: ...rt F SPEED 9600 DATABIT 8 PARITY N STOPBIT 1 RTSCTS N Communications Setti Data Speed 300 to 5 300 600 1200 2400 4800 9600 19200 38400 57600 SPEED a b c d e f METER EVENTS BREAKER MONITOR RELAY ELEMENTS LOCAL CONTROL SET SHOW RELAY STATUS VIEW CONFIGURATION DISPLAY TEST RESET ACCESS LEVEL MAIN MENU SET SHOW PORT GLOBAL GROUP ACTIVE GROUP 1 DATE TIME SELECT A CATEGORY SELECT AN INSTANCE SELECT A CL...

Page 853: ...page 3 10 to change the default access level passwords Step 1 through Step 7 are necessary if you have not yet configured the relay and want to test metering using a test source If the relay is already connected to the system you may jump to Step 8 to view the sys tem metering information Step 1 Prepare to control the relay at Access Level 2 a Using a communications terminal type ACC Enter b Type ...

Page 854: ... and three current sources are available connect the sources to the relay as shown in Figure 3 27 If three voltage sources and two current sources are available use the connection diagram of Figure 3 28 b Apply 67 V per phase line to neutral in ABC phase rotation c Apply 2 0 A per phase in phase with the applied phase voltages SET G ESS TERSE Enter Global Current and Voltage Source Selection Curre...

Page 855: ...Current Sources for Three Phase Faults and METER Test Three Phase Voltage and Current Test Sources IA VB IB VC IC VA IAW Z01 Z02 Z03 Z04 Z05 Z06 Z13 Z14 Z15 Z16 Z17 Z18 IBW ICW VAY VBY VCY Relay Rear Panel Analog Voltage and Current Inputs N N N Three Phase Voltage and Current Test Sources IAW Z01 Z02 Z03 Z04 Z05 Z06 Z13 Z14 Z15 Z16 Z17 Z18 IBW ICW VAY VBY VCY Relay Rear Panel Analog Voltage and C...

Page 856: ...ng the Default Passwords in the Terminal on page 3 10 to change the default access level passwords You should also be familiar with QuickSet see Checking Relay Status in QuickSet on page 3 12 and Section 2 PC Software Step 1 Start QuickSet and establish a connection with the relay See Step 1 and Step 2 of Checking Relay Status in QuickSet on page 3 12 for details on how to do this Step 2 Set the r...

Page 857: ...hoose 1 from the drop down menu under ESS Current and Voltage Source Selection Step 4 Set PT and CT ratios a In the QuickSet Settings tree view click the drop down arrow next to Group 1 to expand this branch see Figure 3 31 b Click the drop down arrow next to Set 1 c Click Line Configuration You will see the Line Configuration window similar to Figure 3 31 d Enter setting CTRW Current Transformer ...

Page 858: ...In the top toolbar select Tools HMI HMI to start the GUI Step 7 Click the Phasors button of the HMI tree view see Figure 3 32 to view phasors QuickSet displays fundamental line metering quantities with a display similar to Figure 3 33 The test setup is adjusted for an approximately 30 degree lagging current Figure 3 31 Group 1 Terminal Configuration Settings in QuickSet ...

Page 859: ...3 41 Date Code 20171006 Instruction Manual SEL 400 Series Relays Basic Relay Operations Examining Metering Quantities Figure 3 32 HMI Phasors View in QuickSet ...

Page 860: ...nd this example assumes that you have not enabled the demand metering or synchro nism check features Step 1 Prepare to use the front panel by applying power to the relay Note that the LCD shows a sequence of screens called the ROTATING DISPLAY If you do not operate the front panel for a certain period the relay will enter front panel time out mode and you will see the sequential screens of the ROT...

Page 861: ...elay Elements Use the communications port TAR command or the front panel to display the state of relay elements control inputs and control outputs Viewing a change in relay element Relay Word bit status is a good way to verify the pickup settings you have entered for protection elements Figure 3 34 Front Panel Screens for METER VOLTAGE kV VA 133 9 0 VB 133 9 120 VC 133 9 120 CURRENT A IA 400 5 31 ...

Page 862: ...utput level b Connect a single phase current output of the test source to the IAW analog input Step 4 Type TAR 50P1 Enter to view the initial element status The relay returns a target terminal screen similar to that shown in Figure 3 35 Step 5 View the element status change a Type TAR 50P1 1000 Enter this command causes the relay to repeat the TAR 50P1 command 1000 times For more infor mation on t...

Page 863: ...se the navigation keys to highlight 5 and then press ENT to enter the character 5 in the text input field c Enter the 0 P and 1 characters in the same manner d Highlight ACCEPT and press ENT The relay displays the LCD screen containing the 50P1 element as shown Figure 3 36 d Figure 3 36 Viewing Relay Word Bits From the Front Panel LCD ELEMENT SEARCH A B C D E F G H I J K L M N O P Q R S T U V W X ...

Page 864: ...in the following steps shows you how to use a front panel LED to view a change in state for the SEL 451 50P1 Phase Instantaneous Overcurrent element In this example use QuickSet to configure the relay You must have a computer that is communicating with the relay and running QuickSet see Making Settings Changes in Initial Global Settings on page 3 20 In addition you need a variable current source s...

Page 865: ...the SEL 451 a Click File Send QuickSet prompts you for the settings class you want to send to the relay as shown in the Group Select dialog box of Figure 3 38 b Click the check box for Front Panel c Click OK The relay responds with the Transfer Status dialog box shown in Figure 3 38 If you see no error message the new settings are loaded in the relay Figure 3 37 Setting Pushbutton LED Response in ...

Page 866: ...for storing and reporting power sys tem events These include high resolution oscillography with sampling as high as 8 kHz event reports that encompass important variables in the power system and the SER that reports changing power system conditions and relay operating states You can view oscillograms taken from high resolution raw data or from filtered event report data Each type of presentation g...

Page 867: ...nging these default settings to match your application This example assumes that you have successfully established communication with the relay see Making an EIA 232 Serial Port Connection on page 3 4 In addition you must be familiar with relay access levels and passwords see Changing the Default Passwords in the Terminal on page 3 10 to change the default access level passwords You should also be...

Page 868: ...scribes how to view the event history data with QuickSet and how to examine the history data through use of the ASCII terminal interface Reading the Event History in QuickSet The procedure in the following steps shows how to use the QuickSet HMI to gather relay event history information See Event History on page 9 27 for more information on event history This example assumes that you have successf...

Page 869: ... shown in Figure 3 42 Reading the Event History in the Terminal The procedure in the following steps shows how to use the relay HIS command to confirm that you captured power system data with an event trigger This exam ple assumes that you have successfully established communication with the relay see Making an EIA 232 Serial Port Connection on page 3 4 In addition you must be familiar with relay ...

Page 870: ...in Generating an Event on page 3 49 The procedure in the following steps shows you how to retrieve the high resolution raw oscillography data for this event Perform the steps listed in Generating an Event on page 3 49 before executing the instructions in this example For this procedure you must use a communica tions terminal emulation computer program capable of file transfers If you need help fin...

Page 871: ...erred successfully you have the entire COMTRADE file for the high resolution raw data capture Step 5 Use ACSELERATOR Analytic Assistant SEL 5601 Software SYN CHROWAVE Event QuickSet or other COMTRADE capable pro grams to play back high resolution raw data oscillograms of the high resolution raw data capture files you just transferred Retrieving High Resolution COMTRADE Data in QuickSet The procedu...

Page 872: ... similar to that shown in Figure 3 45 Step 3 Get the event a Highlight the event you want to view and click Get Selected Events b After getting the event QuickSet prompts you to save the event file DAT in a directory c Click Tools Events and select the saved event file dat d Press Open QuickSet then presents the window similar to that in Figure 3 46 and the sample event oscillogram of Figure 3 47 ...

Page 873: ...ed in Generating an Event on page 3 49 The procedure in the following steps shows you how to retrieve the event report data files for this event Perform the steps listed in Generating an Event on page 3 49 before executing the instructions in this example For this procedure you must use a terminal program capable of Ymodem protocol file transfer Step 1 Prepare to monitor the relay at Access Level ...

Page 874: ...le record Use the relay com munications ports or QuickSet to view the SER records For more information on the SER see Section 9 Reporting The latest 200 SER events are viewable from the front panel For more informa tion see Section 4 Front Panel Operations Setting the SER and Examining an SER Record in QuickSet The procedure in the following steps shows you how to use QuickSet to program relay ele...

Page 875: ...nstruction Manual SEL 400 Series Relays Basic Relay Operations Reading Oscillograms Event Reports and SER Figure 3 48 Selecting SER Points and Aliases Settings in QuickSet Figure 3 49 SER Points and Aliases Settings in QuickSet ...

Page 876: ...et Alias field f Type OFF in the Clear Alias field g Click OK Step 5 Click File Save to save the new settings in QuickSet Step 6 Upload the new settings to the relay a Click File Send QuickSet prompts you for the settings class you want to send to the relay as shown in the first dialog box of Figure 3 50 b Click the Report check box c Click OK QuickSet responds with the second dialog box of Figure...

Page 877: ...ESET button when you press the pushbutton and it remains asserted for one processing interval Setting the SER and Examining the SER Record in the Terminal The procedure in the following steps shows how to use a terminal connected to a relay communications port to set an element in the SER Use text edit mode line editing to enter the SER settings see Text Edit Mode Line Editing on page 3 22 Also in...

Page 878: ...Type SER Enter at the Access Level 1 prompt or higher to view the SER report The relay presents a screen similar to the SER display of Figure 3 52 Downloading an SER Report File The procedure in the following steps shows you how to retrieve the SER report stored in the relay as a file For this procedure you must use a terminal emulation program with file transfer capability Step 1 Prepare to monit...

Page 879: ...essfully use a word pro cessing program to view the contents of the file You will see the SER records in a format similar to Figure 3 52 Operating the Relay Inputs and Outputs SEL 400 series relays give you great ability to perform control actions at bay and substation locations via the relay control outputs The control outputs close and open circuit breakers switch disconnects and operate auxilia...

Page 880: ...Enter d Type the correct password to go to Access Level B You will see the Access Level B prompt Step 2 Attach an indicating device ohmmeter with a beep sounder or a test set to the terminals for control output OUT104 This output is a standard control output and is not polarity sensitive Step 3 Perform the pulse operation a Type PULSE OUT104 Enter The relay confirms your request to pulse an output...

Page 881: ...rrow navigation pushbuttons to highlight the LOCAL CONTROL action item as shown in Figure 3 56 a b Press the ENT pushbutton You will see the LOCAL CONTROL submenu as shown in Figure 3 56 b Step 5 View the OUTPUT TESTING screen a Press the Up Arrow and Down Arrow navigation pushbuttons to highlight the OUTPUT TESTING action item as shown in Figure 3 56 b b Press the ENT pushbutton The relay display...

Page 882: ... to highlight ACCEPT and press ENT The relay pulses the output and you will see the indicating device turn on for a second and then turn off Controlling a Relay Control Output With a Local Bit in the Terminal In this example you set Local Bit 3 to start the transformer cooling fans near the breaker bay where you have installed the SEL 451 Thus you can use the LCD screen and navigation pushbuttons ...

Page 883: ...ter at the Line prompt The relay checks that this is a valid entry and responds with the next line prompt 2 followed by the settings prompt Step 5 End the settings session a Type END Enter The relay displays a readback of all the front panel settings eventually displaying the Save settings Y N prompt In Figure 3 58 a vertical ellipsis represents the readback At theendofthereadbackinformation justb...

Page 884: ...screen as shown in Figure 3 60 b d Press ENT to see the 5 MVA XFMR Fans as shown in Figure 3 60 c e Highlight 1 ON and press ENT The graphical local control handle moves to the 1 position At this time the transformer fans will begin running SET O OUT105 Enter Output Main Board OUT105 NA LB03 Enter OUT106 NA END Enter Output Main Board OUT101 T3P1 BREAKER 1 TRIP OUT102 T3P1 EXTRA BREAKER 1 TRIP OUT...

Page 885: ...rogram to drive control outputs to trip circuit breakers See Section 5 Protection in the product specific instruction manual for complete information on tripping equations and settings For target illumination at tripping see Section 4 Front Panel Operations Close Output Signals Some SEL 400 series relays feature an automatic recloser for single circuit breaker and two circuit breaker applications ...

Page 886: ...on with the relay see Making an EIA 232 Serial Port Connection on page 3 4 In addition you must be familiar with relay access levels and passwords see Changing the Default Passwords in the Terminal on page 3 10 to change the default access level passwords You should also be familiar with QuickSet see Section 2 PC Software Step 1 Start QuickSet and establish a connection with the relay See Step 1 a...

Page 887: ...new settings in QuickSet Step 6 Upload the new settings to the relay a Click File Send QuickSet prompts you for the settings class or instance you want to send to the relay b Click the check box for Outputs as shown in the first dialog box shown in Figure 3 62 c Click OK QuickSet responds with the second dialog box of Figure 3 62 If you see no error message the new settings are loaded in the relay...

Page 888: ...ion on page 3 4 In addition you must be familiar with relay access levels and passwords see Changing the Default Passwords in the Terminal on page 3 10 to change the default access level passwords Step 1 Prepare to control the relay at Access Level 2 a Using a communications terminal type ACC Enter b Type the Access Level 1 password and press Enter You will see the prompt c Type 2AC Enter d Type t...

Page 889: ...ree pole tripping breaker Modify the procedure listed here for your application This example assumes that you have successfully established communication with the relay see Making an EIA 232 Serial Port Connection on page 3 4 In addition you must be familiar with relay access levels and passwords see Changing the Default Passwords in the Terminal on page 3 10 to change the default access level pas...

Page 890: ...uts Step 3 Access the Control Inputs settings a Click the arrow next to the Global branch of the Settings tree view b Click the arrow next to the Control Inputs branch of the Settings tree view see Figure 3 64 Step 4 Set EICIS Independent Control Input Settings to Y Figure 3 64 Accessing Control Inputs Settings in QuickSet ...

Page 891: ...Input IN101 Dropout Delay to 0 25 The relay checks the new value and enters the value in the QuickSet database Step 6 Configure the relay to read the circuit breaker auxiliary contact a Expand the Breaker Monitor branch of the Settings tree view by clicking the button see Figure 3 66 b In the tree view click Breaker 1 to select circuit breaker monitor settings for Circuit Breaker 1 c Set the 52AA1...

Page 892: ...UT401 OUT416 IN501 IN524 and OUT501 OUT516 are provided by remotely connected Axion modules See the installation section of the product specific instruction manual for details on how these are configured and mapped internally Within the relay the inputs behave just like local inputs They will be accurately time tagged in SER Similarly the outputs will behave like local outputs except that the comm...

Page 893: ...purpose of the procedure in the following steps is to show one method for deriving the TIME Q Time Source information from Relay Word bits TSOK and TIRIG when using an IRIG Time Source The TSOK Relay Word bit is at logical 1 when the relay is in HIRIG time mode For this application example use a pro tection SELOGIC variable PSV to monitor timekeeping status PSV02 asserts when the relay is synchron...

Page 894: ...l output to alarm a loss of HIRIG mode a In the Settings tree view click Outputs and then click Main Board see Figure 3 68 b In the OUT108 Main Board Outputs text box enter the OR NOT PSV02 condition to the preexisting OUT108 NOT SALARM OR HALARM equation as shown in Figure 3 68 Figure 3 67 Programming a PSV to Monitor HIRIG in QuickSet ...

Page 895: ...c Click OK QuickSet responds with a display similar to the second dialog box shown in Figure 3 62 If you see no error message the new settings are loaded in the relay To confirm that you have prepared an out of synchronization loss of HIRIG mode alarm disconnect the IRIG B input The relay alarm will activate Readying the Relay for Field Application Before applying the relay in your power system se...

Page 896: ... on page 3 10 Step 9 Change the default passwords see Changing the Default Passwords in the Terminal on page 3 10 Step 10 Set the DATE and TIME see Making Simple Settings Changes on page 3 15 Step 11 Use test sources to verify relay ac connections see Examining Metering Quantities on page 3 35 Step 12 Verify control input connections Step 13 Verify control output connections Step 14 Perform protec...

Page 897: ...ng relay operations This section describes features found in many but not necessarily all SEL 400 series relays See the relay specific instruction manuals to determine which front panel features are supported in that relay This section includes the following Front Panel Layout on page 4 1 Front Panel Menus and Screens on page 4 14 Front Panel Automatic Messages on page 4 31 Operation and Target LE...

Page 898: ...ayout Figure 4 1 SEL 451 Front Panel 8 Pushbutton Model Figure 4 2 SEL 451 Front Panel 12 Pushbutton Model with Optional Auxiliary Trip Close Buttons Liquid Crystal Display LCD and Navigation Pushbuttons Operation and Trip Target LEDs Direct Action Pushbuttons and Indicators EIA 232 Serial Port i4055c ...

Page 899: ...r the LEDs are programmable Select relay models feature auxiliary TRIP CLOSE pushbuttons These pushbuttons are electrically isolated from the rest of the relay The relay front panel features large operator control pushbuttons with annuncia tor LEDs that facilitate local control Factory default settings associate specific relay functions with these direct action pushbuttons and LEDs Using SELOGIC c...

Page 900: ...e Front Panel branch of the QuickSet Settings tree view The maxi mum backlight time is 60 minutes FP_TO 60 When the front panel times out the relay displays an automatic ROTATING DISPLAY described later in this section under Screen Scrolling on page 4 5 Navigating the Menus The relay front panel presents a menu system for accessing metering settings and control functions Use the LCD and the six pu...

Page 901: ...display to show the next set of full screen menu items with the first menu item highlighted Pressing the ESC pushbutton reverts the LCD display to the previous screen Pressing ESC repeatedly returns you to the MAIN MENU If a status warning alarm condition or event condition is active not acknowledged or reset the relay dis plays the full screen status warning alarm screen or trip event screen in p...

Page 902: ...lay points screen shows as many as 11 enabled display points with 96 display points the relay can pres ent a maximum of nine display points screens If a display point does not have text to display the screen space for that display point is maintained Figure 4 6 Sample ROTATING DISPLAY Circuit Breaker 1 Closed ROTATING DISPLAY Press for menu Line Current A RMS IA 119 6 IB 119 7 IC 119 5 FREQ 60 00 ...

Page 903: ...row or Right Arrow pushbuttons switches the display to the next screen pressing the Up Arrow or Left Arrow pushbuttons switches the display to the previous screen In manual scrolling mode the display shows arrows at the top and bottom of the vertical scroll bar The screen arrows indicate that you can navigate between the different screens at will The relay retrieves data prior to displaying each n...

Page 904: ...rder just as in the SER with the most recently asserted alarm displayed on the top Deasserted alarms may be removed from the display with user acknowledgment as shown in Example 4 1 Table 4 2 SER Point Settings Description Range Relay Word Bit Any valid relay element Reporting Name 20 character maximum ASCII string SET State Name logical 1 20 character maximum ASCII string CLR State Name logical 0...

Page 905: ... see Automatic Deletion and Rein sertion on page 9 31 Upon reinsertion the element state will be updated on the alarm point display If the relay enters a period of SER data loss the sta tus of alarm points cannot be determined The screen shown in Figure 4 11 will appear until you exit the data loss condition at which point the alarm point elements will be polled and displayed if asserted Subsequen...

Page 906: ...ll display points occupy one and only one line on the display at all times The height of the line is determined by the Text Size setting parameter Display points of single line height span one screen in total width Display points of double line height span two screens in total width You can use multiple dis play points to simulate multiple lines Use the following syntax to display the given Relay ...

Page 907: ...he decimal point and sign charac ter if applicable The scale value is optional if omitted the scale factor is processed as 1 If the numeric value is smaller than the field size requested the field is padded with spaces to the left of the number If the numeric value will not fit within the field width given characters are displayed The text size deter mines if the display will be in single font or ...

Page 908: ... 1234MWh PAD 7 2 1234 56 PAD A Ph Dem Pwr 4 1 A Ph Dem Pwr 1234 5 ICD C Demand 5 C Demand 1230 ICD C Demand 4 2 0 001 kA C Demand 1 23 kA MWHAOUT A Phase Out 3 1000 A Phase Out 1234 MWHAOUT A Phase Out 3 1000 kWH A Phase Out kWh 1 Fixed Text Fixed Text 0 Fixed Text Fixed Text 1 Empty Line 0 Empty Line Display Point is hidden Example 4 2 Creating a Display Point Display points screens can be used t...

Page 909: ...er visibility to the SF6 Alarm A horizontal scroll appears while in man ual scrolling mode regardless of whether or not the display point label width requires two full screens to display Example 4 3 Monitoring Test Modes With Display Points This example uses the Relay Word bit TESTFM Fast Meter test running to activate a front panel display point that alerts an onsite operator that the relay is in...

Page 910: ...S VIEW CONFIGURATION DISPLAY TEST RESET ACCESS LEVEL ONE LINE DIAGRAM Support Screens The relay displays special screens over the top of the menu or screen that you are using to control the relay or view data These screens are the ADJUST CONTRAST screen and the PASSWORD REQUIRED screen Contrast You can adjust the LCD screen contrast to suit your viewing angle and lighting conditions To change scre...

Page 911: ...the dark box cursor one space to the right You can backspace at any time by highlighting the BACKSPACE character and then pressing ENT When finished enter the password by highlighting the ACCEPT option and then pressing ENT If you entered a valid password for an access level greater than or equal to the required access level the relay authorizes front panel access to the combination of access leve...

Page 912: ...Event Report on page 9 14 for more information on event reports The front panel event buffer size is 100 summaries The relay numbers summary events in order from 10000 through 42767 and displays the most recent summa ries on the LCD You can view summary event reports from the relay front panel display by select ing EVENTS from the MAIN MENU The relay presents the Events Menu as shown in Figure 4 1...

Page 913: ...SER Point Alias Name Asserted or Deasserted state and the Date and Time of the event When in the SER Events screen three SER records are displayed on one screen Using the navigation pushbuttons the most recent 200 SER events are viewable on the front panel display The top event is the most recent event and the bottom event is the oldest The upper right of the screen displays the sequential indexes...

Page 914: ...taining the last SER event By default three SER events are shown per screen You can change this to five per screen by setting SER_PP to Y This will cause the element name and state information to be shown on the same line with the element name truncated to ten characters and the state truncated to eight characters Figure 4 20 SER Events Screen Figure 4 21 No SER Events Screen Table 4 6 Front Panel...

Page 915: ...or future use When you move item by item through the Relay Word bit table pressing the Up Arrow or Down Arrow pushbuttons shows each previous or next screen in turn Accelerated navigation occurs when you press and hold the Up Arrow or Down Arrow pushbuttons Holding the Up Arrow or Down Arrow pushbuttons repeats the regular pushbutton action at two rows every second for the first ten rows Con tinue...

Page 916: ...NT SEARCH screen If the relay finds a match the screen displays the element row containing the matching element Local Control The relay provides great flexibility in power system control through the LOCAL CONTROL menus You can use the front panel LOCAL CONTROL menus to perform these relay functions Trip and close circuit breakers password required Assert deassert and pulse relay control outputs to...

Page 917: ...ay displays the confirma tion message OPEN COMMAND ISSUED and trips Circuit Breaker 1 Relay Word bit OC1 pulses The BREAKER 1 STATUS changes to OPEN When you highlight the close option and press ENT the relay displays the confir mation message CLOSE COMMAND ISSUED and closes Circuit Breaker 1 Relay Word bit CC1 pulses The BREAKER 1 STATUS changes to CLOSED Be aware that not all SEL 451 relays supp...

Page 918: ...y Word bit drives the state of the graphical switch on the display i e with LB_DPnn deasserted the switch points to 0 Any unused local control bits default to the clear logical 0 state Also any reconfigured local bit retains the existing bit state after you change the bit setting Deleting a local bit sets that bit to the clear logical 0 state In the top part of Figure 4 26 the following custom lab...

Page 919: ...r Yes The default for the pulse state is N for No if you do not specify Y the local bit defaults at N and gives a continuous set or clear switch level If you enter an invalid setting the relay displays an error message prompting you to correct your input If you do not enter a valid local bit number the relay dis plays A local bit element must be entered If you enter a local bit number and that Fig...

Page 920: ...tion Range Default Local Bit Supervision n SELOGIC Equation NA 1 Local Bit Status Display n SELOGIC Equation NA LBn Figure 4 27 Local Bit Supervision Logic Example 4 4 Enabling Local Bit Control This application example demonstrates a method to create one of the control points in the LOCAL CONTROL screens of Figure 4 26 to control the interlock on a power bus tie circuit breaker Perform the follow...

Page 921: ...nd Aliases prompt to go to the line that lists Local Bit 9 See Text Edit Mode Line Editing on page 3 22 for information on text edit mode line editing To delete Local Bit 9 type DELETE Enter after the line that displays Local Bit 9 infor mation For example if a previously programmed Local Bit 9 appears in the SET F line numbered listings on Line 1 then typing DELETE Enter at Line 1 deletes Local B...

Page 922: ...N screen in Figure 4 29 shows the settings that you can set in the line configuration settings category To edit or examine a setting use the Up Arrow and Down Arrow pushbuttons to highlight that setting then press ENT The relay displays a settings entry screen with the existing setting value see the SET CTRW screen in Figure 4 29 If the prompt for the selected setting does not fit on the line the ...

Page 923: ...gs have specific options use the setting options screens to select these options Figure 4 30 shows examples of the settings input screens Figure 4 29 Example SET SHOW Screens SET SHOW PORT GLOBAL GROUP ACTIVE GROUP 3 DATE TIME GROUP SELECT AN INSTANCE SELECT A CLASS M 1 2 3 ACTIVE 4 5 6 GROUP 3 SELECT A CATEGORY Line Configuration Relay Configuration 37 Current Different Mho Phase Distance E Quad ...

Page 924: ... NEW GROUP number Step 4 Once you have selected the new active group press ENT to change the relay settings to this new settings group Date Time Another submenu item of the SET SHOW first screen Figure 4 29 is the DATE TIME screen shown in Figure 4 32 By default the relay generates date and time information internally you can also use external high accuracy time modes with time sources such as a G...

Page 925: ...y For a discussion of the timing modes in the relay see Section 11 Time and Date Management Relay Status The relay performs continuous hardware and software self checking If any vital system in the relay approaches a failure condition the relay issues a status warn ing If the relay detects a failure the relay displays the status failure RELAY STA TUS screen immediately on the LCD For both warning ...

Page 926: ...ses various passwords to control access to front panel functions As you progress through these menus the relay detects the existing password level and prompts you for valid passwords before allowing you access to levels greater than Access Level 1 see Password on page 4 15 When you want to return the front panel to the lowest access level Access Level 1 highlight RESET ACCESS LEVEL item on the MAI...

Page 927: ...trol Front Panel Operations on page 5 12 Front Panel Automatic Messages The relay automatically displays alert messages Any message generated because of an alert condition takes precedence over the normal ROTATING DISPLAY and the MAIN MENU Alert conditions include these significant events Alarm Point asserts Event reports and trips user defined Status warnings Status failures To display event repo...

Page 928: ...T If a trip event occurs while you are using a front panel screen the message area notification reads RELAY EVENT When you repeatedly press ESC as if returning to the MAIN MENU during this warning or trip alert situation the relay displays the corresponding full screen automatic message concerning the warn ing or trip in place of the MAIN MENU If the front panel display is at the MAIN MENU and a s...

Page 929: ...port as many as seven characters by aliasing the Tn_LED bits with the SET T command or with QuickSet In 12 pushbutton models the asserted and deasserted colors for the LED are deter mined with settings TnLEDC Options include red green amber or off In some SEL 400 series relays if TnLEDL Y the relay latches the target on the rising edge of the target bit In these relays to cause the bits to latch w...

Page 930: ...menu screens if the trip conditions have cleared Lamp Test Function With TARGET RESET The TARGET RESET pushbutton also provides a front panel lamp test Pressing TAR GET RESET illuminates all the front panel LEDs and these LEDs remain illumi nated for as long as you press TARGET RESET The target LEDs return to a normal operational state after you release the TARGET RESET pushbutton Other Target Res...

Page 931: ...trol Pushbuttons See Section 4 Front Panel Operations of the product specific instruction manual for a description of the default configuration of operator control pushbuttons and LEDs Figure 4 41 SEL 451 Default Operator Control Pushbuttons and LEDs 8 or 12 Pushbuttons Operator Control Pushbutton Annunciator LED ...

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Page 933: ...etermine the state of Circuit Breaker k and declare Circuit Breaker k alarm conditions See Section 5 Protection of the product specific instruction manual for a description of circuit breaker status logic Relay Word bits and circuit breaker status logic diagrams SEL 400 series relays support opening and closing breakers These operations can be controlled via the terminal commands OPEN and CLOSE th...

Page 934: ...ect Open Logic and Relay Word bit 89OPEm is an input to the Disconnect Close Logic Figure 5 1 Disconnect Switch Close Logic Close Immobility Timer 89CITm 0 CYC 89CIRm default setting NOT 89OPNm 89ALm 89CRSm default setting 89CLm OR 89CSIm Relay Word Bits SELOGIC control equation This SELOGIC control equation processed at 1 8 cycle 89CIMm 89CLSm Reset 0 CYC 60 CYC 5 2 3 Close Seal in Timer 89CSTm 0...

Page 935: ...t 89OPNm is asserted See Figure 5 3 for a description of these inputs With the default settings when Relay Word bit 89CLm asserts the close seal in circuit is blocked causing 89CLSm to deassert Likewise with the default settings when Relay Word bit 89OPNm asserts the open seal in circuit is blocked causing 89OPEm to deassert 89ALm The disconnect switch status and alarm logic in Figure 5 3 generate...

Page 936: ... switch operations Disconnect Switch Close and Open Control Logic Processing Figure 5 1 shows the Disconnect Switch Close Logic and Figure 5 2 shows the Disconnect Switch Open Logic Some motor operated disconnect switches have their own seal in circuits to seal the closing and opening signals in Other motor operated disconnect switches however require external sealed in circuits to maintain the cl...

Page 937: ... 89CSIm time an open and close signal could be sent to the disconnect switch at the same time The 89CLSm Relay Word bit input to the Disconnect Switch Open Logic guarantees that open and close commands are not transmitted to the disconnect switch simultaneously When the 89CLSm Relay Word bit deasserts an open command can be per formed The 89OBLm SELOGIC control equation provides an additional cust...

Page 938: ...ailed to move the switch sufficiently to open the normally open auxiliary contact 89AMm Disconnect Switch Status and Alarm Logic Settings 89ALPm This setting in the Bay settings class defines the disconnect switch alarm time Disconnect Switch Status and Alarm Logic Outputs 89ALm If a disconnect switch operation initiated from the front panel does not complete the 89ALPm timer expires and the 89ALm...

Page 939: ... timer longer than the expected undetermined disconnect state time but less than the 89CSTm or 89OSTm seal in timers If the 89ALPm timer expires the 89ALm Relay Word bit asserts Relay Word bit 89ALm asserts when the disconnect operation does not complete successfully When the 89ALPm timer begins timing the operation in progress Relay Word bit 89OIPm and Relay Word bit 89CLBm assert The 89CLBm Rela...

Page 940: ...n Immobility Timer Logic Inputs LOCAL The LOCAL Relay Word bit supervises local disconnect control and is based on the LOCAL SELOGIC control equation in the Bay settings class Disconnect switch operations from the front panel are possible when the LOCAL Relay Word bit is asserted in other words the LOCAL Relay Word bit prevents control from the HMI without proper supervision 89CBLm 89OBLm The 89CB...

Page 941: ...ations this disconnect operate method is not supervised by the breaker jumper or appropriate relay access levels as is the case with other disconnect operation methods 89CCMm 89OCMm 89CCMm and 89OCMm Relay Word bits pulse for one quarter cycle when close or open disconnect operations are executed from the one line diagram on the front panel screen The LOCAL Relay Word bit must be asserted for Rela...

Page 942: ...he close and open immobility timers work in conjunction with the disconnect alarm timer to provide disconnect control and alarm indications When the disconnect switch main contact is stationary closed or open the state of the disconnect switch is easily determined If the disconnect switch main contact is open normally closed Form B auxiliary contact 89BMm asserted is closed normally open Form A au...

Page 943: ...ime the 89ALPm timer expires and an alarm condition is declared The Close Immobility Logic starts the Close Immobility Timer for an operation where the disconnect switch does not move the minimum distance to open the normally closed auxiliary contact open to close operation When the close immobility timer expires an alarm condition is declared and Relay Word bit 89ALm asserts If the disconnect mov...

Page 944: ... momentary assertion through the automation processing interval This conditioning ensures the reliable detection of remote bit RB01 RB32 assertion in automation logic Remote bits that assert and deassert multi ple times within the same automation logic processing interval will be processed as asserting continuously for the entire automation logic processing interval Bay Control Front Panel Operati...

Page 945: ...d the relay prompts you to enter the appropriate passwords The Breaker Jumper is not installed the Breaker Control Disabled Please Install the Breaker Jumper message briefly appears on the screen Use the arrow pushbuttons on the front panel to navigate within the one line dia gram When you first select the one line diagram none of the apparatus on the one line diagram are highlighted Press the Lef...

Page 946: ...rrow pushbutton while displaying the bottom bay control screen displays the top bay control screen Circuit Breaker and Disconnect Definitions and State Representations Table 5 1 shows the apparatus definitions and symbols displayed on the one line diagram NOTE The intermediate states only apply to disconnect switches because circuit breaker operations have a short duration Each apparatus circuit b...

Page 947: ...ine diagram when a disconnect operation is in progress Table 5 2 Circuit Breaker State Representations Apparatus Position Symbol Asserted Relay Word Bit Circuit breaker open not highlighted NOT 52CLSMm Circuit breaker open highlighteda a When the circuit breaker is highlighted the two symbols shown alternate in the display NOT 52CLSMm Circuit breaker closed not highlighted 52CLSMm Circuit breaker ...

Page 948: ... Figure 5 9 c for three seconds and then returns to the screen in Figure 5 9 a Disconnect Operation In Progress not highlightedb 89OIPm Disconnect Operation In Progress highlightedc 89OIPm a When the disconnect switch is highlighted and no operation is in progress a square box alternately frames the switch symbol b For a disconnect switch operation in progress where the disconnect switch is not hi...

Page 949: ...iscrepancy screen shown in Figure 5 10 c so that the operator can immediately identify the offending pole You can operate the breaker from the pole discrepancy screen after the discrepancy has been rectified All other screens are the same as when you set the relay to three pole operations Figure 5 9 Screens for Circuit Breaker Selection BAYNAME BAYNAME TRIP BREAKER CLOSE BREAKER STATUS BmCTLNM PRE...

Page 950: ...vi gate between the disconnect control functions in Figure 5 11 b If the LOCAL Relay Word bit is not asserted when the ENT pushbutton is pressed the relay dis plays screen in Figure 5 11 c for three seconds and then returns to the screen in Figure 5 11 a Figure 5 10 Screens During a Pole Discrepancy Condition a Bay Screen POLE DISCREPANCY 1 5 seconds delay BAYNAME TRIP BREAKER CLOSE BREAKER STATUS...

Page 951: ... that the discon nect switch is in is highlighted in other words if Relay Word bit 89OPN1 is asserted the OPEN DISCONNECT text has a box drawn around it To close the disconnect switch use the Up Arrow or Down Arrow pushbutton to highlight the CLOSE DISCONNECT text Figure 5 11 Screens for Disconnect Switch Selection BAYNAME BAYNAME OPEN DISCONNECT CLOSE DISCONNECT STATUS DmCTLNM PRESS TO ACTIVATE B...

Page 952: ...he case of a successful close operation the relay displays the screen in Figure 5 14 b Failing to close also has two possible scenarios the disconnect starts to move but does not complete the operation or the disconnect switch operation does not initiate When Relay Word bit 89OPN1 deasserts the Close Immobility timer resets indi cating that the disconnect switch has started to move If Relay Word b...

Page 953: ...een b is displayed Down button pressed BAYNAME OPEN DISCONNECT CLOSE DISCONNECT NOT ALLOWED OPEN DmCTLNM NO LOCAL CONTROL BAYNAME OPEN DISCONNECT CLOSE DISCONNECT OPEN DmCTLNM PRESS TO ACTIVATE b Disconnect Control Screen BAYNAME OPEN DISCONNECT CLOSE DISCONNECT OPEN DmCTLNM PRESS TO ACTIVATE a Disconnect Control Screen 89OPN1 asserted 89OPN1 asserted If 89CCM1 asserts screen c is displayed 89OIP1...

Page 954: ...lay Word bits 89OIPm and 89ALm are asserted Relay Word bit 89ALm takes priority If Relay Word bit 89OPNm is asserted the relay displays the screen in Figure 5 12 a This is the initial screen for an open to close operation If Relay Word bit 89CLm is asserted the relay displays the screen in Figure 5 14 b This is the initial screen for a close to open operation Figure 5 13 HMI Disconnect Operation i...

Page 955: ...ree position disconnect has two labels one for the in line branch and one for the ground perpendicular branch In the example shown in Figure 5 15 the three position disconnect is made up of Disconnect SW3 and Disconnect SW4 As with the standard disconnect be sure to correlate the disconnect wiring and set tings with the disconnects assigned to the three position disconnect image on the one line di...

Page 956: ...isconnect 3 in line closed Disconnect 4 ground opened 89CL3 and 89OPN4 Disconnect 3 in line opened Disconnect 4 ground closed 89OPN3 and 89CL4 Disconnect 3 in line intermediatea Disconnect 4 ground opened b 89OIP3 or 89AL3 and 89OPN4 Disconnect 3 in line opened Disconnect 4 ground intermediatea b 89OPN3 and 89OIP4 or 89AL4 All other status combinations Disconnect 3 closed Disconnect 4 closed Disco...

Page 957: ... line disconnect open and the ground disconnect closed The three position disconnect logic is identical to two standard disconnects but control actions are limited as shown in Table 5 5 A control action is only avail able if the disconnect name is listed next to the action as indicated in the Control Options Displayed column For example in the second set of control actions where Disconnect SW3 is ...

Page 958: ...closed the control screen will change as show in Figure 5 16 c Table 5 5 Three Position Disconnect Switch Control Screen Status and Control Options State of Disconnects Status Displayed Control Options Displayed Control Actions Available Disconnect SW3 Open Disconnect SW4 Open OPENED OPENED SW3 SW4 CLOSE SW3 OPENa CLOSE SW4 CLOSE SW3 NO OPEN CONTROL CLOSE SW4 Disconnect SW3 Closed Disconnect SW4 O...

Page 959: ...ith three position disconnects contact SEL QuickSet Bay Control Screens QuickSet provides an easy and intuitive way to configure and set the bay control function Select the Bay Control button from the tree to see the first interactive bay forms in QuickSet as shown in Figure 5 18 Figure 5 17 Bay Control One Line Diagram With Three Position Disconnect Closed In Line BAYNAME ESC NAVIG I 9999A V 9999...

Page 960: ...the bay control screens Local The LOCAL SELOGIC control equation enables local and remote control of the disconnect switch This example illustrates how the input contact IN107 can accommodate existing bay controls that use a key to manually change from remote to local control The key switch is made to actuate a contact when the key is turned as shown in Figure 5 19 With the contact of the switch w...

Page 961: ...ame Enter the name of the busbar e g 132 Bus No 1 and click OK Disconnect Assignments To configure disconnects click the box next to the disconnect switch A dialog box appears as shown in Figure 5 21 Figure 5 19 Local and Remote Control Logic With Key Control Rated DC Input Voltage Contact closed Local control Contact open Remote control IN107 Figure 5 20 Setting Busbar Names in QuickSet ...

Page 962: ...approximately four characters D01CTLN Enter a Disconnect 1 label on the control screen Enter a descriptive name there are 15 characters available that clearly identifies the disconnect 89AM01 89BM01 These SELOGIC control equations report the state of Disconnect 1 auxiliary con tacts Both equations must be programmed for the Disconnect Switch Status and Alarm Logic to function correctly Figure 5 21...

Page 963: ... Cold weather and low battery voltages can impact disconnect switch operation times Be sure to consider these conditions when setting the seal in timers 89CIT01 89OIT01 The close open Disconnect 1 immobility timers are triggered at the same time as the seal in timers Expiration of these immobility timers indicates that the Dis connect 1 auxiliary contact status failed to change state within the ex...

Page 964: ...r a descriptive breaker name as many as 15 characters 52mCLSM 52m_ALM These SELOGIC control equations report breaker close status and breaker alarm status Any bit in the Relay Word as well as logical operators can be pro grammed into these SELOGIC control equations Analog Display If analog display points are not required leave the setting s blank because the relay displays only the defined display...

Page 965: ...e of the analog quantity For example a scaling value of 0 5 displays only half the value of FREQ while a scaling value of 2 displays twice the value of FREQ Enter text such as the units of the analog quantity in the Post Text field Test the entries by typing a value of 60 51 in the preview analog display field Click the Preview button and verify that all entries are correct and will fit on the scr...

Page 966: ...Transformer Image Number Figure 5 27 Different Types of Circuit Breakers and Disconnects Circuit breaker ANSI type Closed vertical Circuit breaker ANSI type Open vertical Circuit breaker ANSI type Closed horizontal Circuit breaker ANSI type Open horizontal Circuit breaker IEC type Closed vertical Circuit breaker IEC type Open vertical Circuit breaker IEC type Closed horizontal Circuit breaker IEC ...

Page 967: ...done with other SEL 400 series relays Bus 1 Bus 2 and Transfer BUS Bay With Ground Switch MIMIC 4 Figure 5 29 illustrates the Bus 1 Bus 2 and Transfer Bus Bay with Ground Switch MIMIC 4 The Bay configuration used in this example provides five disconnect switches one breaker and the ability to display as many as six Analog Quantities The labels and Analog Quantities shown in Figure 5 29 are all a r...

Page 968: ...ters depending on the pixel width of the string BAYLAB1 or BAYLAB2 are not required because the MIMIC setting selected in this example does not include bay labels If MIMIC 14 17 18 or 23 had been selected the relay would have prompted for BAYLAB1 and BAYLAB2 settings Busbar Information Bus Name Labels Based on the MIMIC setting the relay provides as many as nine bus name labels in the one line dia...

Page 969: ...e status and breaker alarm status Any bit in the Relay Word can be programmed into this SELOGIC control equation as well as logical operators The equations below return the state of the Bkr 1 status and any Bkr 1 alarm conditions 521CLSM 52ACL1 521_ALM 52AAL1 Disconnect Information The relay provides disconnect switch information for as many as ten disconnect switches For the bay configuration sel...

Page 970: ...CCN01 asserts Relay Word bit 89OPN1 deasserts as soon as the disconnect switch starts to move The OR combination of Relay Word bit 89CLS1 and 89OPN1 keeps the close disconnect signal asserted until the dis connect operation has completed The SELOGIC control equations below demon strate disconnect lockout control in the relay The 89OCN01 SELOGIC control equation illustrates the same type of supervi...

Page 971: ...control equation enables local and remote control of the disconnect switch This example illustrates how the SEL 451 input contact IN107 can accommodate existing bay controls that use a key to manually change from remote to local control The key switch is made to actuate a contact when the key is turned as shown in Figure 5 30 With the contact of the switch wired to the SEL 451 input the key switch...

Page 972: ... closing circuit and OUT104 to the disconnect switch opening circuit OUT103 89CLS1 AND NOT 52CLSM1 OUT104 89OPEN1 AND NOT 52CLSM1 The outputs in the relay are not designed to break the coil current in the disconnect motor An auxiliary contact with adequate current interrupting capacity must clear the coil current in the disconnect motor before the output opens Failure to observe this safeguard cou...

Page 973: ...isconnect 1 Alarm Pickup Delay 1 99999 cyc 260 89CCN1 Disconnect 1 Close Control SELOGIC Equation 89CC01 89OCN1 Disconnect 1 Open Control SELOGIC Equation 89OC01 89CST1 Disconnect 1 Close Seal in Time 1 99999 cyc 280 89OST1 Disconnect 1 Open Seal in Time 1 99999 cyc 280 D2HMIN Disconnect 2 HMI Name max 3 17 characters D2 D2CTLN Disconnect 2 Name 25 pixels 4 6 characters Dis 2 89AM2 Disconnect 2 N ...

Page 974: ...5 Disconnect 5 Open Control SELOGIC Equation 89OC05 89CST5 Disconnect 5 Close Seal in Time 1 99999 cyc 280 89OST5 Disconnect 5 Open Seal in Time 1 99999 cyc 280 One Line Analog Display 1 1 Analogs 2 IAWM IA 4 0 1 A 3 VABFM V 3 0 1 kV 4 FREQ F 4 1 1 Hz 5 3P P 3 0 1 MW 6 3Q_F Q 3 0 1 MVR Control Selection LOCAL Local Control SELOGIC control equation IN107 Table 5 7 Application Example Front Panel Se...

Page 975: ...3 OUT103 SELOGIC control equation 89CLS1 AND NOT 52CLSM1 OUT104 OUT104 SELOGIC control equation 89OPEN1 AND NOT 52CLSM1 OUT105 OUT105 SELOGIC control equation 89CLS2 AND NOT 52CLSM1 OUT106 OUT106 SELOGIC control equation 89OPEN2 AND NOT 52CLSM1 OUT201 OUT201 SELOGIC control equation 89CLS3 AND 89OPN5 OUT202 OUT202 SELOGIC control equation 89OPEN3 AND 52CLSM1 OUT203 OUT203 SELOGIC control equation ...

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Page 977: ...s four three pole reclose shots You can designate the leader and follower circuit breakers in a two circuit breaker configuration The relay recloser can dynamically change leader and fol lower designations based on settings and operating conditions You can program the autoreclose logic to perform one shot of high speed three pole reclose This high speed three pole shot replaces one of the four del...

Page 978: ...d then the recloser logic proceeds through the 3PMRCD Manual Close Reclaim Time Delay time and then goes to the ready state Reset BK1RS BK2RS The autoreclose logic is in the reset or ready state for either circuit breaker when the circuit breaker is ready to begin an autoreclose cycle There are three reset state timers After a successful reclose cycle the relay goes to the reset state after reclai...

Page 979: ...lower decision during an autoreclose cycle unless the autoreclose logic receives another initiation If the recloser receives another initiation the logic reevaluates the leader and fol lower circuit breakers to determine the number of circuit breakers in a scheme NBKn the leader circuit breaker LEADBKn and the follower circuit breaker FOLBKn This determination is based on the service status of the...

Page 980: ...begin a single pole autoreclose cycle are satis fied ESPR1 for example and the recloser receives a single pole reclose initia tion SPRI see Figure 6 8 Relay Word bit 3PARC asserts when all necessary conditions to begin a three pole autoreclose cycle are satisfied E3PR1 for exam ple and the recloser receives a three pole reclose initiation 3PRI see Figure 6 9 Figure 6 1 Autoreclose State Diagram fo...

Page 981: ...lose the recloser goes to lockout BK1LO after timer BKCFD expires SPRCD Reclaim Timing If the circuit breaker closes the recloser starts timer SPRCD Single Pole Reclaim Time Delay The recloser determines subsequent state transitions during reclaim timing according to the status of Relay Word bit SPLSHT Single Pole Reclose Last Shot When SPLSHT is asserted the recloser forces all subse quent relay ...

Page 982: ...KP at this point to determine whether to increment the shot counter The recloser waits indefinitely for the circuit breaker to open as indicated by Relay Word bit 3POLINE The recloser begins timing 3POID1 Three Pole Open Interval 1 Delay when the circuit breaker opens After the open interval time 3POID1 expires the relay asserts Relay Word bit BK1CL to reclose the circuit breaker if supervisory co...

Page 983: ...t breaker fails to close within BK1CFD time Relay Word bit 79DTL asserts Single and Three Pole Mode NOTE Single and three pole mode is only supported in breakers that provide single pole breaker control The single and three pole mode SPAR 3PAR uses elements of both the single pole mode SPAR and the three pole mode 3PAR Reclosing begins after a sin gle pole trip in the single pole cycle 79CY1 with ...

Page 984: ...1 are used to set the relay auto reclose modes Table 6 4 illustrates how to enable the autoreclose modes for Cir cuit Breaker 1 Table 6 2 One Circuit Breaker Three Pole Reclosing Initial Settings Setting Description Entry General Global Settings Global NUMBK Number of Breakers in Scheme 1 Breaker Configuration Breaker Monitor BK1TYPa a Only applies to relays that support single pole breaker operat...

Page 985: ...th single pole and three pole reclosing set ESPR1 to evaluate to logical 1 set E3PR1 to evaluate to logical 1 and configure settings NSPSHOT and N3PSHOT for the desired number of reclose shots of each type see Recloser Mode Enables on page 6 8 Trip Logic and Reclose Sources for Single Pole Breaker Applications Internal Recloser Program the recloser function to drive the trip logic with Relay Word ...

Page 986: ...ied ESPRn for example and the recloser receives a single pole reclose initia tion SPRI see Figure 6 9 Relay Word bit 3PARC asserts when all necessary conditions to begin a three pole autoreclose cycle are satisfied E3PRn for exam ple and the recloser receives a three pole reclose initiation 3PRI see Figure 6 10 Single pole recloser settings also include the initial recloser settings see Enable Aut...

Page 987: ...e scheme If NBK2 is asserted the recloser checks for a single pole open on the follower and starts timer TBBKD Time Between Breakers For ARC If multiple poles of the follower circuit breaker are open the recloser sends the follower to lockout BKnLO When TBBKD expires the recloser closes the follower breaker if FBKCEN Follower Breaker Closing Enable is asserted and supervisory condition SPnCLS is s...

Page 988: ...aximum number of shots NSPSHOT supervision condition SPnCLS fails to assert in BKnCLSD time Relay Word bit 3POLINE asserts for a circuit breaker manual opening the circuit breaker fails to close within BKCFD time or any time Relay Word bit 79DTL asserts Three Pole Mode Figure 6 15 and Figure 6 16 show the two circuit breaker three pole autoreclose cycle 79CY3 when E79 Y and E79 Y1 respectively The...

Page 989: ...lower circuit breaker if NBK2 is asserted To close the follower circuit breaker the recloser checks for two active circuit breakers in the scheme If NBK2 is asserted the recloser checks for a three pole open on the follower and starts timer TBBKD Time Between Breakers For ARC When TBBKD expires the recloser closes the follower breaker if FBK CEN Follower Breaker Closing Enable is asserted and supe...

Page 990: ...page 6 10 The recloser closes the circuit breakers and pro ceeds to the reclaim timer SPRCD If a fault occurs during the SPRCD reclaim time and SPLSHT is asserted then the recloser asserts Relay Word bit 3PARC if all three pole reclose conditions are satisfied Upon asserting 3PARC the recloser exits the 79CY1 cycle state and goes to the beginning of the three pole autoreclose cycle state 79CY3 The...

Page 991: ... BK1 as the leader set SLBK2 1 to select Circuit Breaker BK2 as the leader SLBK1 has priority over SLBK2 if you set both settings to 1 or both to 0 Circuit Breaker BK1 is the leader Circuit Breaker BK1 is the leader for the following conditions BK1 is the only circuit breaker in service BK1 and BK2 are in service and BK1 is selected as the leader SLBK1 1 BK1 and BK2 are in service and the setting ...

Page 992: ...ate At the start of the reclose cycle the relay freezes this calculation and sets circuit breaker des ignations The leader follower designation can dynamically change in the cycle if the leader circuit breaker goes to lockout and FBKCEN is asserted Set the initial leader follower designation and follower close conditions with set tings SLBK1 Lead Breaker Breaker 1 SLBK2 Lead Breaker Breaker 2 and ...

Page 993: ...r on page 6 17 for another method to prevent BK2 from becoming the leader The following examples help illustrate how the relay autoreclose logic dynami cally determines the leader and follower circuit breakers These examples describe a two circuit breaker scheme such as used in a circuit breaker and a half arrangement as shown in Figure 6 3 Example One No Follower This example describes recloser s...

Page 994: ...with BK2 Table 6 9 defines the logical state of the autoreclose logic at this point Table 6 6 Leader Follower Selection Setting Label Value SLBK1 1 SLBK2 0 FBKCEN 0 Table 6 7 Example One Reset and 79CY3 States Relay Word Bit Description Logical State NBK0 No Active Breakers in Reclose Scheme 0 NBK1 One Breaker Active in Reclose Scheme 0 NBK2 Two Active Breakers in Reclose Scheme 1 LEADBK0 No Leade...

Page 995: ...t State After Reclaim Time Relay Word Bit Description Logical State NBK0 No Active Breakers in Reclose Scheme 0 NBK1 One Breaker Active in Reclose Scheme 1 NBK2 Two Active Breakers in Reclose Scheme 0 LEADBK0 No Leader Breaker 0 LEADBK1 Leader Breaker Breaker 1 0 LEADBK2 Leader Breaker Breaker 2 1 FOLBK0 No Follower Breaker 1 FOLBK1 Follower Breaker Breaker 1 0 FOLBK2 Follower Breaker Breaker 2 0 ...

Page 996: ... as in Table 6 13 Reset State Prior to receiving initiation for a three phase fault the autoreclose logic resets for both circuit breakers Table 6 14 defines the logical state of the autoreclose logic for this example prior to the initiation of an autoreclose cycle Table 6 12 Example Two Final Reset State Relay Word Bit Description Logical State NBK0 No Active Breakers in Reclose Scheme 0 NBK1 One...

Page 997: ...LBK1 Follower Breaker Breaker 1 0 FOLBK2 Follower Breaker Breaker 2 1 Table 6 14 Example Three Reset State Sheet 2 of 2 Relay Word Bit Description Logical State Table 6 15 Example Three Three Pole Cycle State Relay Word Bit Description Logical State NBK0 No Active Breakers in Reclose Scheme 0 NBK1 One Breaker Active in Reclose Scheme 0 NBK2 Two Active Breakers in Reclose Scheme 1 LEADBK0 No Leader...

Page 998: ...close Logic for Two Circuit Breakers Three Pole Trip Circuit Breakers The initial settings necessary to enable autoreclose for two three pole trip circuit breakers are shown in Table 6 19 Table 6 17 Leader Follower Selection Setting Label Setting SLBK1 IN106 Disconnect 1 a contacts SLBK2 IN107 Disconnect 2 a contacts FBKCEN 0 Figure 6 4 Leader Follower Selection by Relay Input Table 6 18 Two Circu...

Page 999: ...N O Contact Input BK1 SELOGIC Equation IN101 Breaker 2 Inputs Breaker Monitor 52AA2 N O Contact Input BK2 SELOGIC Equation IN102 Relay Configuration Group E79 Reclosing Y or Y1 Table 6 20 Two Circuit Breaker Single Pole Reclose Initial Settings Setting Description Entry NUMBK Number of Breakers in Scheme 2 Breaker Configuration Breaker Monitor BK1TYP Breaker 1 Trip Type 1 BK2TYP Breaker 2 Trip Typ...

Page 1000: ... the relay can attempt a single pole autoreclose cycle for Circuit Breaker BK2 If ESPR2 equals logical 0 the relay cannot initi ate a single pole autoreclose cycle for Circuit Breaker BK2 When E3PR2 equals logical 1 the relay can attempt a three pole autoreclose cycle for Circuit Breaker BK2 If E3PR2 equals logical 0 the relay goes to lock out following a three pole trip for Circuit Breaker BK2 As...

Page 1001: ...quals logical 1 the relay can only three pole trip Circuit Breaker BK1 The same conditions apply to setting E3PT2 and Circuit Breaker BK2 Table 6 23 summarizes the relay trip logic enable options Relay Word bits R3PTE1 and R3PTE2 both equal logical 1 for any of the follow ing conditions when Global setting NUMBK Number of Breakers in Scheme is 2 and SPLSHT Single Pole Last Shot is asserted see Fig...

Page 1002: ...l to IN106 Other external recloser signals are required consult the external recloser documentation for interconnection with the relay In installations where the external reclosing relay does not provide three phase trip control signals the TOP Trip during Open Pole Relay Word bit can be used in the E3PT setting This Relay Word bit will assert just after a single or two pole trip and remain assert...

Page 1003: ...Logic Diagram When E79 Y Figure 6 8 Line Open Logic Diagram When E79 Y1 52AA1 3POBK1 Timer in cycles 0 0 1 0 52AA2 3POBK2 Timer in cycles 0 0 1 0 Setting Relay Word Bit Breaker 1 Setting Relay Word Bit Breaker 2 NBK2 NBK1 3POBK1 3POBK2 3POLINE LEADBK1 3POBK1 LEADBK2 3POBK2 Relay Word Bits Relay Word Bits NBK2 3POBK1 3POBK2 NBK1 3POLINE LEADBK1 3POBK1 LEADBK2 3POBK2 Relay Word Bits Relay Word Bits ...

Page 1004: ...nable SPLSHT 79STRT BK1EXT BK2EXT ESPR1 79CY3 BK1LO BK2LO SPARC SPRI S R Q R3PTE1 R3PTE2 R3PTE ESPR2 NSPSHOT N NUMBK 2 NUMBK 2 NUMBK 1 3PARC SPARC Drop Out SPOIT Time out 79DTL 3POLINE R has precedence over S BK1TYP 3 BK1TYP 3 BK2TYP 3 0 2 CYC Figure 6 10 Three Pole Reclose Enable 3PLSHT BK1LO BK2LO E3PR1 E3PR2 NUMBK 2 3PARC 3PRI 0 4 CYC ...

Page 1005: ...to Close SP1CLS SPO Single Pole Open Time Out No Timed Out Single Pole Reclaim Time SPRCD Breaker Close Failure Time BKCFD Ready State BK1RS to Beginning of 79CY3 to Beginning of 79CY1 Lockout BK1LO 3PARC SPARC Timed Out Timing No Lockout BK1LO Lockout BK1LO Timed Out Timing Issue CLOSE Command BK1CL Did Breaker Close BK1CL 12 3 6 9 12 3 6 9 12 3 6 9 12 3 6 9 12 3 6 9 Recalculate NBKn Leader and F...

Page 1006: ...d Did Breaker Close Yes Timed Out Timed Out Timed Out Breaker Open Close Supervision Delay Three Pole Open Interval Timer 3POIDn No Timing BK1CL No Timing Yes 3PARC Timing Breaker Close Failure Timer BKCFD Three Pole Reclaim Timer 3PRCD BK1CLSD No Yes Increment Shot Counter and Issue CLOSE Command 3PARC Lockout BK1LO Timed Out 79CY3 79CY3 Yes No No 3POLINE Is Skip Shot Asserted Has the Line Opened...

Page 1007: ...ngle Pole Open Does Follower Have Single Pole Open Issue Leader CLOSE Command Did Leader Close Determine Active Breakers in Scheme Determine Active Breakers in Scheme Is Leader Allowed to Close SPnCLS To Reclaim Stage Timed Out No No No No NBK1 Yes 3PARC Yes No Timing NBK2 Timing Breaker Close Failure Timer BKCFD Time Between Breakers TBBKD Timed Out Yes Yes Yes Yes LBKCL NBK1 Send Leader to Locko...

Page 1008: ...losed No Timing Timed Out Timed Out Follower Breaker Close Failure Timer BKCFD Send Follower to Lockout State Send Follower to Lockout Leader to Reclaim Stage Lockout BKnLO 12 3 6 9 No Timing 12 3 6 9 12 3 6 9 79CY3 Is 79BRCT Asserted Recalculate NBKn Leader and Follower Determine Active Breakers Determine Leader SPARC Timing SPARC To Beginning of 79CY1 Send Both Breakers to Ready State Breaker 1 ...

Page 1009: ...ngle Pole Open Does Follower Have Single Pole Open Issue Leader CLOSE Command Did Leader Close Determine Active Breakers in Scheme Determine Active Breakers in Scheme Is Leader Allowed to Close SPnCLS To Reclaim Stage Timed Out No No No No NBK1 Yes 3PARC Yes No Timing NBK2 Timing Breaker Close Failure Timer BKCFD Time Between Breakers TBBKD Timed Out Yes Yes Yes Yes LBKCL NBK1 Send Leader to Locko...

Page 1010: ...Closed No Timing Timed Out Timed Out Follower Breaker Close Failure Timer BKCFD Send Follower to Lockout State Send Follower to Lockout Leader to Reclaim Stage Lockout BKnLO 12 3 6 9 No Timing 12 3 6 9 12 3 6 9 79CY3 Is 79BRCT Asserted Recalculate NBKn Leader and Follower Determine Active Breakers Determine Leader SPARC Timing SPARC To Beginning of 79CY1 Send Both Breakers to Ready State Breaker 1...

Page 1011: ...ssue Leader CLOSE Command Yes No Yes Timing 12 3 6 9 No Timing Timed Out or 3 Pole Reclosing Disabled for Lead Breaker E3PRn 0 Timed Out LBKCL C A Determine Active Breakers in Scheme NBK2 NBK1 Lockout BKnLO A Freeze 3PARC 3 Pole Reclose Initiation 3PARC from Ready States BK1RS and or BK2RS or from Single Pole Reclose Cycle State 79CY1 3 Pole Reclose Initiation 3PARC while in 3 Pole Reclose Cycle S...

Page 1012: ...s Follower Closing Enabled FBKCEN 1 Is the Leader in the Lockout State Have Follower Close Supervision Conditions Been Met 3PnCLS Is the Follower Closed Determine Active Breakers in Scheme Issue Follower CLOSE Command LEADBKR L O FOLBKR L O Determine Leader and Send Leader to Lockout State To Reclaim Stage Is the Leader in the Lockout State Yes Yes Yes Yes Yes FBKCL Yes No No No No No D Timing Tim...

Page 1013: ...inued D 12 3 6 9 Is 79BRCT Asserted Recalculate NBKn Leader and Follower Determine Active Breakers Determine Leader Timing 3PARC 3PARC To beginning of 79CY3 Send Breakers not already in the Lockout State e g BKnL0 to the Reset State BKnRS Breaker 1 Ready State BK1RS Breaker 2 Ready State BK2RS No Yes NBK1 LEADBK1 LEADBK2 NBK2 Timed Out Reclaim Timer 3PRCD Breaker Open Lockout BKnLO ...

Page 1014: ...eaker E3PRn 0 Timed Out LBKCL C A Determine Active Breakers in Scheme NBK2 NBK1 Lockout BKnLO A Freeze 3PARC 3 Pole Reclose Initiation 3PARC from Ready States BK1RS and or BK2RS or from Single Pole Reclose Cycle State 79CY1 3 Pole Reclose Initiation 3PARC while in 3 Pole Reclose Cycle State 79CY3 If 3 Pole Reclosing is disabled for Breaker n E3PRn 0 send Breaker n to lockout BKnLO Recalculate Lead...

Page 1015: ...s Follower Closing Enabled FBKCEN 1 Is the Leader in the Lockout State Have Follower Close Supervision Conditions Been Met 3PnCLS Is the Follower Closed Determine Active Breakers in Scheme Issue Follower CLOSE Command LEADBKR L O FOLBKR L O Determine Leader and Send Leader to Lockout State To Reclaim Stage Is the Leader in the Lockout State Yes Yes Yes Yes Yes FBKCL Yes No No No No No D Timing Tim...

Page 1016: ...7 is the substi tution of settings and logic outputs BK2MCL for BK1MCL ULCL2 for ULCL1 etc A manual close is issued for breaker BK1 if all of the following are true A new manual close signal for breaker BK1 is detected rising edge assertion of SELOGIC setting BK1MCL No unlatch close conditions are present SELOGIC setting ULCL1 deasserted No close is presently in progress for breaker BK1 Relay Word...

Page 1017: ... Relay Word bit BK1CFT asserts momentarily Close logic output BK1CL deasserts Note in Figure 6 17 that if breaker BK1 manual close logic is actively operating as described in the preceding steps then breaker BK2 manual close logic can not be actively operating Breaker BK2 manual close logic only has a chance to operate if breaker BK1 manual close logic is not actively operating and two breakers ar...

Page 1018: ...Unlatch Close Output ULCL1 1 Deassert Close Output BK1CL 0 END Number of Breakers in Scheme NUMBK Decrement Breaker Close Failure Timer Assert Breaker Close Failure output BK1CFT 1 Breaker BK1 Y Y N Y Y N N N 1 Breaker BK2 From Breaker BK2 logic Breaker 2 Manual Close Logic Similar to Breaker 1 Breaker Close Failure Timer Timed Out New Manual Close signal and No Unlatch Close Condition and No Clos...

Page 1019: ...vailable from the line PTs But resultant voltage VP corresponds to only one phase of this three phase voltage e g setting SYNCP VAY VP is the normalized voltage from voltage input VAY All the voltage elements in Figure 6 19 are single phase voltage elements detecting live or dead voltage on the bus side with a single phase voltage ele ment and likewise on the line side Whether or not synchronism c...

Page 1020: ...sm check condition follower breaker Supervising Manual Closing Voltage checks can also be used to supervise manual closing For example pre sume that manual closing of breaker BK1 Figure 6 18 should not be allowed if the respective bus is dead dead line dead bus or live line dead bus condition BK1MCL NOT DLDB1 OR AND LLDB1 AND Figure 6 18 Voltage Check Element Applications Bus 2 VS1 Bus 1 Potential...

Page 1021: ...ment Logic 27BK2P 27BK1P VS1 59BK1P VS2 59BK2P LLDB2 DLDB2 DLLB1 LLDB1 DLLB2 DLDB1 27LP VP 59LP Settings Voltages Relay Word Bits Table 6 24 Autoreclose Logic Relay Word Bits Sheet 1 of 3 Name Description BK1RS Breaker 1 in Reset State BK2RS Breaker 2 in Reset State 79CY1a Relay in Single Pole Reclose Cycle State 79CY3 Relay in Three Pole Reclose Cycle State BK1LO Breaker 1 in Lockout State BK2LO ...

Page 1022: ...er 2 3POBK2 Three Pole Open Breaker 2 3POBK1 Three Pole Open Breaker 1 3POLINE Three Pole Open Line R3PTE Three Pole Tripping and Reclosing Only R3PTE1 Recloser Three Pole Trip Enable BK1 R3PTE2 Recloser Three Pole Trip Enable BK2 BK1CL Breaker 1 Close Command BK2CL Breaker 2 Close Command BK1CLST Breaker 1 Close Supervision Delay Timed Out BK2CLST Breaker 2 Close Supervision Delay Timed Out BK1CF...

Page 1023: ...e Breaker Active in Reclose Scheme NBK2 Two Breakers Active in Reclose Scheme LLDB1 Live Line Dead Bus 1 59L AND 27BK1 DLLB1 Dead Line Live Bus 1 27L AND 59BK1 DLDB1 Dead Line Dead Bus 1 27L AND 27BK1 LLDB2 Live Line Dead Bus 2 59L AND 27BK2 DLLB2 Dead Line Live Bus 2 27L AND 59BK2 DLDB2 Dead Line Dead Bus 2 27L AND 27BK2 a Only applicable to products that support single pole reclosing Table 6 24 ...

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Page 1025: ...e 7 13 MIRRORED BITS Remote Analog Metering on page 7 13 Monitor present power system operating conditions with instantaneous metering Maximum Minimum metering displays the largest and smallest system devia tions since the last reset Demand metering includes either thermal or rolling ana lyzes of the power system and peak demand metering Energy metering displays the megawatt hours imported megawat...

Page 1026: ...ort is negative see Figure 7 1 NOTE The SEL 487B does not include power and power factor in its metering reports For power factor LAG and LEAD refer to whether the current lags or leads the applied voltage The reactive power Q is positive when the voltage angle is greater than the current angle V I which is the case for inductive loads where the current lags the applied voltage Conversely Q is neg...

Page 1027: ... in the SER or anything that will trigger an event High Accuracy Instantaneous Metering The relay is a high accuracy metering instrument Table 7 2 and Table 7 3 show the metering accuracy for the relay instantaneous metering quantities at nominal power system frequency and at 20 C Use a method similar to that in Example 7 1 to compute exact error coefficients Figure 7 1 Complex Power P Q Plane Q P...

Page 1028: ...er 0 5 or 0 5 0 40 Example 7 1 Calculating Exact Error Coefficients Consider the case of a 5 A relay during normal operating conditions The secondary current in the CT is 1 0 A for nominal system operation Noting that this current is greater than 10 percent of INOM 1 A 0 5 A calculate the error coefficient error 0 2 1 0 A 0 8 mA INOM 0 002 1 0 A 0 0008 A 5 0 002A 0 004A 0 002 A to 0 006 A and 0 00...

Page 1029: ...answer Y and press ENT at the Maximum Minimum submenu reset prompt on the front panel LCD screen You can also reset maximum minimum metering with Global settings typically RST MML RSTMMB1 and RSTMMB2 Maximum Minimum Metering Updating and Storage The relay updates maximum minimum values once per power system cycle The relay stores maximum minimum values and the corresponding dates and times to nonv...

Page 1030: ... of the day you can optimize your system generation resources or your consumption of elec tric power The relay provides you this demand information and enables you to operate your power system with an effective economic strategy NOTE Not all SEL 400 series relays support demand metering The relay uses longer term accumulations of the metering quantities for reliable demand data Thermal Demand and ...

Page 1031: ...4 lists the rolling demand response for four DMTC peri ods shown in Figure 7 4 Rolling demand metering response is at 100 percent 1 0 per unit of the full applied value after a time equal to the fourth DMTC period see d in Figure 7 4 Figure 7 3 Thermal Demand Metering Step Current Input Thermal Demand Meter Response EDEM THM 1 0 1 0 0 9 0 5 0 0 5 0 0 5 10 15 0 5 10 15 Time minutes DMTC Period Time...

Page 1032: ...gure 7 4 Rolling Demand Metering Step Current Input Rolling Demand Meter Response EDEM ROL 1 0 1 0 67 33 0 0 5 0 DMTC Period a 0 5 10 15 Time minutes 0 5 10 15 Time minutes Step Current Input Rolling Demand Meter Response EDEM ROL 1 0 1 0 67 33 0 0 5 0 DMTC Period b 0 5 10 15 Time minutes 0 5 10 15 Time minutes Step Current Input Rolling Demand Meter Response EDEM ROL 1 0 1 0 67 33 0 0 5 0 DMTC Pe...

Page 1033: ...lues use the MET RD command from a commu nications terminal or use the RESET button in the QuickSet HMI Meter and Control Demand Peak window or answer Y and press ENT at the Demand Sub menu reset demand prompt on the front panel LCD screen The relay begins the demand meter sampling period from the time of the demand meter reset To reset the peak demand metering values enter the MET RP command from...

Page 1034: ...y imported and exported on a per phase basis every second As in demand metering the relay uses the longer term accumulations of rms or true real power for reliable energy data View or Reset Energy Metering Information You can read the energy metering quantities by using a communications port QuickSet or the relay front panel LCD screen To reset the energy values use the MET RE command from a commu...

Page 1035: ...on the relay records maximum and minimum battery volt ages Figure 7 6 shows a sample dc battery monitor meter report Use the MET BAT command from a communications terminal to obtain this report Any battery voltage between setting DCLWP and the dc battery monitor low limit of 15 Vdc is in the L Zone Battery voltages in the H Zone are voltages higher than the DCHWP setting Use the MET RBM command fr...

Page 1036: ...030645 Protection Analog Quantities PMV01 0 000 PMV02 0 000 PMV03 0 000 PMV04 0 000 PMV05 0 000 PMV06 0 000 PMV07 0 000 PMV08 0 000 PMV09 0 000 PMV10 0 000 PMV11 0 000 PMV12 0 000 PMV13 0 000 PMV14 0 000 PMV15 0 000 PMV16 0 000 PMV17 0 000 PMV18 0 000 PMV19 0 000 PMV20 0 000 PMV21 0 000 PMV22 0 000 PMV23 0 000 PMV24 0 000 PMV25 0 000 PMV26 0 000 PMV27 0 000 PMV28 0 000 PMV29 0 000 PMV30 0 000 PMV3...

Page 1037: ...umber 2008030645 Automation Analog Quantities AMV001 0 000 AMV002 0 000 AMV003 0 000 AMV004 0 000 AMV005 0 000 AMV006 0 000 AMV007 0 000 AMV008 0 000 AMV009 0 000 AMV010 0 000 AMV011 0 000 AMV012 0 000 AMV013 0 000 AMV014 0 000 AMV015 0 000 AMV238 0 000 AMV239 0 000 AMV240 0 000 AMV241 0 000 AMV242 0 000 AMV243 0 000 AMV244 0 000 AMV245 0 000 AMV246 0 000 AMV247 0 000 AMV248 0 000 AMV249 0 000 AMV...

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Page 1039: ...ese monitoring features are available online in real time you can detect impending problems immediately The result is better power system reliability and improved circuit breaker life expectancy NOTE This section lists settings for Circuit Breaker 1 The number of circuit breakers and the circuit breaker references vary between relays See the product specific instruction manual for the specific bre...

Page 1040: ...ree pole tripping circuit breaker set BK1TYP 3 The factory default setting is BK1TYP 1 Be sure to configure the relay with the settings that match your circuit breakers NOTE Some SEL 400 series relays use a BK_SEL setting to list enabled breakers rather than the EBnMON settings shown here Circuit Breaker Contact Wear Monitor The circuit breaker contact wear monitor in the relay provides informatio...

Page 1041: ...s on page 3 15 for information on setting the relay using these methods The default settings cause the contact wear monitor to integrate and increment each time the relay trip logic asserts Perform the following specific steps to use the circuit breaker contact wear monitor Step 1 Enable the circuit breaker monitor Step 2 Load the manufacturer s circuit breaker maintenance data Step 3 Preload any ...

Page 1042: ...ange B1COSP1 Close open set point 1 max 0 65000 close open operations B1COSP2 Close open set point 2 mid 0 65000 close open operations B1COSP3 Close open set point 3 min 0 65000 close open operations B1KASP1a a The ratio of settings B1KASP3 B1KASP1 must be in the range 5 B1KASP3 B1KASP1 100 kA interrupted set point 1 min 1 0 999 kA in 0 1 kA steps B1KASP2 kA interrupted set point 2 mid 1 0 999 kA ...

Page 1043: ...this point the mechanical circuit breaker service life Figure 8 3 Circuit Breaker Contact Wear Curve With Relay Settings B1COSP2 1 10 100 kA Interrupted per Operation kA Number of Close Open Operations 10000 1000 100 10 B1COSP3 B1KASP1 B1KASP2 B1KASP3 B1KASP1 B1COSP1 B1KASP2 B1COSP2 B1KASP3 B1COSP3 B1COSP1 Example 8 1 Creating the Circuit Breaker Contact Wear Curve Acquire the manufacturer s maint...

Page 1044: ...time I2 t for circuit breaker maintenance For example manufacturer s data specify I2 t per phase at 750 kA2 seconds for a particular circuit breaker at a rated arcing duration for each trip of 1 cycle The circuit breaker maximum interrupting current rating is 40 kA and the continuous load current rating is 2 kA You can construct the contact wear curve for this circuit breaker from the specified I2...

Page 1045: ... Three pole tripping uses the single setting BM1TRPA for all three poles Initiation settings can include both internal and external tripping conditions To capture trip information initiated by devices other than the relay you must pro gram the SELOGIC control equation BM1TRP to sense these trips Table 8 4 Circuit Breaker Monitor Initiate SELOGIC Control Equations Name Description Commenta a See Ta...

Page 1046: ...t The worst case for this condition occurs when the circuit breaker is open auxiliary circuit breaker 52A contact in Figure 8 4 is open You can change the input debounce time IN206PU for slow or noisy mechanical switches the default debounce time of 1 8 cycle should be sufficient for most trip bus arrangements Use the SET G GLOBAL command or the QuickSet Global Control Inputs Settings tree view to...

Page 1047: ...ption current with setting B1MKAI Maximum kA Interrupt Rating BK1 If the percent of current interrupt that the relay records exceeds threshold setting B1KAIAT kA Interrupt Capacity Alarm Threshold BK1 the relay asserts breaker monitor alarm Relay Word bit B1KAIAL Mechanical Operating Time The mechanical operating time is the time between trip initiation or close initia tion and the associated phas...

Page 1048: ...IC Equation Connect external trip signals to IN301 IN302 and IN303 and external close signals to IN304 IN305 and IN306 for the A B and C Phases respec tively Use the default settings for input conditioning debounce time and assertion level as with inputs IN201 to IN203 above Set the mechanical operating time threshold for the slow trip alarm B1MSTRT to 30 ms and the slow close alarm threshold B1MS...

Page 1049: ... to the restoration of phase quantities The relay compares these tripping or clos ing times to the electrical slow operation time thresholds for tripping and closing B1ESTRT and B1ESCLT respectively The relay issues an electrical slow opera tion alarm B1ESOAL for 5 seconds when trip or close times exceed these thresh olds Figure 8 6 shows the timing diagram for the A Phase pole of Circuit Breaker ...

Page 1050: ...our installation The control volt age for this example is 125 Vdc Control Inputs IN201 IN206 are located on the relay I O Interface board 1 Set the electrical operating time threshold for the slow trip alarm B1ESTRT at 25 ms and the slow close alarm threshold B1ESCLT at 65 ms Use your company standard practices to determine these settings for your application For this example enter the following s...

Page 1051: ...ker 1 NOTE Pole scatter applies only to single pole mechanism circuit breakers BK1TYP 1 These circuit breakers have an auxiliary circuit breaker 52A contact for each phase Figure 8 7 shows the operating time for each pole A B and C of Circuit Breaker 1 TAB represents the operating time deviation between poles A and B TBC is the time between B and C and TCA is the time between C and A Once activate...

Page 1052: ...signals to IN204 IN205 and IN206 for the A B and C Phases respec tively This example uses control inputs IN201 IN206 you can use any con trol inputs that are appropriate for your installation Set the pole scatter trip alarm time threshold B1PSTRT at 4 ms the pole scatter close alarm time threshold B1PSCLT at 6 ms and the pole discrep ancy time delay B1PDD at 1400 ms Use your company standard pract...

Page 1053: ...tting B1PDD should be longer than the single pole reclosing dead time B1PDD SPOID circuit breaker pole operating time contact latency 1 2 Equation 8 4 where SPOID is the single pole open interval time and the factor 1 2 is a safety factor Round this time to the next higher hundreds of milliseconds value to give the pole discrepancy setting Figure 8 8 shows a Circuit Breaker 1 operation where Pole ...

Page 1054: ...quation 52AC1 IN303 C Phase Normally Open Control Input BK1 SELOGIC Equation Connect external trip signals to IN301 IN302 and IN303 and external close signals to IN304 IN305 and IN306 for the A B and C Phases respec tively This example uses control inputs IN301 IN306 you can use any con trol inputs that are appropriate for your installation Set the pole discrepancy time delay B1PDD at 1400 ms This...

Page 1055: ...RTIN is a SELOGIC control equation to activate the motor running timer The rising edge of B1MRTIN indicates the motor starting time a falling edge indicates the motor stop time The motor running time logic asserts the alarm Relay Word bit B1MRTAL for 5 seconds when the motor running time exceeds the predefined threshold Setting B1MRTIN to logical 0 disables the motor running time feature of the ci...

Page 1056: ... However the relay continues to advance the operation counter to as many as 9999999 operations per pole until reset Accu mulated circuit breaker wear operations data are retained if the relay loses power or if the circuit breaker monitor is disabled EBnMON N The control voltage for this example is 125 Vdc Control Input IN207 is located on the relay I O Interface board 1 The recharge time measureme...

Page 1057: ... 8 24 4 26 5 30 1 26 3 34 2 Inactivity Time days 1 1 1 1 1 1 3 Pole Trip 3 Pole Close AB BC CA AB BC CA Max Pole Scatter ms 5 1 3 1 5 0 6 3 4 1 2 1 Last Pole Scatter ms 2 1 1 0 3 1 4 1 2 1 2 1 Pole A Pole B Pole C Accum Pri Current kA 3 13657 0 43533 0 41785 Accum Contact Wear 0 5 0 5 0 5 Max Interrupted Current 1 6 0 2 0 2 Last Interrupted Current 1 6 0 2 0 2 Number of Operations 5 5 5 Alarm Tota...

Page 1058: ... the Compressed ASCII circuit breaker report in a spe cial order For the purpose of improving products and services SEL sometimes changes the items and item order The information presented below explains the message and serves as a guide to the items in a Compressed ASCII configuration circuit breaker report The format of the Compressed ASCII CBR message is the following BRE 1 P Enter Accum Contac...

Page 1059: ...the dc voltage ac ripple and voltage between each battery terminal and ground SEL 400 series relays provide either one or two dc monitor channels See the product specific instruction manual to see how many breaker monitor channels the relay supports Four voltage thresholds give you the ability to create five sens ing zones low failure low warning normal high warning and high failure for the dc vol...

Page 1060: ...w to apply the dc battery monitor to a typical 125 Vdc protection battery system with a 48 Vdc communications equipment battery system Adjust the values used here to meet the specifications of your company Battery Voltage When setting the station dc battery monitor you must determine the minimum and maximum dc levels in the battery system In addition you must also establish the threshold levels fo...

Page 1061: ...ndard also identifies an Allowable AC Component in DC Con Table 8 8 Example DC Battery Voltage Conditions Condition Calculation Battery Voltage Vdc Trip Close 80 125 Vdc 100 0 Open Circuit 60 cells 2 06 volts cell 123 6 Float Low 60 cells 2 15 volts cell 129 0 Float High 60 cells 2 23 volts cell 133 8 Equalize Mode 60 cells 2 33 volts cell 139 8 Trip Close 80 48 Vdc 38 4 Open Circuit 24 cells 2 06...

Page 1062: ...ound battery voltage to the negative to ground battery voltage is 1 to 1 or 1 00 Equation 8 5 is the balanced no grounding ratio for a 125 Vdc battery system Equation 8 5 If either terminal is partially or completely shorted to chassis ground then the terminal voltage will be less than the nominal terminal to ground voltage This causes the ratio of positive voltage to negative voltage to differ fr...

Page 1063: ...can use the battery monitor Relay Word bits to alert operators for out of tol erance conditions in the battery systems Add the appropriate Relay Word bit to the SELOGIC control equation that drives the relay control output you have selected for alarms For example use the Form B contact of control output OUT214 Set the SELOGIC control equation to include the battery monitor thresholds OUT214 NOT HA...

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Page 1065: ...parisons of data across the power system Use a coordinated network of time synchronized relays to create moment in time snapshots of the power system These data are useful for determining power system dynamic voltage and current phasors impedances load flow and system states Data Processing SEL 400 series relays are numeric or microprocessor based relays that sample power system conditions The rel...

Page 1066: ...see Oscillography on page 9 9 Figure 9 2 shows the path a power system signal received via SV remote data acquisition takes through relay processing The received SV messages are first filtered decoded scaled and resampled The resampled data then continues through software filtering and progresses to protection and automation process ing The relay resamples the 4 8 kHz 4 kHz SV messages to 8 kHz an...

Page 1067: ...g 8 kHz A D Low Pass Filter Hi Res Data COMTRADE Breaker Monitor 8000 samples second Anti Alias Digital LPF Voltages Currents Control Inputs Optoisolated V I Source Select Debounce A D Hardware Software Filtered Event Report Metering SER Protection and Automation RMS Digital Filter Half Cycle Digital Filter 1 Cycle Cosine Digital Filter Digital Elements Analog Quantities Sync IRIG B BNC Time of Sa...

Page 1068: ...n the raw data are viewed The relay filters both types of control inputs with settable debounce timers and updates the resulting Relay Word bits every processing interval Event reports can include the filtered control input Relay Word bits Control input state changes will appear to occur faster in COMTRADE oscillog raphy files than in event reports EVE command or Sequential Events Recorder reports...

Page 1069: ...e Filtered Event Report Metering SER Protection and Automation RMS Digital Filter Half Cycle Digital Filter 1 Cycle Cosine Digital Filter Digital Elements Analog Quantities Sync IRIG B BNC Time of Sample High Accuracy Clock PROTO PMU serial port s Filter and Down Sample Correlated to GPS Time Reference Synchrophasors 50 or 60 per second depending on NFREQ setting Digital Elements except control in...

Page 1070: ... causes the relay to begin recording data You therefore do not have to enter any condition that causes a trip in the ER SELOGIC control equa tion SELOGIC Control Equation ER Program the SELOGIC control equation ER to trigger high resolution raw data oscillography traveling wave data oscillography and standard event reports for conditions other than TRIP conditions When ER asserts the relay begins ...

Page 1071: ...gering element causes ER to assert then clears the way for other elements to assert ER because the relay uses only the beginning of a long element assertion The starting element in a continuously occurring fault does not mask other possi ble element triggers This allows another rising edge sensitive element to generate another event report later in that same continuously occurring fault such as an...

Page 1072: ... sampling rate of 1 5625 MHz and a fixed event length of 7 5 ms NOTE PRE has a dynamic range based on the current value of LER The upper range of PRE LER 0 05 The relay stores all data captures to volatile RAM and then moves these data to nonvolatile memory storage There is enough volatile RAM to store one maxi mum length capture maximum LER time for a given SRATE No data captures can be triggered...

Page 1073: ...ffective sampling rates The high resolution raw data and travel ing wave data oscillograms are available as files through the use of Ymodem file transfer and File Transfer Protocol FTP in the binary COMTRADE file format output IEEE Std C37 111 1999 Common Format for Transient Data Exchange COMTRADE for Power Systems The filtered data oscillograms give you accurate information on the relay protec t...

Page 1074: ...n by the ERDG setting The relay stores high resolution raw data oscillography in binary format and uses COMTRADE file types to output these data HDR header file CFG configuration file DAT high resolution raw data file The HDR file contains summary information about the event in ASCII format The CFG file is an ASCII configuration file that describes the layout of the DAT file The DAT file is in bin...

Page 1075: ... ANG DEG 0 0 0 0 0 0 0 0 0 0 Summary Event Information SET_G1 TXT INFO RELAYTYPE SEL 411L FID SEL 411L X136 V0 Z001001 D20110114 BFID SLBT 4XX R205 V0 Z001002 D20100128 PARTNO 0411L0X6X1B6BCXH5C4E4XX IOBOARDS INT4_E 24 8 0 0 1 CFSINT8 8 8 0 0 2 G1 SID Station A RID Relay 1 NUMBK 2 BID1 Breaker 1 BID2 Breaker 2 NFREQ 60 AR197 AR198 AR199 AR200 Relay Settings Figure 9 5 Sample COMTRADE HDR Header Fi...

Page 1076: ...ains no carriage return line feed characters The sequential position of the data in the binary file determines the data transla tion Refer to the IEEE Std C37 111 1999 Common Format for Transient Data Exchange COMTRADE for Power Systems for more information Programs that read the binary COMTRADE files include ACSELERATOR Analytic Assis tant SEL 5601 Software and ACSELERATOR QuickSet SEL 5030 Softw...

Page 1077: ... event Event Reports Event Summaries and Event Histories Event reports simplify post fault analysis and help you improve your understand ing of protection scheme operations Event reports also aid in testing and trouble shooting relay settings and protection schemes because these reports contain detailed data on voltage current and relay element status For further analysis assistance the relay appe...

Page 1078: ... port by using the EVE N EXT command You can use the EVE command and a terminal to retrieve event reports by event order or by event serial number The relay labels each new event with a unique serial number as reported in the HIS command history report see Event History on page 9 27 Events are referenced two ways by relative reference or by event serial number Relative references are in the range ...

Page 1079: ...he report lists the RID setting Relay ID and the SID setting Station ID The FID string identifies the relay model flash firmware version and the date code of the firmware The relay reports a date and time stamp to indicate the internal clock time when the relay triggered the event The relay reports the firmware checksum as CID The event report column labels follow the header The data underneath th...

Page 1080: ...eeform line number chronologically with the ERAQc quantities In this example ERAQ01 PMV01 ERAQ02 PMV02 etc In the event report the ERAQ quantities follow the fixed analog quantities 9 128 5623 8479 2984 287 1 213 9 3 5 216 1 143 8 234 5 173 6821 1924 4724 219 8 47 3 214 0 289 7 331 7 180 4 126 5540 8404 2990 286 6 213 7 3 5 216 3 143 7 227 3 177 6749 1860 4713 220 0 47 4 212 9 289 6 331 8 176 2 10...

Page 1081: ...t ac current column data to the sampled waveform and rms values Figure 9 8 shows how to find the phasor angle If you use the larger 8 samples cycle event report take every other sample and apply those values in this procedure This examples assumes you have captured an event report and are prepared to calculate phasors from it Step 1 Calculate the phasor magnitude a Select a cycle of data from the ...

Page 1082: ...ent Histories Figure 9 7 Event Report Current Column Data and RMS Current Magnitude 0 t 378 107 378 107 267 267 76 266 76 IA Y previous 1 4 cycle X present sample Y 267 θ X 76 76 266 76 1 4 cycle Raw Waveform multiply by 2 2 Event Report Column Data 7 6 2 2 6 7 2 2 7 6 6 θ arctan Y X arctan 267 76 105 9 degrees ...

Page 1083: ... event report as you did when finding the magnitude Cycle 1 data for this example b Compute phasor angle using the following expression Equation 9 2 In Equation 9 2 Y is the first or previous value IA column current of a data pair and X is the present value of the pair For this example the computation shown in Figure 9 8 yields 105 9 degrees c Compute phasor angles from the remaining data pairs fo...

Page 1084: ... and third quadrants when X is negative When in doubt graph the X and Y quantities to confirm that the angle that your calculator reports is correct Figure 9 8 Event Report Current Column Data and RMS Current Angle 0 t 378 107 378 107 267 267 76 266 76 IA Y previous 1 4 cycle X present sample Y 267 θ X 76 76 266 76 1 4 cycle Raw Waveform multiply by 2 2 Event Report Column Data 7 6 2 2 6 7 2 2 7 6...

Page 1085: ...a scaled instantaneous current value not an rms quantity that relates to the rms phasor current value by the expression Equation 9 5 Polar Calculator Method A method for finding the phasor magnitude and angle from event report quarter cycle data pairs is to use a polar capable calculator or computer program Many calculators and computer programs convert Cartesian X and Y coordinate data to polar d...

Page 1086: ... every 79 columns the relay generates a new report that follows the previous report The report displays the digital label header for each column in a vertical fashion aligned on the last character For example if the first digital section elements are IN201 RMBA5 Z2P LBOKA OUT203 OUT204 and HALARM the header appears as in Figure 9 10 If the Relay Word bits included in the header were assigned alias...

Page 1087: ...s When you enter an input INnnn in the event digitals list the relay displays the filtered input with time latency in the event report and the Compressed ASCII event report However in the binary COMTRADE file event report the relay reports the actual high sample rate capture time for relay inputs Event Summary Section of the Event Report The third portion of an event report is the summary section ...

Page 1088: ...R Event Number 10030 Shot 1P 0 Shot 3P 0 Freq 60 00 Group 1 Targets INST COMM 87L Breaker 1 CLOSED Trip Time 11 18 49 016 Breaker 2 NA Event Information PreFault IA IB IC IG 3I2 VA VB VC V1mem MAG A kV 426 426 427 1 0 286 420 286 638 286 302 286 453 Prefault Data ANG DEG 1 3 118 7 121 3 130 6 99 2 0 0 120 0 120 0 0 0 Fault MAG A kV 426 426 427 1 1 286 397 286 632 286 298 286 450 Fault Data ANG DEG...

Page 1089: ... Reporting in the product specific instruction manual for a list of these bits Additionally it includes the rows containing those Relay Word bits configured for inclusion by the ERDG setting For the purpose of improving products and services SEL sometimes changes the items and item order Output Interface Board 1 OUT201 3PT OUT202 BK1CL OUT203 BK2CL OUT204 NA OUT205 NA OUT206 NA OUT207 NA OUT208 NA...

Page 1090: ...rst use the SUM N EXT command to view that summary You can use the SUM command to retrieve event summaries by date or date range and by event number The relay labels each new event with a unique num ber as reported in the HIS command history report see Event History on page 9 27 Table 9 2 lists the SUM commands See SUMMARY on page 14 52 for complete information on the SUM command You can also view...

Page 1091: ...Items that are below the blank row are no longer in relay memory these events appear in the history report to indicate past power system performance The relay does not ordinarily modify the numerical or time order in the history report However if an event report is corrupted power was lost during storage for example the relay lists the history report line for this event after the blank row Viewing...

Page 1092: ... the history report file from the relay Use a terminal emu lation program with file transfer capability At an Access Level 1 prompt or higher type FILE READ REPORTS HISTORY TXT Enter Start the termi nal download routine to store the file on your computer If you want the Com pressed ASCII file type FILE READ REPORTS CHISTORY TXT Enter In addition you can use QuickSet to download history files Seque...

Page 1093: ... The SER CV or SER RV command will not clear any SER data that has been recorded but not viewed on a particular serial port To clear all SER data on a serial port use the SER C or SER R command To clear all SER data from all serial ports use the SER CA or SER RA com mand available only from Access Levels P A O and 2 This procedure would normally be used after relay commissioning or testing Use an ...

Page 1094: ...tom of the list SER m na a The parameters m and n indicate SER numbers that the relay assigns at each SER trigger Return the SER records from m to n If m is greater than n records appear with the oldest highest number at the top of the list and the most recent lowest number at the bottom of the list If m is less than n records appear with the most recent lowest number at the top of the list and th...

Page 1095: ...wer up relay enable and relay dis able any group change and settings change diagnostic restart and memory over flow Automatic Deletion and Reinsertion The SER also includes an automatic deletion and reinsertion function The relay automatically deletes oscillating SER items from SER recording This function prevents overfilling the SER buffer with chattering information Set Report set ting ESERDEL E...

Page 1096: ...gnal Profile Acquisition Rate Although you can select as many as 20 analog quantities the signal acquisition rate is the same for all analog quantities Select an acquisition rate of 1 5 15 30 or 60 minutes SPEN Signal Profile Enable Use this SELOGIC control equation to specify conditions under which the profil ing must take place If there are no conditions be sure to set SPEN 1 or else no data are...

Page 1097: ...1 All SEL 400 series relays are factory calibrated this section contains no calibra tion information If you suspect that the relay is out of calibration contact your Technical Service Center or the SEL factory Testing Philosophy Protective relay testing generally consists of three categories acceptance testing commissioning testing and maintenance testing The categories differ in testing complexit...

Page 1098: ... operational Use TEST DB TEST DB2 and TEST FM to check SCADA interfaces See TEST DB on page 14 55 TEST DB2 on page 14 56 and TEST FM on page 14 57 for information on these relay commands Table 10 2 lists guidelines for commissioning testing For further discussion of these tests see Checking Relay Operation in Section 3 Testing of the product specific instruction manual Table 10 1 Acceptance Testin...

Page 1099: ... changed If the topology needs to be changed e g modules are added or replaced the system will need to be recom missioned by pressing the COMMISSION pushbutton When the commissioning and validation of the topology is complete the voltages and currents will be mapped according to the topology assignments see Section 2 Installation in the product specific instruction manual Secondary injection testi...

Page 1100: ...t each maintenance interval the only items to be tested are those that have not operated via fault conditions and otherwise during the maintenance interval The basis for this testing philosophy is simple you do not need to perform fur ther maintenance testing for a correctly set and connected relay that measures the power system properly and for which no relay self test has failed SEL 400 series r...

Page 1101: ...rents and voltages magnitude and phase angle connected to the relay in primary values In addition metering shows many other quantities including the power system fre quency FREQ and the voltage input to the station dc battery monitors Vdc1 and Vdc2 Compare these quantities against quantities from other devices of known accuracy The metering data are available at the serial ports from the ACSELERAT...

Page 1102: ...against the reported fault location and fault type If you question the relay response or your test method you can obtain the full event report and the high resolution oscillographic report for a more detailed analysis See Event Summary on page 9 26 for more information on the event summary SER Reports The relay provides an SER report that time tags changes in relay elements con trol inputs and con...

Page 1103: ...f relay elements and other relay functions Target indications element pickup dropout Control output closures SER reports The tests and procedures in the following subsections are for 5 A relays Scale values appropriately for 1 A relays Once you have completed a test return the relay settings that you modified for the test to default or operational values Testing With Relay Word Bits Use the commun...

Page 1104: ...ust have a computer that is communicating with the relay and running QuickSet see Making Settings Changes in Initial Global Settings on page 3 20 Step 1 Prepare to control the relay with QuickSet by establishing communi cation checking passwords and reading relay settings Step 2 Click the Outputs Main Board branch of the QuickSet Settings tree structure to view output settings shown in Figure 10 2...

Page 1105: ... The relay responds with the Transfer Status dialog box as shown in Figure 10 3 If you see no error message the new settings are loaded in the relay Step 6 Connect an indicating device to OUT105 on the relay rear panel A VOM multi tester on a low resistance scale can indicate an OUT105 control output closure Step 7 Connect a test source to the relay a Set the current output of a test source to zer...

Page 1106: ...o capture the selectable operating quantity time overcurrent element 51S1 operat ing times The procedure also shows how to set the torque control supervision for the 51S1 element The relay uses Equation 10 1 and Equation 10 2 to determine the operating time for the 51S1 element For a current input 50 percent greater than the default pickup the test value ITEST is Equation 10 1 where M is the picku...

Page 1107: ...source for relay testing Step 1 Prepare to control the relay with QuickSet by establishing communi cation checking passwords and reading relay settings Step 2 Set the selectable operating quantity time overcurrent element for test operation a Open the Group 1 Set 1 Relay Configuration Time Over current branch of the Settings tree view see Figure 10 4 b Verify that enable setting E51S Selectable In...

Page 1108: ...oubleshooting andMaintenance Test Methods Step 3 View the SER settings a Click the next to the Report branch of the QuickSet Settings tree view structure shown in Figure 10 5 b Click on the SER Points and Aliases branch Figure 10 4 Checking the 51S1 Overcurrent Element QuickSet ...

Page 1109: ... a Step h for SITM2 SER Points and Aliases Point 2 with setting values 51S1 GROUND O C 1 LINE 1 51S1 PICKED UP 51S1 RESET Figure 10 5 shows the entry field for SITM2 just before pressing the OK button You can enter as many as 250 relay elements in the SER Points and Aliases list see Sequential Events Recorder SER on page 9 28 Step 5 Click File Save to save the new settings in QuickSet Step 6 Uploa...

Page 1110: ...urrent magnitude of 1 125 A secondary in the relay b Keep the current source at this level past the expected element time out longer than 3 2 seconds c Return the current source to zero after the element times out Step 9 Select the HMI menu top toolbar to start the QuickSet HMI interface Step 10 View the SER report Click the SER button of the HMI tree view QuickSet displays the SER report similar ...

Page 1111: ...rance condition causes the relay to declare a status failure and enter a protec Figure 10 7 SER Report QuickSet HMI Table 10 5 Alarm Relay Word Bits Alarm Relay Word Bit Description HALARML Latches for any relay failures HALARMP Asserts for five seconds when a warning condition occurs HALARMA Starts pulsing for five seconds every minute whenever a new warning condi tion occurs and continues to pul...

Page 1112: ...enter or the SEL factory immediately see Technical Support on page 10 31 The relay generates an automatic status report at the serial ports for a self test sta tus failure if you set Port setting AUTO Y The relay issues a status message with a format identical to the STATUS command output but includes the power supply information from the STA A response The relay also displays status warning and s...

Page 1113: ... A Serial Number 0000000000 FID SEL 451 5 Rxxx V0 Zxxxxxx Dyyyymmdd CID 0xxxxx Failures No Failures Warnings No Warnings Channel Offsets mV W Warn F Fail CH1 CH2 CH3 CH4 CH5 CH6 CH7 CH8 CH9 CH10 CH11 CH12 MOF 0 0 0 0 0 0 0 0 0 0 0 0 0 Power Supply Voltages V W Warn F Fail 3 3V_PS 5V_PS N5V_PS 15V_PS N15V_PS 3 28 4 91 4 93 14 70 14 79 Temperature 23 7 degrees Celsius Communication Interfaces Active...

Page 1114: ...eed to Troubleshooting Procedures on page 10 19 Step 1 Confirm that the power is on Do not turn the relay off Step 2 Measure and record the control power voltage at the relay POWER ter minals marked and on the rear panel terminal strip Step 3 Measure and record the voltages at all control inputs Step 4 Measure and record the state of all control outputs Step 5 Inspect the serial communications por...

Page 1115: ...n See Table 10 7 Other self test failure LCD displays STATUS FAILURE screen See Table 10 7 System Does Not Respond to Commands NOTE If Port setting PROTO PMU that serial port will not respond to ASCII commands Additionally a PROTO PMU port will not respond to any messages when Global setting EPMU N No communication Confirm cable connections and types If correct type Ctrl X Enter This resets the te...

Page 1116: ...control output connection Check continuity Form A con tacts should be open and Form B contacts should be closed Contact the SEL factory or your Technical Service Center if continuity checks fail I O interface board failure LCD displays STATUS FAILURE screen Contact the SEL factory or your Technical Service Center Time Date Errors External IRIG time source error Check IRIG B time source or cables C...

Page 1117: ...vice Center Power Supply Voltage Status Warning Power supply voltage s are out of tolerance Log the Status Warning If repeated warnings occur take preventive action A D converter failure LCD displays STATUS FAILURE screen Contact the SEL factory or your Technical Service Center Power Supply Voltage Status Failure Power supply voltage s are out of tolerance LCD displays STATUS FAILURE screen Contac...

Page 1118: ...e spent battery from beneath the clip of the battery holder Step 8 Replace the battery with an exact replacement Use a 3 V lithium coin cell Ray O Vac No BR2335 or equivalent The positive side of the battery faces up Step 9 Reinstall the relay main board drawout tray Step 10 Reattach the power cable interface board cable s and input board analog cable Step 11 Reconnect the front panel cable to the...

Page 1119: ... board s Step 14 Locate the power supply Fuse F1 is at the rear of the power supply circuit board see Figure 10 11 Step 15 Examine the power supply for blackened parts or other damage If you can see obvious damage reinstall all boards and contact SEL to arrange return of the relay for repair Step 16 Remove the spent fuse from the fuse clips Step 17 Replace the fuse with an exact replacement see Se...

Page 1120: ...uipped to work with these components contact SEL about returning this device and related SEL equipment for service Step 1 Follow your company standard to remove the relay from service It will be necessary to remove power from the relay as part of this pro cess Step 2 Disconnect power from the relay Isolate any contact inputs or out puts that will be affected by the installation of the I O interfac...

Page 1121: ...the relay front panel hang from this ribbon cable c Remove the ribbon cable at the front panel by pushing the cable retention levers toward the back of the front panel as shown in Figure 10 13 If your front panel is equipped with auxiliary trip and close pushbuttons remove the connectors to the pushbuttons connected at the front panel and the expansion I O board Step 7 Remove the power supply expa...

Page 1122: ...t jumper configuration for the interface board being installed For example the jumper configuration in Figure 10 15 a is for an inter face board being installed at the 300 level i e the jumpers are set to ON OFF ON OFF Step 10 Install the drawout tray with the I O interface board a Position the drawout tray edges into the left side and right side internally mounted slots b Slide the I O interface ...

Page 1123: ...n the rear of the I O interface board Figure 10 16 shows the I O board section without terminal blocks The yellow dividers are the connector keying for each terminal block b Refer to Figure 10 17 for the corresponding key positions inside the receptacle Figure 10 16 Screw Terminal Connector Receptacles Figure 10 17 Screw Terminal Connector Keying Key A B C 2 1 3 C A B B 2 1 3 A C 1 2 3 200 Address...

Page 1124: ...b 0 8 Nm to 1 4 Nm Step 13 Reconnect the power the interface board and the analog input board cables to the relay main board Step 14 Reconnect the cables removed in Step 6 Step 8 and reinstall the relay front panel cover Step 15 Apply power Step 16 Reconnect any serial cables that you removed from the communica tions ports in the disassembly process Step 17 Establish a terminal emulation session w...

Page 1125: ...e terminal emulation window following an STA command as shown in Figure 10 19 Step 2 Disconnect power to the relay and return to Step 8 to verify you have correctly configured the jumpers Step 9 If the jumpers are not cor rect repeat the I O board installation instructions beginning with Step 9 Step 3 If the jumpers are correct enter the CAL level a Enter the VEC D command b If you see the error S...

Page 1126: ...gable however if a module is removed the TiDL system will be disabled the same as powering off the unit Step 2 Loosen the chassis retaining screw at the top of the module Step 3 Tip the top of the module away from the chassis and lift it from the bottom lip Step 4 Install the new module inserting the bottom lip first by using the notch on the module to help with alignment see Figure 10 20 Then pus...

Page 1127: ... power to the SEL relay Step 8 When startup is complete press and hold the COMMISSION button on the back of the relay for two seconds for the relay to verify the con nected topology Technical Support We appreciate your interest in SEL products and services If you have questions or comments please contact us at Schweitzer Engineering Laboratories Inc 2350 NE Hopkins Court Pullman WA 99163 5603 U S ...

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Page 1129: ...calculates synchrophasors for currents and line voltages for each phase and for positive sequence as specified in IEEE C37 118 Standard for Synchrophasor Measurements for Power Sys tems You can then perform detailed analysis and calculate load flow from the synchrophasors See Section 18 Synchrophasors for more information about phasor measurement functions in the relay This section presents detail...

Page 1130: ...8 can be used for high accuracy timekeeping The relay can only be synchronized by a grandmaster on the PTP timescale not an arbitrary ARB timescale With the ARB timescale the epoch is set by an administrative procedure and can change at any time during normal operation The PTP timescale uses the PTP epoch of Jan uary 1 1970 00 00 00 TAI International Atomic Time which corresponds to December 31 19...

Page 1131: ...n to PTP the master clock sync and announce interval must not exceed four seconds The Relay Word bit PTP_TIM indicates that this basic level of synchronization has been achieved If the master clock reports an accuracy of 1 s or better and the network is not introducing excessive jitter in the time synchronized messages PTP_OK will be set indicating the presence of high accuracy time synchronizatio...

Page 1132: ...is synchronized If PTPPORT 1 the relay is synchronized via Ethernet Port 5A If PTPPORT 2 the relay is synchronized via Ethernet Port 5B The ASCII command COM PTP also displays the port status in COM PTP on page 14 14 If a port is selected to synchronize the relay the port status is ACTIVE otherwise it is PASSIVE Time Source Selection IRIG B via BNC connection IRIG B via Serial Port 1 and PTP can a...

Page 1133: ...e place If you are using a time source that provides time quality information IRIG B with C37 118 or PTP then the presently reported time quality is available via the TQUAL analog quantity and the TQUAL1 TQUAL2 TQUAL4 and TQUAL8 Relay Word bits Table 11 3 and Table 11 4 show how these are encoded for IRIG and the two supported PTP Profiles Table 11 2 CUR_SRC Encoding Source CUR_SRC value BNC IRIG ...

Page 1134: ...ut the grandmaster clock sending announce and synchronization messages at least every four seconds TLOCAL bit will be asserted As an example of checking IRIG status use the command TAR TIRIG to view the relevant Relay Word bits as shown in Figure 11 2 Only the state of the TIRIG and TSOK Relay Word bits are discussed in the troubleshooting steps below The other Relay Word bits of interest to this ...

Page 1135: ...te the relay master time Likewise TSER asserts when serial IRIG is selected and TPTP asserts when PTP is the active source updating the relay master time At any given time only one of these three bits can equal logical 1 Global Time Source vs Local Time Source An SEL 400 series relay indicates that it is synchronized with either a Global or local time source according to the logic as shown in Figu...

Page 1136: ...hanges significantly between successive TIME Q commands there may be too much noise in the time signal for the relay timekeeping function TIM Q Enter Relay 1 Date 02 24 2016 Time 15 08 41 468 Station A Serial Number 0000000000 Time Source HPTP Last Update Source HPTP Grandmaster Clock Quality Clock Class Synchronized with PTP timescale 6 Time Traceable TRUE Clock Accuracy Within 25 ns Offset Log V...

Page 1137: ...DSTP is valid only when IRIG is the active source When PTP is selected it sets the DSTP bit to zero at all times If no high priority source with daylight saving time information is available the DST bit is determined based on the BEG_DST and END_DST Global settings When using PTP as the Time Synchronization source the PTP master may not provide valid DST information as the relay powers up To ensur...

Page 1138: ... b On the left side of the SELOGIC control equation select Math Variables and double click PMV64 c On the right side of the equation select Analog Quantities Time and Date Management d Double click THR Time in Hours e Use the character to add a comment to the line f When finished click Accept Step 5 In a similar manner build a freeform SELOGIC control equation pro gram in Protection Logic that cau...

Page 1139: ...files for the time triggered data captures from each relay with the FILE READ command Parse the binary COMTRADE data for the power system currents and voltages you need to calculate system quantities Fault Analysis Use the relay measurement and communications capabilities to obtain precise simultaneous measurements from the power system at different locations Com bining system measurements from a ...

Page 1140: ...t that instant Use the synchronized phasor measurement capabilities of the relay and the METER PM command or a Synchrophasor Protocol to collect synchronized voltage and current data Use this information to confirm your power flow models For example consider four SEL 421 Relays installed in the power system as shown in Figure 11 7 Substations S and R provide generation for the load at Substation T...

Page 1141: ... IBT S 238 995 A 101 9 VCT S 295 603 kV 118 4 ICT S 238 995 A 18 1 SEL 421 at Substation T Looking Toward Substation R VAT R 295 603 kV 1 6 IAT R 234 036 A 135 8 VBT R 295 603 kV 238 4 IBT R 234 036 A 15 8 VCT R 295 603 kV 118 4 ICT R 234 036 A 104 2 where S3 Three phase complex power MVA P3 Three phase real power MW Q3 Three phase imaginary power MVAR Vpp Phase to phase voltage Vp Phase to neutra...

Page 1142: ...ations Send the relay synchrophasor messages to a central database to determine the power system state Power system contingency analysis models rely on state estimation techniques and may have inaccuracies caused by incorrect present state information or errors in system characteristics such as incorrect line and source impedance esti mates The simultaneous event report triggering technique descri...

Page 1143: ...in this sec tion are unabbreviated and show all possible setting options This section describes how settings are organized explains the concept of set tings groups and then describes some common relay settings Settings Structure on page 12 1 Multiple Setting Groups on page 12 4 Port Settings on page 12 6 DNP3 Settings Custom Maps on page 12 15 Front Panel Settings on page 12 15 Alias Settings on p...

Page 1144: ...E21MG E21MG E21XG E21XG Enables EDCMON EICIS EDRSTC DC1 Mon DC1LFP DC1LWP Setting Mho Phase Dist Mho Phase Dist Z1MP Z1MP Z2MP Z2MP Setting Setting Table 12 1 Typical Settings Classes and Instances Sheet 1 of 2 Class Description Instance Description ASCII Command Access Level Global Relay wide applications settings Global SET G P A O 2 Group Individual scheme settings Group 1 Group 6 Group 1 setti...

Page 1145: ...mmunications port settings PORT F PORT 1 PORT 3 PORT 5 Front panel port PORT 1 settings PORT 3 settings Ethernet card settings SET P F SET P 1 SET P 3 SET P 5 P A O 2 Report Event report and SER settings Report SET R P A O 2 Front Panel Front panel HMI settings Front Panel SET F P A O 2 Protection SELOGIC control equations Protection related SELOGIC con trol equations Group 1 Group 6 Group 1 prote...

Page 1146: ...Fast Operate Fast SER Messages and Fast Message Data Access on page 15 28 Shown with DNP3 Objects 20 and 22 and selected with Objects 40 and 41 Setting Groups Application Ideas Setting groups can be used for such applications as Environmental conditions such as winter storms periods of high summer heat etc Hot line tag that disables closing and sensitizes protection Commissioning and operation Act...

Page 1147: ...rts to logical 1 the relay switches from setting Group 3 as the active setting group to another setting group e g setting Group 5 as the active setting group after qualifying time set ting TGR Global settings NOTE The CHSG Relay Word bit does not operate for settings changes initiated by the serial port or front panel methods In this example TGR qualifies the assertion of setting SS5 before it can...

Page 1148: ...disabled If the individual settings change causes a change in one or more SELOGIC control equation settings SS1 through SS6 the active setting group can be changed sub ject to the newly enabled SS1 through SS6 settings Port Settings Table 12 4 Port Settings Categories Settings Reference Protocol Selection See Table 12 5 Communications Settings See Table 12 6 SEL Protocol Settings See Table 12 7 Fa...

Page 1149: ...a Bits 7 8 bits 8 PARITYc Parity Odd Even None N STOPBITe e For PROTO SEL MBA MBB or PMU only Stop Bits 1 2 bits 1 RTSCTSf f For PROTO SEL or PMU only Enable Hardware Handshaking Y N N Table 12 7 SEL Protocol Settings Label Prompt Default Value TIMEOUTa a Hidden for PROTO PMU Port Time Out OFF 1 60 minutes 5 AUTOb b Hidden for PROTO DNP or PMU Send Auto Messages to Port Y N Y FASTOPc c Hidden for ...

Page 1150: ...evices with IEC 61850 Sampled Values SV publication or subscription capability Bus Operating Mode INDEPEND MERGED INDEPEND NETMODE Operating Mode FIXED FAILOVER SWITCHED PRP FAILOVER NETPORT Primary Network Port A B C D b b The specific options available depend on the physical ports installed in the hardware C PRPTOUT PRP Entry Timeout 100 10000 milliseconds 500 PRPINTV PRP Supervision TX Interval...

Page 1151: ...d EMMSFS are hidden when E61850 is set to N Enable IEC 61850 GSE Y N N EMMSFSa Enable MMS File Services Y N N Table 12 14 SV Receiver Configuration Label Prompt Default Value SVRXEN Enable SV Reception Number of streams 0 7 0 SVRADRsa a s represents the subscription number Seven subscriptions are supported Only settings for subscriptions enabled by SVRXEN will be visible SV Stream s Subscribed MAC...

Page 1152: ...s Scaling 0 3 decimal places 1 DECPLM Misc Data Scaling 0 3 decimal places 1 STIMEO Select Operate Time Out 0 0 60 0 seconds 1 0 DRETRY Data Link Retries OFF 1 15 OFF DTIMEO Data Link Time Out 0 0 30 0 seconds 1 MINDLY Minimum Delay from DCD to TX 0 00 1 00 seconds 0 05 MAXDLY Maximum Delay from DCD to TX 0 00 1 00 seconds 0 10 PREDLY Settle Time RTS On to TX OFF 0 00 30 00 seconds 0 00 PSTDLY Set...

Page 1153: ... Port REQ 1025 65534 20000 DNPMAPn DNP Session Map 1 5 1 CLASSBn Class for Binary Event Data OFF 1 3 1 CLASSCn Class for Counter Event Data OFF 1 3 OFF CLASSAn Class for Analog Event Data OFF 1 3 2 TIMERQn Time Set Request Interval I M 1 32767 mins I DECPLAn Currents Scaling 0 3 decimal places 1 DECPLVn Voltages Scaling 0 3 decimal places 1 DECPLMn Misc Data Scaling 0 3 decimal places 1 STIMEOn Se...

Page 1154: ...ed to TPORT and DNPPNUM 4712 PMOUDP1 PMU Output 1 UDP IP Data Port Number 1 65534 b e e Setting hidden when PMOTS1 TCP 4713 PMOTS2 PMU Output 2 Scheme OFF TCP UDP_S UDP_T UDP_U OFF PMODC2 PMU Output 2 Data Configuration 1 5 1 PMOIPA2 PMU Output 2 Client IP Address w x y z f f Setting hidden when PMOTS2 OFF 192 168 1 4 PMOTCP2 PMU Output 2 TCP IP Port Number 1 65534 d f g g Setting hidden when PMOT...

Page 1155: ...e 1 8 messages 1 RMB8DO RMB8 Dropout Time 1 8 messages 1 MBTIME Accept MIRRORED BITS Time Synchronization Y N N MBNUMAN Number of Analog Channels 0 7 0 MBANA1 Selection for Analog Channel 1 analog label a MBANA2 Selection for Analog Channel 2 analog label a MBANA3 Selection for Analog Channel 3 analog label a MBANA4 Selection for Analog Channel 4 analog label a MBANA5 Selection for Analog Channel ...

Page 1156: ...s 5A and 5B or if the ports are used in SWITCHED mode N PTPPRO PTP Profile DEFAULT C37 238 b b Hidden and forced to C37 238 if Port 5A or 5B is used for the process bus 87L or IEC 61850 9 2 Sampled Values DEFAULT PTPTR PTP Transport Mechanism UDP LAYER2 c c Hide if PTPPRO C37 238 UDP DOMNUM PTP Domain Number 0 255 0 PTHDLY PTP Path Delay Mechanism P2P E2E OFF d d If PTPPRO C37 238 E2E is removed f...

Page 1157: ... settings Front Panel Settings Table 12 24 DNP3 Settings Categories Settings Reference DNP3 Fault Location Min and Max Table 12 25 Binary Input Map Table 12 26 Binary Output Map Table 12 26 Counter Map Table 12 26 Analog Input Map Table 12 26 Analog Output Map Table 12 26 Table 12 25 Minimum and Maximum Fault Location Label Prompt Default Value MINDIST Min Fault Location to Capture OFF 1000 0 to 1...

Page 1158: ...tton LED 5 SELOGIC Equation PB5_COL PB5_LED Assert and Deassert Color Enter 2 R G A O PB6_LED Pushbutton LED 6 SELOGIC Equation PB6_COL PB6_LED Assert and Deassert Color Enter 2 R G A O PB7_LED Pushbutton LED 7 SELOGIC Equation PB7_COL PB7_LED Assert and Deassert Color Enter 2 R G A O PB8_LED Pushbutton LED 8 SELOGIC Equation PB8_COL PB8_LED Assert and Deassert Color Enter 2 R G A O PB9_LEDa Pushb...

Page 1159: ...R G A O T9_LED Target LED 9 SELOGIC Equation T9LEDL Target LED 9 Latch Y N T9LEDC T_LED Assert and Deassert Color Enter 2 R G A O T10_LED Target LED 10 SELOGIC Equation T10LEDL Target LED 10 Latch Y N T10LEDC T_LED Assert and Deassert Color Enter 2 R G A O T11_LED Target LED 11 SELOGIC Equation T11LEDL Target LED 11 Latch Y N T11LEDC T_LED Assert and Deassert Color Enter 2 R G A O T12_LED Target L...

Page 1160: ..._LED Assert and Deassert Color Enter 2 R G A O T24_LEDb Target LED 24 SELOGIC Equation T24LEDLb Target LED 24 Latch Y N T24LEDCb T_LED Assert and Deassert Color Enter 2 R G A O a PB9 PB12 settings are only available on 12 pushbutton models b T17 T24 settings are only available on 12 pushbutton models Table 12 29 Selectable Screens for the Front Panel Sheet 1 of 2 Label Prompt Default Value SCROLD ...

Page 1161: ... Points EVE Event Summaries SER SER HMI Display OFF PB2_HMI Pushbutton 2 HMI Screen OFF AP DP EVE SER a b OFF PB3_HMI Pushbutton 3 HMI Screen OFF AP DP EVE SER a b OFF PB4_HMI Pushbutton 4 HMI Screen OFF AP DP EVE SER a b OFF PB5_HMI Pushbutton 5 HMI Screen OFF AP DP EVE SER a b OFF PB6_HMI Pushbutton 6 HMI Screen OFF AP DP EVE SER a b OFF PB7_HMI Pushbutton 7 HMI Screen OFF AP DP EVE SER a b OFF ...

Page 1162: ...ations and are used in most relay reports Assign a valid seven character alias name to any Relay Word bit or any Analog Quantity Some SEL 400 series relays support aliasing additional types of data Invalid alias names include the following keywords used by settings and SELOGIC control equations END INSERT DELETE LIST NA OFF SELOGIC control equation operators e g NOT AND OR COS cannot be used as al...

Page 1163: ...on page 13 5 for more information The default configu ration of the protection SELOGIC control equations is relay specific See the product specific instruction manual to see the defaults Automation Freeform SELOGIC Control Equations Automation freeform SELOGIC control equations are in Blocks 1 through 10 NOTE Some versions of some SEL 400 series relays have only one automation setting block with a...

Page 1164: ... OUTx01 OUTx16 where x 2 5 corresponding to Interface Boards 1 to 4 The category for any interface board is only available if the interface board is installed The defaults are relay specific see the relay specific instruction manual to see the defaults Make Table 12 35 settings if an Ethernet card is present and IEC 61850 is ordered Table 12 34 Output Settings Categories Settings Reference Main Bo...

Page 1165: ... by the settings described in Table 12 40 Any of the analog quantities listed in Section 12 Analog Quantities in the product specific instruction manual may be selected As many as 20 analog quantities can be included in the signal profile Table 12 37 87L Communications Bits Labela b a x 1 4 These settings are hidden when E87CH N or 2E or 3E or 4E Also hidden if there is no serial communications ca...

Page 1166: ...rea of the relay Notes entries are in a single block of 100 lines By default there is no text stored in the Notes set tings Table 12 40 Signal Profile Label Prompt Default Value SPAR Signal Profile Acq Rate 1 5 15 30 60 min 5 SPEN Signal Profile Enable SELOGIC Eqn 0 Table 12 41 Event Reporting Label Prompt Default Value ERDIG Store Selected S or All A Relay Word Bits S SRATE Sample Rate of Event R...

Page 1167: ...station restoration system created in automation programming should not be able to corrupt programming for protection tasks Similarly extended pro tection algorithms must operate at protection speeds unaffected by the volume of automation programming SEL 400 series relays contain several separate programming areas discussed in SELOGIC Control Equation Setting Structure Separate access levels and p...

Page 1168: ... when protection or automation program ming results necessitate activating the output You can use more complicated logic to supervise control of the output with other external and internal informa tion For example use a command from the SCADA master to supervise auto mated control of a motor operated disconnect in the substation SELOGIC Control Equation Setting Structure SEL 400 series relays use ...

Page 1169: ... For all protection settings including protection SELOGIC control equation pro gramming there are six groups of settings that you activate with the protection settings group selection Only one group is active at a time When you switch groups for example you can activate completely different programming that cor responds to the conditions indicated by the active group See Multiple Setting Groups on...

Page 1170: ...artially filled blocks that contain related programming Use automation SELOGIC control equation programming to automate tasks that do not require time critical deterministic execution For example if you are coordinating control inputs from a substation HMI and SCADA master use auto mation freeform SELOGIC control equations and set the output contact setting to the automation SELOGIC control equati...

Page 1171: ...eed the maximum processing requirements the relay measures and calculates the avail able capacity when you enter SELOGIC control equations The relay will not allow you to enter programming that will cause the relay to be unable to complete all protection SELOGIC control equations each protection processing interval There are six protection settings groups Only one protection settings group can be ...

Page 1172: ...rm SELOGIC Control Equations Freeform SELOGIC control equations provide advanced relay customization and automation programming There are freeform SELOGIC control equation pro gramming areas used for protection and automation You can use freeform SELOGIC control equation programming to enter program steps sequentially so that the relay will perform steps in the order that you specify You can refer...

Page 1173: ...ations the relay evalu ates the expression on the right to a result that is a logical 1 or a logical 0 The LVALUE must be some type of Boolean storage location or setting that requires a Boolean value For example the setting for the Protection Conditioning Timer 7 Input PCT07IN requires a value of 0 or 1 which you set with a Boolean SELOGIC control equation The second type is a math SELOGIC contro...

Page 1174: ... Enter the line without the comment character to enable the line later when you want it to be executed Comments are a powerful documentation tool for helping both you and others understand the intent of programming and configuration of the settings You can use comments liberally comments do not reduce SELOGIC control equation exe cution capacity Example 13 3 Boolean and Math SELOGIC Control Equati...

Page 1175: ...ons related to SELOGIC control equation programming in the relay You can use these bits in SELOGIC control equation programming to react to these conditions You can also send these bits to other devices through relay interfaces including MIRRORED BITS communications and DNP3 The special condition bits are shown in Table 13 2 The relay sets the first execution bits AFRTEXA AFRTEXP and PFRTEX moment...

Page 1176: ... Execution Bit Operation on Power Up Name Description AFRTEXA Relay sets on power up and clears after each automation programming block has been executed once AFRTEXP Relay sets on power up Relay clears after it enables protection and all auto mation programming blocks have been executed once PFRTEX Relay sets on startup Relay clears after protection runs for 1 cycle Table 13 3 First Execution Bit...

Page 1177: ...sing the METER command Use the MET PMV command to see all protection math variable results PMV01 PMV64 Similarly use the MET AMV command to see all automation math variable results AMV001 AMV256 Example 13 4 SELOGIC Control Equation Boolean Variables The equations below show freeform SELOGIC control equation program ming examples that use SELOGIC control equation Boolean variables Each line has a ...

Page 1178: ...ne has a comment after the that provides additional description PMV01 378 62 Store 387 62 in PMV01 PMV09 5 VAFM Store sum of 5 and A Phase voltage in kV in PMV09 You can use SELOGIC control equation math variables more than once in freeform programming Use AMV010 in the following SELOGIC control equations to calculate intermediate results Determine if any phase voltage is greater than 13 kV A Phas...

Page 1179: ...lling through the rows of Relay Word bits Protection Latch Bits Program the 32 latch bits PLT01 PLT32 in the protection freeform SELOGIC control equation programming area There is a separate protection freeform SELOGIC control equation programming area associated with each protection set tings group The latches in protection can have separate programming for Set and Reset in each protection settin...

Page 1180: ...AND PLT04 HOT LINE TAG WHEN PLT04 DEASSERTED PLT04 defeats the RECLOSE ENABLED operator control function PLT02R PB2_PUL AND PLT02 OR NOT PLT04 HOT LINE TAG DISABLES RECLOSE In the factory settings for PLT04S and PLT04R rising edge operators are not required because Relay Word bit PB5_PUL only asserts for one processing interval If the application required control input IN103 to set or clear the Ho...

Page 1181: ... for all protection set tings groups The relay evaluates the latch bit value at the end of the automation freeform SELOGIC control equation execution cycle The values for Reset ALTnnR and Set ALTnnS remain unchanged until evaluation of all SELOGIC control equa tions when the relay evaluates the latch ALTnn For example if you have mul tiple SELOGIC control equations for set the last equation in the...

Page 1182: ...mer Output never turns on as illustrated in Figure 13 4 If the input reasserts again one or more processing intervals later the conditioning timer pickup timer begins timing again from zero Table 13 9 Conditioning Timer Quantities Type Typical Quantity Name Range Protection freeform conditioning timers 32 PCT01 PCT32 Table 13 10 Conditioning Timer Parameters Type Item Description Setting Name Exam...

Page 1183: ...f the input reasserts before the dropout time expires the dropout timer resets so it begins timing again from zero when the input drops out again Combining the features shown above Figure 13 6 illustrates conditioning timer operation for use of both the pickup and dropout characteristics The Output PCT03Q turns on after the Input PCT03IN turns on and the Pickup Time PCT03PU expires The Output turn...

Page 1184: ...Example 13 7 Figure 13 6 Conditioning Timer With Pickup and Dropout Timing Diagram Example 13 7 Conditioning Timer Programming and Operation This example uses protection freeform conditioning timer seven PCT07 The freeform settings are as shown here PCT07PU 5 3 Pickup set to 5 3 cycles PCT07D0 6 0 Dropout set to 6 0 cycles PCT07IN IN101 Operate on the first input on the main board PSV29 PCT07Q Pro...

Page 1185: ... conditioning timer You can also view the status of these timer elements through the relay front panel LCD display by selecting RELAY ELEMENTS from the Main Menu and scrolling through the rows of Relay Word bits Sequencing Timers NOTE Times for protection timers must not exceed 2 000 000 cycles for proper operation Sequencing timers are useful for sequencing operation There are two main dif ferenc...

Page 1186: ...o the nearest 0 125 cycles With automation programming the execution interval depends on the amount of automation programming Determine the aver age automation execution interval with the STATUS S command Table 13 12 Sequencing Timer Parameters Type Item Description Setting Name Examples Input Input Value that the relay times Boolean SELOGIC control equation setting PST01IN AST07IN Input Preset Ti...

Page 1187: ...te of the timer by assigning the elapsed time output of the sequencing timer to a math variable Example 13 8 shows how you would assign the elapsed time out put for automation sequence timer AST01 to automation math variable AMV256 To see the elapsed time value issue the MET AMV command to display the val ues of the automation math variables Likewise you can assign the elapsed time output of a pro...

Page 1188: ...ng the protection counter current value PCVnnCV to a protection math variable or by assigning the automation counter current value ACVnnCV to an automation math variable View the math variable values by issuing the appropri ate MET PMV or MET AMV commands The current value count is stored in volatile memory Elapsed time resets to zero for both protection and automation sequential timers when relay...

Page 1189: ...he SELOGIC control equations below provide multiple change detection counting both close and open operations of the circuit breaker The interme diate value PSV01 turns on for one processing interval each time the circuit breaker closes The intermediate value PSV02 turns on for one processing interval each time the circuit breaker opens The OR combination of PSV01 and PSV02 contains a rising edge f...

Page 1190: ...es Relay Word bits incoming control points and SELOGIC control equation elements within the relay The operators are grouped into two types according to the type of SELOGIC control equation in which you can apply these operators Operator Precedence When you combine several operators and operations within a single expression the relay evaluates the operations from left to right starting with the hig...

Page 1191: ...n Use as many as 14 nested sets of parentheses in each SELOGIC control equation The relay calculates the result of the operation on the innermost pair of parentheses first and then uses this result with the remaining operations Table 13 17 is a truth table for an example operation that illustrates how paren theses can affect equation evaluation AND Boolean AND OR Boolean OR Table 13 15 Operator Pr...

Page 1192: ...G is a time based function that creates a pulse when another value changes as shown in Figure 13 9 Use R_TRIG to sense when a value changes from logical 0 to logical 1 and take action only once when the value changes The R_TRIG output is a pulse of one protection processing interval duration typi cally 1 8th cycle This rising edge pulse output asserts one processing interval after the monitored el...

Page 1193: ..._TRIG output is a pulse of one protection processing interval dura tion typically 1 8th cycle This pulse output asserts one processing interval after the monitored element deasserts Figure 13 9 R_TRIG Timing Diagram Example 13 10 R_TRIG Operation The SELOGIC control equation below is invalid PSV15 R_TRIG PSV01 AND PSV23 Invalid statement do not use Use a SELOGIC control equation variable to calcul...

Page 1194: ...ecause the relay uses a floating point format to calculate analog values only integer numbers will match exactly Allow a small hysteresis of the following form PSV01 I01FM 10 002 AND I01FM 9 988 Figure 13 10 F_TRIG Timing Diagram Example 13 11 F_TRIG Operation The SELOGIC control equation below shows an invalid use of the F_TRIG operation ASV015 F_TRIG ASV001 AND ALT11 Invalid statement do not use...

Page 1195: ...Detection If a math operation results in an error the relay turns on the math error bit MATHERR in the Relay Word A settings change or the STATUS SC command resets this bit For example if you attempt to take the square root of a negative number SQRT 5 the math error bit will be asserted until you clear the bit with a STATUS SC command or change settings Table 13 22 Math Operator Summary Operator D...

Page 1196: ...tus bit that signals a math error MATHERR asserts The value that the relay stored previously in the speci fied result location is not replaced The relay clears the corresponding math error bits if you change SELOGIC control equation settings protection or automation or if you issue a STATUS SC command Example 13 13 contains examples of arithmetic operations in use Table 13 23 Math Error Examples E...

Page 1197: ...of expressions that use the LN EXP and LOG operators Use parenthe ses to delimit the argument of a LN EXP or LOG operation The lines below demonstrate math calculation error detection The line below results in a math error if AMV029 becomes 0 AMV006 732 AMV029 In the second line if AMV029 is 6 on the first pass through the automation programming the relay stores the result 122 in AMV006 If on the ...

Page 1198: ...esults in a math error and assertion of the corresponding math bit described in Arithmetic on page 13 30 Example 13 17 shows examples of ASIN and ACOS Use parentheses to delimit the argument of an ASIN or ACOS operation EXP examples AMV004 EXP 2 Calculates e squared AMV005 EXP AMV003 Calculates e to the power AMV003 AMV006 EXP AMV046 AMV047 e raised to the power of the sum LOG examples AMV007 LOG ...

Page 1199: ...CEIL operator Example 13 17 Using the ASIN and ACOS Operators The freeform math SELOGIC control equations below are examples of ASIN and ACOS ASIN examples AMV001 ASIN AMV010 Arc sine of AMV010 AMV002 ASIN AMV010 AMV011 Arc sine of the sum AMV003 ASIN AMV012 Produces an error if AMV012 1 ACOS examples AMV004 ACOS AMV010 Arc cosine of AMV010 AMV005 ACOS AMV010 AMV011 Arc cosine of the sum AMV006 AC...

Page 1200: ...erform a new automation task or cus tomize protection operation take time to design document and implement your project Scale the planning effort to match the overall size of the project but spend sufficient time planning to do the following Document the inputs and outputs of your programming This may include protection elements physical inputs and outputs metering quantities user inputs and other...

Page 1201: ...aded to the relay Comments add structure to freeform programming environments such as Visual Basic C and freeform SELOGIC control equations Example 13 22 shows how to use comments to divide and structure freeform SELOGIC control equation pro gramming Example 13 22 Comments in Freeform SELOGIC Control Equation Programming Use comments to divide and direct your eye through freeform programming This ...

Page 1202: ...eration and testing for abnormal conditions will help you avoid a failure and may reveal deficiencies in the normal operation of your system Alternatively you can sub stitute a remote bit or local bit that you can manually control to help exercise your logic Modify your SELOGIC control equations to simulate the process While you may be unable to change the state of a discrete input easily such as ...

Page 1203: ...etting Table 13 24 SEL 351 Series Relays and SEL 400 Series SELOGIC Control Equation Programming Equivalent Functions Feature SEL 351 Series SEL 400 Series Protection Freeform Style SELOGIC control equation variables SV1 SV16 PSV01 PSV64 Timer Input SV1 SV16 PCT01 PCT32 Timer Pickup settings SV1PU SV16PU PCT01PU PCT32PU Timer Dropout settings SV1DO SV16DO PCT01DO PCT32DO Timer Outputs SV1T SV16T P...

Page 1204: ...e protection group set tings example use the input of a timer as shown in Table 13 21 Example 13 24 Converting SEL 351 Series Relay SELOGIC Control Equation Timers If you have the following SELOGIC control equation timer in an SEL 351 series relay convert it as shown below In an SEL 400 series relay use the format shown below Freeform programming conversion of timer PCT01PU 5 25 Pickup of 5 25 cyc...

Page 1205: ...Series Users In an SEL 400 series relay use the format shown below Protection freeform style settings Freeform programming conversion of latch bit PLT01S RB04 Set if RB04 PLT01R RB05 Reset if RB05 In the output settings set OUT101 as shown below OUT101 PLT01 Example 13 25 Converting SEL 351 Series Relay Latch Bits Continued ...

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Page 1207: ...ted with the commands for more information on the relay function corresponding to the command or examples of the relay response to the command You can simplify the task of entering commands by shortening any ASCII com mand to the first three characters for example ACCESS becomes ACC Always send a carriage return CR character or a carriage return character followed by a line feed character CR LF to...

Page 1208: ...ay is disabled and you attempt an 89CLOSE n command the relay responds with Command aborted because the relay is disabled If the cir cuit breaker control enable jumper J18C BREAKER is not in place the relay aborts the command and responds Aborted the breaker jumper is not installed When the 89CLOSE n command is issued and the circuit breaker control enable jumper is in place the relay responds CLO...

Page 1209: ...per is in place the relay responds with Open DISNAMn Y N If you answer Y Enter the relay responds Are you sure Y N If you answer Y Enter the command is executed If the response to either prompt is not y or Y the relay responds with Command Aborted AACCESS Use the AAC command to gain access to Access Level A automation See Access Levels and Passwords on page 3 7 for more information ACCESS Use the ...

Page 1210: ...t that includes interrupted currents number of operations and mechanical and electri cal operating times among many parameters The relay displays a listing of breaker monitor alarms with the breaker report BRE n C and BRE n R The BRE n C and BRE n R commands clear reset the circuit breaker monitor data Options C and R are identical BRE C A and BRE R A The BRE C A and BRE R A commands clear all cir...

Page 1211: ...ion instructs an external computer on the method for extracting data from other Compressed ASCII commands See SEL Compressed ASCII Commands on page 15 24 for an example of the CAS command configuration message and for further information on the Compressed ASCII command set Table 14 10 BRE C A and BRE R A Commands Command Description Access Level BRE C A Clear all circuit breaker data B P A O 2 BRE...

Page 1212: ...ormation on the Compressed ASCII command set CEV Use the CEV command to gather relay event reports When parameter n is 1 9999 n indicates the order of the event report The most recent event report is 1 the next most recent report is 2 and so on When parameter n is 10000 42767 n indicates the absolute serial number of the event report Table 14 15 CBR Command Command Description Access Level CBR Ret...

Page 1213: ...na a Parameter n indicates event order or serial number Return particular n event report including settings and sum mary at full length with 4 samples cycle data in Com pressed ASCII format 1 B P A O 2 Table 14 18 CEV ACK Command Command Description Access Level CEV ACK Acknowledge the oldest unacknowledged event at the present communications port 1 B P A O 2 Table 14 19 CEV C Command Command Desc...

Page 1214: ...Access Level CEV Lyyy Return yyy cycles of the most recent event report includ ing settings with 4 samples cycle data in Compressed ASCII format 1 B P A O 2 CEV na Lyyy a Parameter n indicates event order or serial number see CEV on page 14 6 Return yyy cycles of a particular n event report with 4 samples cycle data in Compressed ASCII format 1 B P A O 2 Table 14 22 CEV N Command Command Descripti...

Page 1215: ... P A O 2 CEV na NSUM a Parameter n indicates event order or serial number see CEV on page 14 6 Return a particular n event report without the event sum mary at full length with 4 samples cycle data in Com pressed ASCII format 1 B P A O 2 Table 14 25 CEV Sx Command Command Description Access Level CEV Sx Return the most recent event report at full length with x samples cycle data in Compressed ASCI...

Page 1216: ...elay assumes all CT inputs are 5 A nominal This is necessary so the relay scales the information correctly See Section 2 Installation of the product specific instruction manual for more information on using this command as part of configuring the relay This will restart the relay and force all settings to default so this command must be made before making any other settings in the relay Table 14 2...

Page 1217: ...eaker jumper on jumper BREAKER must be in place Further you must enable breaker control for any breakers you want to control Table 14 29 CFG NFREQ Command Command Description Access Level CFG NFREQ f Change nominal frequency to f 50 or 60 2 Table 14 30 CHI Command Command Description Access Level CHI Return the data as contained in the History report short form descriptions for the most recent 100...

Page 1218: ...relay responds with Breaker n is not available COMMUNICATIONS The COMMUNICATIONS command displays communications statistics for the MIRRORED BITS communications channels and for synchrophasor client channels Some relays support additional options to the COM command besides those described here COM c Use the COM c command to view records of the MIRRORED BITS communica tions buffers for specific rel...

Page 1219: ...lear reset communications buffer data for either MIRRORED BITS communications Channel A or Channel B when only one channel is enabled P A O 2 Table 14 35 COM c L Command Command Description Access Level COM A L Display all available records from MIRRORED BITS com munications Channel A the most recent record is Row 1 at the top of the report and the oldest record is at the bottom of the report 1 B ...

Page 1220: ...tion Access Level COM PTP Display PTP data sets and offset statistics 2 COM PTP C Clears PTP offset statistics 2 COM PTP Enter Relay 1 Date 02 24 2016 Time 15 08 43 516 Station A Serial Number 0000000000 PTP offset statistics previously cleared on 02 24 2016 14 08 36 303 UTC Settings Data Set PTP Profile Default Transport Mechanism Layer2 Path Delay P2P Default Data Set Two Step true Clock Identit...

Page 1221: ...Clock Identity 00 30 A7 FF FE 44 55 66 Port Number 1 Port State SLAVE Log Pdelay Request Interval 0 Peer Mean Path Delay 0 ns Announce Receipt Timeout 2 intervals Path Delay Mechanism Peer to Peer Failed to Receive Response true Received Multiple Pdelay Responses false Reason for Non synchronization Time Offset Statistics Mean 0 013393 ns Standard Deviation 5 291062 ns Latest Time Offsets with res...

Page 1222: ... relay checks only the first character you can type Set and Clear When you issue a valid CON command the relay per forms the control action immediately and displays Remote Bit Operated Table 14 37 COM RTC Command Commanda a Parameter c is A B or absent for Channel A Channel B or all enabled channels respectively Description Access Level COM RTC Return a report describing the communications on all ...

Page 1223: ... When you enter the COPY command with valid parameters the relay responds with Are you sure Y N Answer Y Enter for yes to complete copying If the destination instance is the active group the relay changes to the new set tings and pulses the SALARM Relay Word bit CPR Use the CPR command to access the Signal Profile data for as many as 20 user selectable analog values in Compressed ASCII format Noti...

Page 1224: ...cess Level Table 14 42 CSE Command Command Description Access Level CSE Return all records from the SER in Compressed ASCII format with the most recent lowest number at the beginning of the list and the oldest highest number at the end of the list 1 B P A O 2 CSE ka a Parameter k indicates a specific number of SER records Return the k most recent records from the SER in Com pressed ASCII format wi...

Page 1225: ...2 CSE m n TERSEb b Parameters m and n indicate an SER record number Return the SER records in Compressed ASCII for mat from m to n without the label lines in Com pressed ASCII format If m is greater than n then records appear with the oldest highest number at the beginning of the list and the most recent lowest number at the end of the list If m is less than n then records appear with the most rec...

Page 1226: ...sed ASCII format CSU NEXT Use the CSU NEXT command to view the oldest unacknowledged event sum mary in Compressed ASCII format Table 14 45 CSU Command Command Description Access Level CSU Return the most recent event summary with label lines in Compressed ASCII format 1 B P A O 2 CSU na a Parameter n indicates event order or serial number Return a particular n event summary with label lines in Com...

Page 1227: ...day portion of the date If the IRIG B time source is IEEE C37 118 compliant and Global setting IRIGC C37 118 or if an Simple Network Time Protocol SNTP time source is connected the DAT command cannot alter any time setting DNAME X The DNA X command produces the ASCII names of all relay digital I O input output quantities reported in a Fast Meter message in Compressed ASCII format Table 14 49 CSU T...

Page 1228: ...ailable to display similar statistics for ports that exclusively carry other types of traffic for example COM 87L for 87L traffic ETH Use the ETH command when troubleshooting Ethernet connections Figure 14 2 shows a sample ETH command response for a relay with four cop per Ethernet ports and Port 5 setting NETMODE SWITCHED Different Ethernet configurations and different NETMODE settings result in ...

Page 1229: ...erial number of the event report ETH Enter Relay 1 Date 11 04 2010 Time 10 22 19 984 Station A Serial Number 0000000000 MAC 1 00 30 A7 01 E3 0A MAC 2 00 30 A7 01 E3 0B IP ADDRESS 10 201 5 27 16 DEFAULT GATEWAY 10 201 0 1 NETMODE SWITCHED PRIMARY 87L PORT 5A ACTIVE 87L PORT 5A LINK SPEED DUPLEX MEDIA PORT 5A Down TX PORT 5B Down TX PORT 5C Up 100M Full TX PORT 5D Down TX PACKETS BYTES ERRORS SENT R...

Page 1230: ...analog information for the most recent event report with 4 samples cycle data 1 B P A O 2 EVE A na a Parameter n indicates event order or serial number see EVE on page 14 23 Return only the analog information for a particular n event report with 4 samples cycle data 1 B P A O 2 Table 14 57 EVE ACK Command Command Description Access Level EVE ACK Acknowledge the oldest unacknowledged event at the p...

Page 1231: ...ngth with large resolution data 1 B P A O 2 EVE na L a Parameter n indicates event order or serial number Return a particular n event report at full length with large resolution data 1 B P A O 2 Table 14 61 EVE Lyyy Command Commanda a Parameter n indicates event order or serial number see EVE on page 14 23 Description Access Level EVE Lyyy Return yyy cycles of the most recent event report includin...

Page 1232: ...ombine options on each row selecting one option from each column to create an EVE command Table 14 64 EVE NSUM Command Command Description Access Level EVE NSUM Return the most recent event report without the event sum mary at full length with 4 samples cycle data 1 B P A O 2 EVE na NSUM a Parameter n indicates event order or serial number Return a particular n event report without the event sum m...

Page 1233: ...es Example Description EVE L010 S8 Return 10 cycles of an 8 samples cycle event report for the most recent event EVE L10 A Return 10 cycles of the analog portion only of the most recent event report at 4 samples cycle resolution EVE 2 C NSUM For the second most recent event return the event with 8 samples cycle data and omit the event summary Table 14 68 EXIT Command Command Description Access Lev...

Page 1234: ...ical Node Class and cbName GSE Control Block Name e g SEL_411L_1CFG LLN0 DSet13 Multicast Address MultiCastAddr This hexadecimal field represents the GOOSE multicast address Priority Tag Ptag This three bit decimal field represents the priority tag value where spaces are used if the priority tag is unknown VLAN Vlan This 12 bit decimal field represents the virtual LAN Local Area Net work setting w...

Page 1235: ...ance LN0 lnClass Logical Node Class and datSet Data Set Name e g SEL_411L_1CFG LLN0 DSet13 GOOSE Enter GOOSE Transmit Status MultiCastAddr Ptag Vlan StNum SqNum TTL Code SEL_411L_OtterCFG LLN0 GO GooseDSet13 01 0C CD 01 00 10 4 1 1 166 457 Data Set SEL_411L_OtterCFG LLN0 DSet13 GOOSE Receive Status MultiCastAddr Ptag Vlan StNum SqNum TTL Code SEL_411L_1CFG LLN0 GO GooseDSet13 01 0C CD 01 00 04 0 0...

Page 1236: ... GOOSE_SIM_CFG LLN0 GO GooseDSet02 AppID 4114 From 06 30 2014 10 59 29 760 To 06 30 2014 11 10 32 817 Accumulated downtime duration 0000 10 59 325 Maximum downtime duration 0000 10 59 325 Date time maximum downtime began 06 30 2014 10 59 33 492 Number of messages received out of sequence OOS 0 Number of time to live TTL violations detected 1 Number of messages incorrectly encoded or corrupted 654 ...

Page 1237: ...re 1 07 01 2014 11 37 02 051 0000 00 01 000 OUT OF SEQUENCE 2 07 01 2014 11 36 59 051 0000 00 03 000 CONF REV MISMATCH 3 07 01 2014 11 36 38 050 0000 00 00 999 OUT OF SEQUENCE 4 07 01 2014 11 36 29 049 0000 00 09 000 NEEDS COMMISSIONING 5 07 01 2014 11 36 09 049 0000 00 00 999 OUT OF SEQUENCE 6 07 01 2014 11 36 03 049 0000 00 06 000 CONF REV MISMATCH 7 07 01 2014 11 35 48 048 0000 00 00 999 OUT OF...

Page 1238: ...ical The relay prompts you with Are you sure Y N when you issue the HIS C and HIS R commands If you answer Y Enter the relay clears the present port history data Table 14 74 HELP Command Command Description Access Level HELP Display a list of each command available at the present access level with a one line description 1 B P A O 2 HELP command Display information on the command command 1 B P A O ...

Page 1239: ...tored in the relay settings of the IED DEVCODE a unique Device Code for Modbus identification purposes PARTNO the Part Number SERIALNO the serial number of the relay CONFIG abcdef The designator positions indicate a specific relay configuration a represents the nominal frequency where 0 N A 1 60 Hz and 2 50 Hz b represents the phase rotation where 0 N A 1 ABC and 2 ACB c represents the phase input...

Page 1240: ...firmation time delay There is no longer a 30 second confirmation time delay the relay uses the IRIG time source as soon as it determines that the signal is valid a process that may take several seconds Once the IRIG signal is verified the relay clock is updated once per second The IRIG command is still available but is no longer neces sary To check IRIG status use the TIME Q command instead see TI...

Page 1241: ...tus of the RMB Receive MIRRORED BITS and Are you sure Y N If you answer Y Enter the relay responds with Loopback Mode Started In the loopback mode ROK drops out and the relay uses LBOK to indicate whether the data transmissions are satisfactory The relay collects COM data as usual Time synchronization and virtual terminal modes are not available during loopback The relay continues passing analog q...

Page 1242: ...ATA Command Command Description Access Level LOOP DATA Begin loopback of a single MIRRORED BITS communica tions channel either Channel A or Channel B for 5 min utes pass input data to receive data as in nonloopback mode P A O 2 LOOP c DATA Begin loopback of MIRRORED BITS communications Channel c only for 5 minutes pass input data to receive data as in nonloopback mode P A O 2 LOOP c DATA t Begin l...

Page 1243: ...abels the relay lists these bit labels in MSB most significant bit to LSB least significant bit order The TARGET region is usually the only region containing bit labels METER The METER command displays reports about quantities the relay measures in the power system voltages currents frequency remote analogs and so on and internal relay operating quantities math variables and synchronism check valu...

Page 1244: ...r channel and some support two If you have not enabled the Station DC Battery Monitor the relay responds with DC Monitor Is Not Enabled Enable the dc monitor with the Global setting EDCMON The reset command MET RBM resets the dc monitor maximum minimum metering quantities When you issue the MET RBM command the relay responds with Reset Max Min Battery Metering Y N If you answer Y Enter the relay r...

Page 1245: ...e MET PM command to view the time synchronized quantities The relay must be in the high accuracy timekeeping HIRIG or HPTP mode For more infor mation on high accuracy timekeeping see Section 11 Time and Date Manage ment NOTE Not all SEL 400 series relays support synchrophasors Table 14 89 MET D Command Command Description Access Level MET D Display demand metering data 1 B P A O 2 MET D k Display ...

Page 1246: ...ime command while the first com mand is still pending will cancel the first command request in favor of the newer request If you are not connected to the relay when the MET PM time command issues its timed response you can use the MET PM HIS command to view this response This permits you to issue MET PM time to multiple relays using a common time and then go back later to see the results from all ...

Page 1247: ... Failure If the RTDFL Relay Word bit is set to indicate a SEL 2600A failure the relay displays the following SEL 2600 Failure If any of the RTDxTY Port Settings are set to NA the relay displays the follow ing for that channel Channel Not Used If the RTDxxST Relay Word bit is set for any of the RTDNUM channels being reported the relay displays the following Channel Failure OACCESS Use the OACCESS c...

Page 1248: ...iary contact 52A inputs for this circuit breaker the relay waits 0 5 seconds checks the state of the breaker auxiliary contacts and responds Breaker OPEN or Breaker CLOSED as appropriate If Breaker n is not enabled the relay responds Breaker n is not available PACCESS Use the PACCESS command to gain access to Access Level P protection See Access Levels and Passwords on page 3 7 for more informatio...

Page 1249: ...the PING command to determine whether the network is connected properly and other network devices are reachable When the IP address parameter is not of a valid format the relay responds with Invalid IP address After a valid PING command is issued the relay sends out an ICMP echo request messages at one second intervals until receiving a carriage return CR or five minutes elapses A sample PING comm...

Page 1250: ...ve the relay responds Transparent session already in use If you issue the PORT p command to ports 1 2 3 or F or BAY1 or BAY2 87L ports and you have not properly configured the MIRRORED BITS communica tions port the MBNUMVT is not set to 1 or larger Invalid destination port PORT KILL n It is possible to forcefully disconnect a transparent session from another port a port not involved in the present...

Page 1251: ...isplays all the rows that were recorded on that date with the oldest row at the top and the latest row at the bottom 1 B P A O 2 PRO date1 date2 Displays all the rows that were recorded on and between including date1 and date2 date1 chronolog ically precedes date2 with the oldest row date1 at the top and the latest row date2 at the bottom 1 B P A O 2 PRO date2 date1 Displays all the rows that were...

Page 1252: ...to descend to this level or remain at this level In a Telnet session QUIT terminates the connection RTC Use the RTC command to display a description of all data being received on syn chrophasor client channels This report will list the analog quantity and Relay Word bits the data gets stored in locally matched up with a label provided by the sending PMU Use this information as aid to understanding...

Page 1253: ...lowest number at the bottom of the list 1 B P A O 2 SER k Return the k most recent records from the SER with the oldest highest number at the top of the list and the most recent lowest number at the bottom of the list 1 B P A O 2 SER m na a Parameters m and n indicate an SER number which the relay assigns at each SER trigger Return the SER records from m to n If m is greater than n records appear ...

Page 1254: ...s Report setting ESERDEL the relay responds Auto matic removal of chattering SER elements not enabled SET Use the SET command to change relay settings The relay settings structure is ordered and contains these items in structure order classes instances catego ries and settings An outline of the relay settings structure is as follows Classes Global Group Breaker Monitor Protection Automation Output...

Page 1255: ... review the readback information to confirm that you have entered the settings that you intended Table 14 112 SET Command Overview Commanda a Parameter n 1 6 representing Group 1 6 c settings class relay specific i class instance choices depends on the class Description Access Level SET Set the Group relay settings beginning at the first setting in the active group P 2 SET n Set the Group n relay ...

Page 1256: ...ing that you specified SNS In response to the SNS command the relay sends the names of the SER ele ments This is a comma delimited string used to support the SEL Fast SER report STATUS The STATUS command reports relay status information that the relay derives from internal diagnostic routines and self tests See Relay Self Tests on page 10 15 for information on relay diagnostics Table 14 114 SHO Co...

Page 1257: ...hort form status report items plus data on A D analog digital channel offsets power supply voltages temperature communications interfaces and time source synchronization STA C and STA R The STA C and STA R commands reboot the relay Thus these commands clear a transient failure should this unlikely event occur Options C and R are identical Contact your Technical Service Center or the SEL Factory be...

Page 1258: ...dge an event summary that you recently viewed with the SUM NEXT command on the present communications port Acknowledge the oldest summary specify no event number If you attempt to acknowledge an event summary that you have not viewed on the present port with the SUM NEXT command the relay responds Event summary number n has not been viewed with the NEXT option Table 14 120 STA SC and STA SR Comman...

Page 1259: ... the terminal screen in groups of eight with the target row elements listed above each grouping TAR ALL Use the TAR ALL command to display all of the relay targets Table 14 123 SUM N Command Command Description Access Level SUM N View the oldest unacknowledged event summary at the present communications port 1 B P A O 2 Table 14 124 TAR Command Command Description Access Level TAR Display target R...

Page 1260: ...e you sure Y N If the prompt is acknowledged the relay sets analog quantity TECORR n and asserts Relay Word bit PLDTE for approximately 1 5 cycles The relay then displays the new TECORR value along with the remaining TEC command data The TECORR value does not affect the TE time error estimate until the LOADTE SELOGIC equation asserts Table 14 126 TAR R Command Command Description Access Level TAR ...

Page 1261: ...tabase accessed through the Fast Mes sage Data Access operations The database address addr can be any legitimate decimal or hexadecimal address A hexadecimal address is a numeral with an h suffix or a 0x prefix You can enter the override value value1 as an integer a floating point number which overrides two registers a character which must be in single quotes or a string which must be in double qu...

Page 1262: ... or logical 1 for digital and status ele ments The analog value2 can be an integer or a floating point number The Relay Word bit TESTDB2 will be asserted while there are points in this test mode Table 14 130 TEST DB OFF Command Command Description Access Level TEST DB OFF Clear all override testing values from all virtual devices B P A O 2 TEST DB OFF 1 Clear all override testing values from Virtu...

Page 1263: ...relay shows the item label and override values To force a value use the TEST FM label value1 value2 command The item label label is any analog channel label in the Fast Meter configuration if avail able any digital element label from the DNA command and any status ele ment label from the BNA command except the TEST and FMTEST items Table 14 132 TEST DB2 OFF Command Command Description Access Level...

Page 1264: ...hese relays will not support the TEST FM DEM command TEST FM OFF Use the TEST FM OFF command to remove override values The relay returns the Fast Meter registers to the pretest values When you have successfully removed a Fast Meter test value for example TEST FM IA1 OFF the relay responds Override Removed When an attempt to remove an FM test value fails the relay responds Override Not Found When r...

Page 1265: ...lue mm is for minutes from 0 59 and the value ss is for seconds from 0 59 If you enter a valid time the relay updates and saves the time in the nonvolatile clock and displays the time you just entered If you enter an invalid time the relay responds Invalid Time TIME Q The TIME Q command returns detailed information on the relay internal clock Use this command to query the status of high accuracy t...

Page 1266: ...68 Station A Serial Number 0000000000 Time Source HPTP Last Update Source HPTP Grandmaster Clock Quality Clock Class Synchronized with PTP timescale 6 Time Traceable TRUE Clock Accuracy Within 25 ns Offset Log Variance 0 Time Mark Period 1000 000061 ms Internal Clock Period 19 999935 ns Figure 14 10 Sample Time Q Command Response With PTP TIME DST Enter local 11 28 19 UTC 18 28 19 UTC Offset 07 0 ...

Page 1267: ...the exception and diagnostics records in the relay VERSION The VERSION command displays the relay hardware and software configuration Use the VER command to list the part numbers serial numbers checksums soft ware release numbers and other important relay configuration information When you issue the VER command the relay displays the latest release numbers for various items typically including FID...

Page 1268: ... relay database regions and data types Typical relay regions are LOCAL METER DEMAND TARGET HISTORY BREAKER STATUS and ANALOGS view this list with the MAP 1 command The relay is Virtual Device 1 all commands begin with VIEW 1 In all database views if a data item is in test mode controlled by TEST DB command the relay displays an asterisk mark following the data value VER Enter FID SEL 411L R101 V0 ...

Page 1269: ...ion Command Description Access Level VIEW 1 region Display the data in the relay database in the region region 1 B P A O 2 VIEW 1 region BL Display the data in the region region and include bit labels 1 B P A O 2 Table 14 144 VIEW 1 Commands Register Item Command Description Access Level VIEW 1 addr Display the data in the relay database at register address addr 1 B P A O 2 VIEW 1 addr NR ma a Par...

Page 1270: ...it in the relay database The relay searches the entire relay database struc ture for the bit label you specified this process takes more time and processing than narrowing the search by using the VIEW 1 region command and the VIEW 1 addr command with the bit label option bit_label Table 14 145 VIEW 1 Commands Bita a Parameter bit is a number from 0 15 with 0 as the LSB least significant bit Comman...

Page 1271: ...se to collect data from the relay set the relay and perform relay test and diagnostic functions The relay has three rear panel serial ports and one front panel serial port These serial ports conform to the EIA 232 standard often called RS 232 Several optional SEL devices are available to provide alternative physical interfaces including EIA 485 and fiber optic cable The relay also has a Ethernet c...

Page 1272: ...tions EIA 232a SEL MIRRORED BITS Communi cation on page 15 31 Phasor Measurement Proto cols C37 118 and SEL Fast Message EIA 232a Ethernetb Section 18 Synchrophasors PTP Ethernet Precision Time Protocol PTP on page 15 15 SEL Binary Protocols Fast Meter Fast Operate Fast SER EIA 232a or Telnet using Ethernet SEL Fast Meter Fast Operate Fast SER Messages and Fast Message Data Access on page 15 28 SE...

Page 1273: ... Name Description Comments 1 5 Vdc Modem power Jumper selectable on PORT 1 PORT 3 No connection on PORT F 2 RXD Receive data 3 TXD Transmit data 4 IRIG B Time code signal positive PORT 1 only No connection on PORT F PORT 2 and PORT 3 5 GND Signal ground Also connected to chassis ground 6 IRIG B Time code signal negative PORT 1 only No connection on PORT F PORT 2 and PORT 3 7 RTS Request to send 8 ...

Page 1274: ... to connect devices We strongly recommend that you use fiber optic cables to connect devices within a substation Power equipment and control circuit switching can cause substantial interference with communications circuits You can also experi ence significant ground potential differences during fault conditions that can interfere with communications and damage equipment Fiber optic cables pro vide...

Page 1275: ...e supports hardware handshaking or if you must always assert RTS RTSCTS N for proper operation Data Frame The relay ports use asynchronous data frames to represent each character of data Four port settings influence the framing SPEED DATABIT PARITY and STOPBIT The time allocated for one bit is the reciprocal of the SPEED For example at 9600 bits per second one bit time is 0 104 milliseconds ms The...

Page 1276: ...erfaces The Ethernet card includes redundant physical interfaces with the capability to automatically transfer communications to the backup interface in the event that the primary network fails For information on substation integration architectures see Section 16 DNP3 Communication and Section 17 IEC 61850 Communication Once installed in a relay the settings needed for network operation and data ...

Page 1277: ...aining bits with zeros in our example it is 192 168 1 0 The broadcast address is derived similarly but the remaining bits are filled with ones 192 168 1 255 for the example above Neither the network base address nor the broadcast address can be used for any host or router addresses on the network Table 15 4 Ethernet Card Network Configuration Settings Label Description Range Default EPORT Enable E...

Page 1278: ...ine the network and node and how these settings affect the DEFRTR setting If there is no router on the network enter a null string Table 15 5 CIDR Notation CIDR Value Subnet Mask 32 255 255 255 255 31 255 255 255 254 30 255 255 255 252 29 255 255 255 248 28 255 255 255 240 27 255 255 255 224 26 255 255 255 192 25 255 255 255 128 24 255 255 255 000 23 255 255 254 000 22 255 255 252 000 21 255 255 2...

Page 1279: ...nt When the timer runs out the relay disconnects the MMS session making it available for other MMS clients This feature was implemented in addition to the TCP keep alive timer to specifi cally handle MMS clients that do not disconnect properly As there are a limited number of MMS sessions available this ensures that misbehaving MMS clients do not take up multiple MMS sessions Note that the MMS ina...

Page 1280: ...e 15 5 On startup the relay communicates using the primary network interface selected by the NETPORT setting If the relay detects a link failure on the primary inter face it asserts the LNKFAIL Relay Word bit If the link status on the standby interface is healthy the relay activates the standby network interface after time FTIME If the link status on the primary interface returns to normal before ...

Page 1281: ... the other Redundant Ethernet Network Using SWITCHED Mode Make Port 5 setting NETMODE SWITCHED to activate the internal Ethernet switch The internal switch connects a single Ethernet stack inside the relay to two external Ethernet ports The combination of relay and internal switch operate the same as if a single Ethernet port on a relay were connected to an external unmanaged Ethernet switch Use t...

Page 1282: ... transfer requests via TCP IP protocols Access data using either the standard TCP IP Telnet and FTP interfaces or optionally through the Web HTTP Server DNP3 LAN WAN or IEC 61850 interface You cannot access all data through all interfaces See the appropriate interface section below for details on data access FTP FTP is a standard application level protocol for exchanging files between com puters o...

Page 1283: ...elay user interface When you connect with Telnet and log into the relay you can use all of the ASCII and Compressed ASCII commands described in Section 14 ASCII Command Reference to configure and interact with the relay You can also use the SEL binary Fast Meter and Fast Operate commands described in SEL Fast Meter Fast Operate Fast SER Messages and Fast Mes sage Data Access on page 15 28 Use a Te...

Page 1284: ... associated with each SNTP operation mode UNICAST MANYCAST and BROADCAST Table 15 9 Settings Associated With SNTP Setting Prompt Range Default Description ESNTP SNTP Enable OFF UNICAST MANYCAST BROADCAST UNICAST MANYCAST BROADCAST OFF Selects the mode of operation of SNTP See descriptions in SNTP Operation Modes on page 15 14 SNTPRATa SNTP Request Update Rate 15 3600 s 15 3600 s 60 Determines the ...

Page 1285: ...e to any broadcasting NTP server If setting SNTPPIP is set to a specific IP address while setting ESNTP BROADCAST then the relay will listen for and synchronize to only NTP server broadcasts from that address When synchronized the relay asserts Relay Word bit TSNTPP Relay Word bit TNSTPP deasserts if the relay does not receive a valid broadcast within the SNTPT0 setting value after the period defi...

Page 1286: ...evices The Default profile supports both UDP or layer 2 802 3 Ethernet transport and can use either end to end E2E or peer to peer P2P Delay Mechanism Grandmas ter clocks can send Announce Sync and Delay request messages over a wide range of intervals A Default profile network can consist of boundary clocks or transparent clocks anywhere between the grandmaster and the end devices The only perform...

Page 1287: ... master grandmaster or boundary clocks to which the relay may synchronize The relay will not syn chronize to any master clock that is not in the list It is recommended to use this feature for additional security The AMNUM setting selects the number of master clocks you will list in this table The default value is OFF which means the relay will synchronize to any master clock on the network If AMNU...

Page 1288: ...ded by the open and close bracket characters followed by a carriage return and line feed Only one keyword is allowed per line in the file For example the keyword INFO would look like this in the file INFO CR LF Records are defined as comma delimited text followed by a carriage return and line feed One line in a text file equals one record Fields are defined as comma delimited text strings Comma De...

Page 1289: ...ile is supplementary to the CFG TXT file The CFG XML file describes the IED configuration any options such as the Ethernet port and includes firmware iden tification settings class names and configuration file information SWCFG ZIP File Read Write The SWCFG ZIP file is a compressed file used to store external support software settings It is readable at Access Level 1 and above and writable at Acce...

Page 1290: ...settings are changed ERR TXT Read Only The ERR TXT file contents are based on the most recent SET_cn TXT or SET_61850 CID file written to the relay If there were no errors the file is empty If errors occurred the relay logs these errors in the ERR TXT file SET_61850 CID Present if ordered with the IEC 61850 protocol option the SET_61850 CID file contains the IEC 61850 configured IED description in...

Page 1291: ...ponses Event file names start with the prefix E4_ E8_ E12 C4_ C8_ C12 or HR_ followed by a unique event serial number For example if one event is triggered with serial number of 10001 the EVENTS directory contains the files shown in Table 15 14 Event oscillography in COMTRADE format consists of three files CFG DAT and HDR that conform to the COMTRADE standard S SET_Sn TXT Group n n in range 1 6 1 ...

Page 1292: ... a In the SEL 487B this is replaced with C1210001 TXT which provides a 12 samples cycle Compressed ASCII event report b In the SEL 487B this is replaced with E1210001 TXT which provides a 12 samples cycle event report Table 15 14 EVENTS Directory Files for Event 10001 Sheet 2 of 2 File Usage Table 15 15 SYNCHROPHASORS Directory File Sample File Description 080528 160910 0 ONA 1 ABC PMU 080528 date...

Page 1293: ...ginally designed the SEL ASCII commands for communication between the relay and a human operator via a keyboard and monitor or a printing terminal A computer with a serial port can also use the SEL ASCII protocol to communi cate with the relay collect data and issue commands The ASCII character set specifies numeric codes that represent printing charac ters and control characters The complete ASCI...

Page 1294: ...aracter ETX Each line of the message ends with a carriage return CR and line feed LF Send the CAN character to the relay to abort a transmission in progress For example if you request a long report and want to terminate transmission of this report depress the Ctrl and X keys Ctrl X to terminate the report SEL Compressed ASCII Commands The relay supports a subset of SEL ASCII commands identified as...

Page 1295: ...e sentation of the two byte binary checksum The checksum value is the sum of the first byte on a line first byte following STX CR or CR LF through the comma preceding the checksum If you request data with a Compressed ASCII command and these data are not available in the case of an empty history buffer or invalid event request the relay responds with the following Compressed ASCII format message S...

Page 1296: ... is the number of Compressed ASCII command descriptions to follow COMMAND is the ASCII name for the Compressed ASCII command that the requesting device terminal or external software sends The naming convention for the Compressed ASCII commands is a C character preceding the typical command For example CSTATUS abbreviated to CST is the Compressed ASCII STATUS command H identifies a header line to p...

Page 1297: ...f any subsequent message Normal transmission resumes after the relay receives an XON character Automatic Messages If you enable automatic messages AUTO Y the relay issues a message any time the relay turns on asserts a self test changes to another settings group or triggers an event For virtual ports the relay issues automatic messages only if the connection is active Automatic messages contain th...

Page 1298: ...responses SEL Fast Meter Fast Operate Fast SER Messages and Fast Message Data Access SEL Fast Meter is a binary message that you solicit with binary commands Fast Operate is a binary message for control The relay can also send unsolicited Fast SER messages and unsolicited synchrophasor messages automatically If the relay is connected to an SEL communications processor these messages provide the me...

Page 1299: ...y completed demand period A5D3h Peak demand Fast Meter data message Defines values for peak demands as of end of most recently completed demand periods Table 15 20 Fast Operate Command Types Command Hex Name Description A5E0h Fast Operate command for remote bits Sends command code that will change the state of a remote bit if setting FASTOP Y for this port A5E3h Fast Operate command for cir cuit b...

Page 1300: ... and types Func tion Code B1h 33h Bit label request Relay sends set of bit labels for specific data item Function Code B3h 10h Data request Relay responds with set of requested data Function Code 90h Table 15 21 Fast Message Command Function Codes Used With Fast Messages A546 Message and Relay Response Descriptions Sheet 2 of 2 Function Code Hex Function Relay Action Table 15 22 Commands in Recomm...

Page 1301: ...channels to a serial port PROTO MBA or MBGA for MIRRORED BITS communications Channel A or PROTO MBB or MBGB for MIRRORED BITS communications Channel B Transmitted bits include TMB1A TMB8A and TMB1B TMB8B The last letter A or B designates with which channel the bits are associated These bits are controlled by SELOGIC control equations Received bits include RMB1A RMB8A and RMB1B RMB8B You can use re...

Page 1302: ... multiply the analog quantity by a set value before transmission and divide by the same quantity upon reception To maintain accuracy add 0 5 to the analog quantity after any scaling Virtual terminal sessions Setting MBNUMVT controls the number of additional channels available for the virtual terminal session If MBNUMVT OFF the relay does not dedicate any additional channels to the virtual terminal...

Page 1303: ...igured data rate At 9600 bps this is approximately one message every 1 4 cycle At 19200 bps it is approximately every 1 8 cycle At 38400 bps it is approximately two every 1 8 cycle However if pacing is enabled it slows to one message every 3 ms at 19200 and 38400 bps see Table 15 26 Each message contains the most recent values of the transmit bits If you enabled any of the extended features throug...

Page 1304: ...ass every occurrence while a setting of 8 causes a counter to wait for eight con secutive occurrences in the received data before updating the data bits The pickup and dropout security count settings are separate Control the security count settings with the settings RMBnPU and RMBnDO A pickup dropout security counter operates identically to a pickup dropout timer except that the counter uses units...

Page 1305: ...el A or B exceeds a user definable threshold the relay will assert a user accessible flag RBADA or RBADB When channel unavailability exceeds a user definable threshold for Channel A or B the relay asserts a user accessible flag CBADA or CBADB MIRRORED BITS Communications Protocol for the Pulsar 9600 BPS Modem NOTE Use an SEL C272 or SEL C273 cable To use a Pulsar MBT modem set setting MBT Y Settin...

Page 1306: ...data and a failure to communicate properly When you set TXMODE to P the relay sends new MIRRORED BITS messages every 3 ms even if the selected data speed SPEED setting would allow more frequent messages As a function of the settings for SPEED TXMODE and MBT the message transmission periods are shown in Table 15 26 SPEED Data speed Hidden and set to 9600 if MBT Y 300 600 1200 2400 4800 9600 19200 3...

Page 1307: ...s hidden and set to 0 if MBNUM 7 or 8 0 n n 7 MBNUM MBANA1c Selection for analog Channel 1 Analog quantity label MBANA2c Selection for analog Channel 2 Analog quantity label MBANA3c Selection for analog Channel 3 Analog quantity label MBANA4c Selection for analog Channel 4 Analog quantity label MBANA5c Selection for analog Channel 5 Analog quantity label MBANA6c Selection for analog Channel 6 Anal...

Page 1308: ...ve a prompt before entering commands to avoid losing echoed characters while the external transmitter is warming up Step 2 You can use the commands that are available for the protocol setting of the port where the SEL 2885 is installed Step 3 If the port PROTO setting is set to SEL you can use the QUIT com mand to terminate the connection If no data are sent to the relay before the port time out p...

Page 1309: ...L 2600A RTD Module to the port via the SEL 2800 EIA 232 to Fiber Optic Transceiver Operation The SEL 2600A RTD module sends all temperature measurements to the relay every 0 5 seconds The relay places the received temperature measurements into analog quantities RTD01 RTD12 for use in freeform SELOGIC applications The data range is from 50 to 250 C NOTE When a channel status bit is not asserted the...

Page 1310: ...interpretation are indicated in Table 15 30 Direct Networking Example This direct networking example demonstrates direct networking to the relay using the Ethernet card Figure 15 10 shows the Ethernet network topology This examples uses a SEL 421 but the same concepts apply to any SEL 400 series relay MET T Enter Relay 1 Date 05 17 2003 Time 13 42 13 220 Station A Serial Number 0000000000 RTD Inpu...

Page 1311: ...IG B time synchronization from the SEL 2030 that is synchronized by the GPS clock attached to the SEL 2030 The SEL 2030 provides its output syn chronization signal from its internal clock so that loss of the signal from the GPS will not result in a loss of synchronization between substation devices as they will all be synchronized to the SEL 2030 clock During long periods of loss of synchronizatio...

Page 1312: ... of CTRL E TERTIM2 0 Length of time the channel must be idle before accepting the termination string in seconds IPADDR 10 201 0 112 16 IP network address DEFRTR 10 201 0 1 Default router ETCPKA N Disable TCP keep alive functionality IEC 61850 only KAIDLE 10 Length of time to wait with no detected activity before sending a keep alive packet must be greater than or equal to KAINTV KAINTV 1 Length of...

Page 1313: ... open data connection BAY_SCREEN TXT ERR TXT SET_A1 TXT SET_A10 TXT SET_A2 TXT SET_A3 TXT SET_A4 TXT SET_A5 TXT SET_A6 TXT SET_A7 TXT SET_A8 TXT SET_A9 TXT SET_ALL TXT SET_B1 TXT SET_D1 TXT SET_D2 TXT SET_D3 TXT SET_D4 TXT SET_D5 TXT SET_F1 TXT SET_G1 TXT SET_L1 TXT SET_L2 TXT SET_L3 TXT SET_L4 TXT SET_L5 TXT SET_L6 TXT SET_N1 TXT SET_O1 TXT SET_P1 TXT SET_P2 TXT SET_P3 TXT SET_P5 TXT SET_PF TXT S...

Page 1314: ...5 settings Only a portion of the PORT 5 settings are shown INFO RELAYTYPE SEL FID SEL 421 X045 V0 Z001001 D20010106 BFID SLBT CFS X000 PARTNO SEL 400H1234 IOBOARDS COMCARDS SEL 2701 X061 V0 Z000000 D20010117 SLBT 2701 X021 V0 Z000000 D20010109 1 P5 TIMEOUT 5 AUTO Y FASTOP N TERTIM1 1 TERSTRN 005 TERTIM2 0 IPADDR 10 201 0 112 SUBNETM 255 255 0 0 DEFRTR 10 201 0 1 NETPORT A FAILOVR N FTIME 5 NETASPD...

Page 1315: ...ttings AUTO Y FASTOP N TERTIM1 1 TERSTRN 005 TERTIM2 0 Fast Message Read Data Access FMRENAB Y FMRLCL N FMRMTR Y FMRDMND Y FMRTAR Y FMRHIS N FMRBRKR N FMRSTAT N FMRANA Y IP Configuration IPADDR 10 201 0 112 16 DEFRTR 10 201 0 1 ETCPKA Y KAIDLE 10 KAINTV 1 KACNT 6 NETMODE FIXED NETPORT A NETASPD AUTO NETBSPD AUTO NETCSPD AUTO NETDSPD AUTO FTP Configuration FTPSERV N HTTP Server Configuration EHTTP ...

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Page 1317: ...RTU then forwards data to the offsite master station By using a data communications protocol rather than hard wiring designers have reduced installation commissioning and mainte nance costs while increasing remote control and monitoring flexibility The DNP User s Group maintains and publishes DNP3 standards in cooperation with IEEE See the DNP User s Group web site www dnp org for more infor matio...

Page 1318: ...lso includes multiple versions called variations For example Object 1 has three variations 0 1 and 2 Variation 0 is used to request Object 1 data from a DNP3 device using its default variation Variation 1 is used to specify binary input values only and Variation 2 is used to specify binary input values with status information Each DNP3 device has both a list of objects and a map of object indices ...

Page 1319: ...analog points the remote device logs changes that exceed a dead band DNP3 outstation devices collect event data in a buffer that either the master can request or the device can send to the master without a request message Data sent from the out station to the master without a polling request are called unsolicited data DNP3 data fit into one of four event classes 0 1 2 or 3 Class 0 is reserved for...

Page 1320: ...quirements for all levels of outstation devices Some implementers perform their own conformance specification testing while some contract with independent companies to perform conformance testing Conformance testing does not always guarantee that a master and remote will be fully interoperable work together properly for all implemented features Con formance testing does help to standardize the tes...

Page 1321: ...rable networks through two primary mechanisms First the communications processor collects data from all remotes in parallel rather than one by one Second the master can collect all data with one message and response drastically reducing message overhead In the communications processor DNP3 network you can also collect data from devices that do not support the DNP3 protocol The communications proce...

Page 1322: ...g data The device trans mits if there is no carrier or waits for a random time before rechecking for a car rier signal However if two nodes both detect a lack of carrier at the same instant these two nodes could begin simultaneous transmission of data and cause a data collision If your network allows for spontaneous data transmission including unsolicited event data transmissions you also must use...

Page 1323: ... Operator initiated control Write analog set point Change the active protection settings group Time synchronization Set the relay time from the master station or automatically request time synchronization from the master Custom mapping Increase communications efficiency by organizing data and reducing available data to what you need for your applica tion Modem support Reduce the cost of the commun...

Page 1324: ...EIA 485 two wire net works are half duplex EIA 485 four wire networks do not provide carrier detec tion The relay uses application confirmation messages to guarantee delivery of unso licited event data before erasing the local event data buffer Data collisions are typically resolved when messages are repeated until confirmed The relay pauses for a random delay between the settings MAXDLY and MINDL...

Page 1325: ...ession n control default dead band operation for the specified data type Because DNP3 Objects 30 and 32 use integer data by default you can use scaling to send digits after the decimal point and avoid truncating to a simple integer value With no scaling the value of 12 632 would be sent as 12 With a scaling setting of 1 the value transmitted is 126 With a scaling setting of 3 the value transmit te...

Page 1326: ...me other high accuracy source Enable time synchronization with the TIMERQ setting TIMERQn for DNP3 LAN WAN Session n and use Object 50 Variation 1 and Object 52 Variation 2 Object 50 Variation 3 for DNP3 LAN WAN to set the time via a DNP3 master TIMERQ can be set in one of three ways A numeric setting of 1 32767 minutes specifies the rate at which the relay shall request a time synchronization A s...

Page 1327: ...f times the relay tries to dial PH_NUM1 before dialing PH_NUM2 Similarly the RETRY2 setting configures the number of times the relay tries to dial PH_NUM2 before trying PH_NUM1 MDTIME sets the length of time from initiating the call to declaring it failed because of no connection and MDRET sets the time between dial out attempts DNP3 Settings DNP3 configuration involves both Global SET G and Port ...

Page 1328: ... and LAN WAN and IEC 61850 GOOSE and MMS Before using the command take precautions to ensure against unintended operations from inadvertent messages sent as the result of a TEST DB2 override for example a bit used to trip a breaker on a remote relay via IEC 61850 GOOSE Table 16 8 Relay DNP3 Object List Sheet 1 of 6 Obj Var Description Requesta Responsea Funct Codes Qual Codes Funct Codes Qual Code...

Page 1329: ...vice name 1 0 129 0 17 0 248 Device attributes Device serial number 1 0 129 0 17 0 249 Device attributes DNP3 subset and conformance 1 0 129 0 17 0 250 Device attributes Device manufacturer s product name and model 1 0 129 0 17 0 252 Device attributes Device manufacturer s name 1 0 129 0 17 0 254 Device attributes Non specific all attributes request 1 0 6 129 0 17 0 255 Device attributes List of a...

Page 1330: ...en delta counter with time of freeze 21 9 32 Bit frozen counter without flag 21 10 16 Bit frozen counter without flag 21 11 32 Bit frozen delta counter without flag 21 12 16 Bit frozen delta counter without flag 22 0 Counter change event All variations 1 6 7 8 22 1 32 Bit counter change event without time 1 6 7 8 129 17 28 22 2a 16 Bit counter change event without time 1 6 7 8 129 130 17 28 22 3 3...

Page 1331: ...me of freeze 31 4 16 Bit frozen analog input with time of freeze 31 5 32 Bit frozen analog input without flag 31 6 16 Bit frozen analog input without flag 32 0 Analog change event All variations 1 6 7 8 32 1b 32 Bit analog change event without time 1 6 7 8 129 17 28 32 2b 16 Bit analog change event without time 1 6 7 8 129 130 17 28 32 3 32 Bit analog change event with time 1 6 7 8 129 17 28 32 4 ...

Page 1332: ...f request 41 2 16 Bit analog output block 3 4 5 6 17 28 129 echo of request 41 3 Single precision floating point analog output block 3 4 5 6 17 28 129 echo of request 41 4 Double precision floating point analog output block 3 4 5 6 17 28 129 echo of request 50 0 Time and date All variations 50 1 Time and date 1 2 7 8 index 0 129 07 quantity 1 50 2 Time and date with interval 50 3 Time and date at ...

Page 1333: ...ce map You may include any label in the Relay Word as part of a DNP3 custom map The relay scales analog values by the indicated settings or fixed scaling Analog inputs for event fault summary reporting use a default scale factor of 1 and dead band of ANADBM Per point scaling and dead band settings specified in a cus tom DNP3 map will override defaults 81 1 Storage object 82 1 Device profile 83 1 P...

Page 1334: ... 1 if leading 0 if lagging or zero 01 02 Relay Word Relay Word bit label Binary Outputs 10 12 RB01 RBnn Remote bits RB01 RBnna 10 12 RB01 RB02 RB03 RB04 RB05 RB06 RB29 RB30 RB31 RBnn Remote bit pairs RB01 RBnna 10 12 OCm Pulse open Circuit Breaker m commandb 10 12 CCm Pulse close Circuit Breaker m commandb 10 12 OCm CCm Open close pair for Circuit Breaker mb 10 12 89OC01 89OCdd Open Disconnect Swi...

Page 1335: ...he relay status variable STWARN and STFAIL are derived from the diagnostic task data and UNRDEV and NUNREV are derived from the event queue Another binary input STSET is derived from the SER and carries the time stamp of actual occurrence 10 12 RSTDNPE Reset clear DNP3 event summary AIsd 10 12 NXTEVE Load next fault event into DNP3 event summary AIs Binary Counters 20 22 ACTGRP Active settings gro...

Page 1336: ...fined All other fields are ignored A pulse operation is asserted for a single processing interval You should exercise caution if sending multiple remote bit pulses in a single message i e point count 1 because this may result in some of the pulse commands being ignored and the return of an already active status message The relay will only honor the first ten points in an Object 12 Variation 1 requ...

Page 1337: ...de specified by Port setting EVEMODn where n 1 6 for Ethernet sessions and not present for serial sessions The selected mode is entered when the relay is first enabled when there is a DNP3 settings change a DNP3 map change or an SER settings change When EVEMODn SINGLE the relay powers up in single event mode When EVEMODn MULTI the relay powers up in multiple event mode A DNP3 session will switch t...

Page 1338: ... The NUNREV bit will also be asserted as long as there remain any unread events newer than the currently loaded event summary To read the oldest unread relay event summary the master should send a close latch on or pulse on control to the NXTEVE binary output point This will load the relay event sum mary analogs with information from the oldest relay event summary discarding the values from the pr...

Page 1339: ...ost powerful features of the relay DNP3 implementation is the abil ity to remap DNP3 data and for analog and counter inputs specify per point scaling and dead bands Remapping is the process of selecting data from the default or reference map and organizing it into a dataset optimized for your appli cation The relay uses point labels rather than point indexes in a reference map to streamline the re...

Page 1340: ...ll cause the relay to report that value for that point Similarly for counters and analog inputs a value of 0 may be used instead of a label which will cause the relay to report 0 for that point A NOOP can be used as a placeholder for binary or analog outputs control of a point with this label does not change any relay values nor respond with an error message Duplicate point labels are not allowed ...

Page 1341: ...e of 157830 You will lose some precision as the last digit is dropped in the scaling process but you can transmit the scaled value using the default variations for DNP3 Objects 30 and 32 If your DNP3 master has the capability to request floating point analog input variations the relay will support them These floating point variations 5 and 6 for Object 30 and 5 8 for Object 32 allow the transmissi...

Page 1342: ...efault DNP map for Binary Outputs Y N DNPBOD Y Enter Use default DNP map for Counters Y N DNPCOD Y Enter Use default DNP map for Analog Inputs Y N DNPAID Y N Enter Use default DNP map for Analog Outputs Y N DNPAOD Y Enter Min Fault Location to Capture OFF 10000 10000 MINDIST OFF Max Fault Location to Capture OFF 10000 10000 MAXDIST OFF Analog Input Map Analog Input Label Scale Factor Deadband 1 LI...

Page 1343: ...ovide a resolution of 0 1 A and a maximum current of 3276 7 A Report change events on a change of 5 A 30 32 2 IB magnitude LIBFAb b Angles are scaled to 1 100 of a degree Report change events on a change of 2 degrees 30 32 3 IB angle LICFMa 30 32 4 IC magnitude LICFAb 30 32 5 IC angle VAFMc c For a nominal voltage of 230 kV scale the analog value by a factor of 100 to provide a resolution of 10 V ...

Page 1344: ...bol and press Enter to advance to the next step SET D 1 TERSE Enter DNP 1 DNP Object Default Map Enables Min Fault Location to Capture OFF 10000 10000 MINDIST OFF Enter Max Fault Location to Capture OFF 10000 10000 MAXDIST OFF Enter Binary Input Map Binary Input Label 1 RLYDIS DELETE 100 Enter 1 EN Enter 2 TRIPLED Enter 3 IN101 Enter 4 IN102 Enter 5 IN103 Enter 6 IN104 Enter 7 SALARM Enter 8 HALAR...

Page 1345: ...M Enter 6 LICFA LICFA 1 200 Enter 7 B1IAFM VAFM Enter 8 B1IAFA VAFA 1 200 Enter 9 B1IBFM VBFM Enter 10 B1IBFA VBFA 1 200 Enter 11 B1ICFM VCFM Enter 12 B1ICFA VCFA 1 200 Enter 13 B2IAFM 3P_F 40 40 Enter 14 B2IAFA 3Q_F 40 40 Enter 15 B2IBFM DC1 200 Enter 16 B2IBFA DELETE 200 Enter 16 Enter Analog Output Map Analog Output Label 1 ACTGRP Enter 2 Enter Save settings Y N Y Enter Saving Settings Please W...

Page 1346: ... a value of 10 4 as 104 which would remain unscaled at the mas ter DECPLV 2 Scale voltage multiplying by 100 to send kilovolts tenths and hundredths of a kilovolt DECPLM 2 Scale miscellaneous analog data multiplying by 100 to send whole numbers and hundredths The relay would report a value of 5 25 as 525 which would remain unscaled at the master STIMEO 10 0 10 second select before operate time out...

Page 1347: ...address of 192 9 0 3 and a DNP3 address of 12 The SEL 487E should be assigned an IP address of 192 9 0 2 default router of 192 9 0 1 and DNP3 address of 101 All event data analog binary counter should be assigned to CLASS 1 All Binary Inputs should have SOE quality time stamps The desired DNP3 data map is shown in Table 16 13 Figure 16 8 DNP3 LAN WAN Application Example Ethernet Network Table 16 1...

Page 1348: ...analog value by a factor of 10 to provide a resolution of 0 1 A and a maximum current of 3276 7 A Report change events on a change of 5 A b Angles are scaled to 1 100 of a degree Report change events on a change of 2 degrees c For a nominal voltage of 230 kV scale the analog value by a factor of 100 to provide a resolution of 10 V and a maximum value of 327 67 kV Report 1 kV for change event repor...

Page 1349: ...ECPLM1 2 Scale analog miscellaneous data multiplying by 10 to send whole numbers and tenths The relay would report a value of 5 25 as 525 which would remain unscaled at the master 102 100 STIMEO1 1 0a 1 0 second to select before operate time out DNPINA1 120a Wait 120 seconds to send inactive heartbeat DNPCL1 Y Allow DNP3 controls for this session AIVAR1 2 Default AI variation ANADBA1 200 Analog de...

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Page 1351: ...s SV products are compliant to the UCA 61850 9 2LE guidelines In accordance with the guideline each publication includes one application service data unit ASDU with four current and four voltage channels Supported publication rates are 4 8 kHz for a 60 Hz power system and 4 kHz for a 50 Hz power system SEL SV publishers support as many as seven SV streams SEL SV subscriber relays support subscribi...

Page 1352: ... tagged as Edition 2 Ed2 Some SEL 400 series devices are compliant with Ed2 Please refer to the product specific manual to identify such devices It is possible and even likely that an installation can have a mixture of devices that conform to either Ed1 or Ed2 The standard supports backwards compatibil ity i e Ed2 devices can send and receive messages to and from Ed1 devices However there are impo...

Page 1353: ...reate objects data items and ser vices that exist independently of any underlying protocols These objects are in conformance with the common data class CDC specification IEC 61850 7 3 which describes the type and structure of each element within a logical node CDCs for status measurements controllable analogs and statuses and settings all have unique CDC attributes Each CDC attribute belongs to a ...

Page 1354: ...pervisory control and data acquisition protocols SCADA that present data as a list of addresses or indices IEC 61850 presents data with descriptors in a composite notation made up of components Table 17 2 shows how the A Phase current expressed as MMXU A phsA cVal is broken down into its component parts Data Mapping Device data are mapped to IEC 61850 logical nodes LN according to rules defined by...

Page 1355: ...correct password authentication parameter value is received the device will provide a successful association response The device will allow access to all supported MMS services for that association Control IEC 61850 Controls An IEC 61850 server may allow a client to manipulate data related to its outputs external devices or internal functions This is accomplished by the IEC 61850 control model whi...

Page 1356: ...er a report just like any data attribute with trigger option Security in Control Models Security in the control model context refers to additional supervision of the sta tus value by the control object The enhanced security models report additional error information on failed operations to the requesting client than the models with normal security Enhanced security control models also provide a co...

Page 1357: ... AddCause value in an MMS information report See Clause 20 5 2 9 of IEC 61850 7 2 for additional information on the AddCause values SEL 400 series relays support the AddCause values in Table 17 4 as part of the LastApplError information report Figure 17 1 MMS Client View of the CON Logical Device Table 17 4 AddCause Descriptions Sheet 1 of 2 AddCause Enumeration AddCause Description Error Conditio...

Page 1358: ...at if the CID file contains a value for ActSG it will be ignored and the relay will use the actual active setting group value for ActSG at the time of CID file download When the IEC 61850 functions of the relay are enabled the selectActiveSG ser vice allows an MMS client to request that the relay change the active setting group The MMS client can request a group switch by writing a valid setting g...

Page 1359: ...ile read write etc are also available for transfer via MMS File Services SCL Files Substation Configuration Language SCL is an XML based configuration lan guage used to support the exchange of database configuration data between dif ferent tools which may come from different manufacturers There are four types of SCL files IED Capability Description file ICD System Specification Description SSD fil...

Page 1360: ... the predefined datasets For buffered reports connected clients may edit the report parameters shown in Table 17 5 Figure 17 2 Relay Predefined Reports Table 17 5 Buffered Report Control Block Client Access RCB Attribute User Changeable Report Disabled User Changeable Report Enabled Default Values RptID YES BRep01 BRep07 RptEna YES YES FALSE OptFlds YES seqNum timeStamp dataSet reasonCode entryID ...

Page 1361: ...resolution of 1 ms However the integrity report is only sent when the period has been detected as having expired The report service rate of 2 Hz results in a report being sent within 500 ms of expiration of the IntgPd The new IntgPd will begin at the time that the current report is serviced Datasets IEC 61850 datasets are lists of references to DataObject attributes for the purpose of efficient ob...

Page 1362: ...he SER the change is detected by the SER process For all other Booleans or Bstrings the change is detected via the scanner which compares the last state against the previous state to detect the change For analogs the scanner looks at the amount of change rela tive to the dead band configured for the point to indicate a change and apply the time stamp In all cases these timestamps are used for the ...

Page 1363: ...eference in each outgoing message and an Ethernet multicast group address Devices that receive GOOSE messages use the text identification and multicast group to identify and filter incoming GOOSE messages Virtual bits VB001 VB256 are control inputs that you can map to values from incoming GOOSE messages using the Architect software See the VBnnn bits in Table 17 10 Table 17 11 and Table 17 12 for ...

Page 1364: ...d Max Time configured for that GOOSE message The first transmission shall occur immediately upon triggering of an element within the GOOSE dataset The second transmission shall occur Min Time later The third shall occur Min Time after the second The fourth shall occur twice Min Time after the third All subsequent transmissions shall occur at the Max Time interval For example a message with a Min T...

Page 1365: ...r the following conditions After a permanent latching self test failure When EGSE is set to No Link layer priority tagging and virtual LAN is supported as described in Annex C of IEC 61850 8 1 2011 GOOSE Performance For outgoing high speed data as identified under GOOSE Processing transmis sion of GOOSE begins within 2 ms of transition of digital data within the relay Note that you can include RAO...

Page 1366: ... to 4 8 kHz 4 0 kHz when the nominal frequency is 60 Hz 50 Hz A time stamp representation known as smpCnt is encoded with each published SV message Given the sampling rate and the need to maintain the time coherence of samples from multiple merging units merging units must be time synchronized to high accuracy time source See Section 11 Time and Date Management for time syn chronization methods Th...

Page 1367: ...mation about TLOCAL and TGLOBAL SEL merging units use the information in Table 17 7 and Table 17 8 to determine the quality of sample timing and the smpSynch values See Table 17 7 and Table 17 8 for smpSynch values When high quality IRIG B is the current time source CUR_SRC BNC_IRIG or CUR_SRC SER_IRIG When high quality PTP is the current time source CUR_SRC PTP SV Subscription An SEL SV relay can...

Page 1368: ...red CH_DLY This design also provides a consis tent delay CH_DLY to protection and control operations which overcomes the non deterministic delays caused by the Ethernet process bus network If SV messages of the first SV subscription which is listed first in the COM SV command response are delayed by more than CH_DLY they are considered lost If less than three consecutive messages are delayed or mi...

Page 1369: ... pro cess bus traffic typically SV and GOOSE will only be transmitted on process bus ports If BUSMODE MERGED all communications use Port 5A and Port 5B with process bus and station bus traffic merged on the same physical net work and the process bus ports are disabled The designation of station bus and process bus is controlled by NETPORT settings The station bus port is the same as the primary po...

Page 1370: ...ay be reported For example Figure 17 8 shows an SEL merging unit publish ing two GOOSE messages from the station bus and process bus Without proper GOOSE messages routing on the Ethernet switch the SV relay receives GOOSE Figure 17 5 Independent Bus Mode With PTP Time Synchronization on the Station Bus Figure 17 6 Independent Bus Mode With IRIG Time Synchronization Figure 17 7 Merged Bus Mode With...

Page 1371: ...ation bus GOOSE messages Simulation Mode NOTE SV Simulation is only applicable in IEDs with SV subscription capability SEL 400 series relays including the SEL 401 can be configured to operate in simulation mode In this mode the SEL 400 series relays continue to process normal SV or GOOSE messages until a simulated SV or GOOSE message is received for a subscription Once a simulated SV or GOOSE mess...

Page 1372: ...y will reject the CID file upon download Edit other manufacturers ICD and CID files prior to importing them into Architect by adding leading zeros to the APPID and VLAN ID of outgoing GOOSE messages as necessary Architect provides a GUI for engineers to select edit and create IEC 61850 GOOSE messages important for substation protection coordination and control schemes Typically the engineer first ...

Page 1373: ...s exam ple shows how to use the software to configure two SV publications on an SEL 401 and an SEL 421 Example 17 1 SV Application Step 1 Open Architect Step 2 Insert the SEL 401 ICD and the SEL 421 7 SV Subscriber Relay ICD in the project tree Step 3 Create an SV Publication for the SEL 401 Configure SVID MAC address APP ID and VLAN information as desired Select an SV dataset to associate it with...

Page 1374: ... 20171006 IEC 61850 Communication IEC 61850 Configuration Step 4 To view the content of the dataset click the icon next to the dataset Example 17 1 SV Application Continued Figure 17 10 Configure an SV Publication Figure 17 11 Example SV Publication Dataset ...

Page 1375: ...21 and click the SV Receive tab to configure the SV subscriptions as shown in Figure 17 12 Step 6 Right click the IED and choose to send the CID file Ensure that the FTP function is enabled on the IEDs before sending CID files Example 17 1 SV Application Continued Figure 17 12 Configure SV Subscription Figure 17 13 Send SEL 401 CID File ...

Page 1376: ...clude it in the CID file to be sent to the device Step 7 Issue the COM SV command on the merging unit and the relay to verify successful publication and subscription Example 17 1 SV Application Continued Figure 17 14 Send SEL 421 7 CID File COM SV Enter TEST SV Mode OFF SV Publication Information MultiCastAddr Ptag Vlan AppID smpSynch _______________________________________________________________...

Page 1377: ...onfiguration Step 1 Open Architect Step 2 Click on the Settings Link tab and then click on Create Settings Link Step 3 Select the settings file and then press OK Step 4 Select which settings to embed in the CID file You can also save a local CID file with settings by clicking on Save CID with Settings ...

Page 1378: ...nstruction Manual Date Code 20171006 IEC 61850 Communication IEC 61850 Configuration Step 5 In the ACSELERATOR project editor window right click on the device to send the CID file Make sure to check the Include Device Settings box ...

Page 1379: ...to use that particular file Unless otherwise indicated ICD files will work with firm ware higher than the firmware in the description but not with lower firmware versions See Appendix A Firmware ICD File and Manual Versions in the product spe cific instruction manual for a list of ICD versions and corresponding firmware versions Logical Nodes Each logical device LD has a set of common data objects...

Page 1380: ...Common Logical Nodes Table 17 10 Table 17 13 show the logical nodes LNs supported in all SEL 400 series relays See the respective product specific instruction manuals to see which additional logical nodes are available in that relay Table 17 10 shows the LNs associated with the Logical Node CFG Health stVal Enumeration Health stVal Value Description 1 Ok EN Relay Word bit 1 5 Alarm EN Relay Word b...

Page 1381: ...al RB13 Remote Bit 13 RBGGIO2 SPCSO14 Oper ctlVal RB14 Remote Bit 14 RBGGIO2 SPCSO15 Oper ctlVal RB15 Remote Bit 15 RBGGIO2 SPCSO16 Oper ctlVal RB16 Remote Bit 16 RBGGIO3 SPCSO17 Oper ctlVal RB17 Remote Bit 17 RBGGIO3 SPCSO18 Oper ctlVal RB18 Remote Bit 18 RBGGIO3 SPCSO19 Oper ctlVal RB19 Remote Bit 19 RBGGIO3 SPCSO20 Oper ctlVal RB20 Remote Bit 20 RBGGIO3 SPCSO21 Oper ctlVal RB21 Remote Bit 21 RB...

Page 1382: ...16 Remote Bit 16 RBGGIO3a SPCSO17 stVal RB17 Remote Bit 17 RBGGIO3a SPCSO18 stVal RB18 Remote Bit 18 RBGGIO3a SPCSO19 stVal RB19 Remote Bit 19 RBGGIO3a SPCSO20 stVal RB20 Remote Bit 20 RBGGIO3a SPCSO21 stVal RB21 Remote Bit 21 RBGGIO3a SPCSO22 stVal RB22 Remote Bit 22 RBGGIO3a SPCSO23 stVal RB23 Remote Bit 23 RBGGIO3a SPCSO24 stVal RB24 Remote Bit 24 RBGGIO4a SPCSO25 stVal RB25 Remote Bit 25 RBGGI...

Page 1383: ...omation SELOGIC Math Variable 001 AMVGGIO1 AnIn002 instMag f AMV002 Automation SELOGIC Math Variable 002 AMVGGIO1 AnIn003 instMag f AMV003 Automation SELOGIC Math Variable 003 AMVGGIO1 AnIn062 instMag f AMV062 Automation SELOGIC Math Variable 062 AMVGGIO1 AnIn063 instMag f AMV063 Automation SELOGIC Math Variable 063 AMVGGIO1 AnIn064 instMag f AMV064 Automation SELOGIC Math Variable 064 AMVGGIO2 An...

Page 1384: ... Ra002 instMag f RA002 Remote Analog Input 002 RAGGIO1 Ra003 instMag f RA003 Remote Analog Input 003 RAGGIO1 Ra030 instMag f RA030 Remote Analog Input 030 RAGGIO1 Ra031 instMag f RA031 Remote Analog Input 031 RAGGIO1 Ra032 instMag f RA032 Remote Analog Input 032 RAGGIO2 Ra033 instMag f RA033 Remote Analog Input 033 RAGGIO2 Ra034 instMag f RA034 Remote Analog Input 034 RAGGIO2 Ra035 instMag f RA035...

Page 1385: ...Mag f RA162 Remote Analog Input 162 RAGGIO6 Ra163 instMag f RA163 Remote Analog Input 163 RAGGIO6 Ra190 instMag f RA190 Remote Analog Input 190 RAGGIO6 Ra191 instMag f RA191 Remote Analog Input 191 RAGGIO6 Ra192 instMag f RA192 Remote Analog Input 192 RAGGIO7 Ra193 instMag f RA193 Remote Analog Input 193 RAGGIO7 Ra194 instMag f RA194 Remote Analog Input 194 RAGGIO7 Ra195 instMag f RA195 Remote Ana...

Page 1386: ...LTGGIO5 Ind02 stVal ALT02 Automation Latch 2 ALTGGIO5 Ind03 stVal ALT03 Automation Latch 3 ALTGGIO5 Ind30 stVal ALT30 Automation Latch 30 ALTGGIO5 Ind31 stVal ALT31 Automation Latch 31 ALTGGIO5 Ind32 stVal ALT32 Automation Latch 32 ASVGGIO4 Ind001 stVal ASV001 Automation SELOGIC Variable 1 ASVGGIO4 Ind002 stVal ASV002 Automation SELOGIC Variable 2 ASVGGIO4 Ind003 stVal ASV003 Automation SELOGIC Va...

Page 1387: ...3 First Optional I O Board Input 3 if installed IN2GGIO15 Ind22 stVal IN222 First Optional I O Board Input 22 if installed IN2GGIO15 Ind23 stVal IN223 First Optional I O Board Input 23 if installed IN2GGIO15 Ind24 stVal IN224 First Optional I O Board Input 24 if installed IN3GGIO16 Ind01 stVal IN301 Second Optional I O Board Input 1 if installed IN3GGIO16 Ind02 stVal IN302 Second Optional I O Boar...

Page 1388: ...LBGGIO1 Ind30 stVal LB30 Local Bit 30 LBGGIO1 Ind31 stVal LB31 Local Bit 31 LBGGIO1 Ind32 stVal LB32 Local Bit 32 MBOKGGIO13 Ind01 stVal ROKA Normal MIRRORED BITS communications Channel A status while not in loopback mode MBOKGGIO13 Ind02 stVal RBADA Outage too long on MIRRORED BITS com munications Channel A MBOKGGIO13 Ind03 stVal CBADA Unavailability threshold exceeded for MIR RORED BITS communic...

Page 1389: ...O16 Ind14 stVal OUT214 First Optional I O Board Output 14 OUT2GGIO16 Ind15 stVal OUT215 First Optional I O Board Output 15 OUT2GGIO16 Ind16 stVal OUT216 First Optional I O Board Output 16 OUT3GGIO17 Ind01 stVal OUT301 Second Optional I O Board Output 1 OUT3GGIO17 Ind02 stVal OUT302 Second Optional I O Board Output 2 OUT3GGIO17 Ind03 stVal OUT303 Second Optional I O Board Output 3 OUT3GGIO17 Ind14 ...

Page 1390: ... PB10LED Pushbutton 10 LED PBLEDGGIO8 Ind11 stVal PB11LED Pushbutton 11 LED PBLEDGGIO8 Ind12 stVal PB12LED Pushbutton 12 LED PLTGGIO2 Ind01 stVal PLT01 Protection Latch 1 PLTGGIO2 Ind02 stVal PLT02 Protection Latch 2 PLTGGIO2 Ind03 stVal PLT03 Protection Latch 3 PLTGGIO2 Ind30 stVal PLT30 Protection Latch 30 PLTGGIO2 Ind31 stVal PLT31 Protection Latch 31 PLTGGIO2 Ind32 stVal PLT32 Protection Latch...

Page 1391: ...Remote Data Bits Channel A bit 16 RTCBGGIO2 Ind01 stVal RTCBD01 RTC Remote Data Bits Channel B bit 1 RTCBGGIO2 Ind02 stVal RTCBD02 RTC Remote Data Bits Channel B bit 2 RTCBGGIO2 Ind03 stVal RTCBD03 RTC Remote Data Bits Channel B bit 3 RTCBGGIO2 Ind14 stVal RTCBD14 RTC Remote Data Bits Channel B bit 14 RTCBGGIO2 Ind15 stVal RTCBD15 RTC Remote Data Bits Channel B bit 15 RTCBGGIO2 Ind16 stVal RTCBD16...

Page 1392: ...l TLED_12 Target LED 12 TLEDGGIO7 Ind15 stVal TLED_13 Target LED 13 TLEDGGIO7 Ind16 stVal TLED_14 Target LED 14 TLEDGGIO7 Ind17 stVal TLED_15 Target LED 15 TLEDGGIO7 Ind18 stVal TLED_16 Target LED 16 TLEDGGIO7 Ind19 stVal TLED_17 Target LED 17 TLEDGGIO7 Ind20 stVal TLED_18 Target LED 18 TLEDGGIO7 Ind21 stVal TLED_19 Target LED 19 TLEDGGIO7 Ind22 stVal TLED_20 Target LED 20 TLEDGGIO7 Ind23 stVal TL...

Page 1393: ...001 Virtual Bit 001 VBGGIO1 Ind002 stVal VB002 Virtual Bit 002 VBGGIO1 Ind003 stVal VB003 Virtual Bit 003 VBGGIO1 Ind126 stVal VB126 Virtual Bit 126 VBGGIO1 Ind127 stVal VB127 Virtual Bit 127 VBGGIO1 Ind128 stVal VB128 Virtual Bit 128 VBGGIO2 Ind129 stVal VB129 Virtual Bit 129 VBGGIO2 Ind130 stVal VB130 Virtual Bit 130 VBGGIO2 Ind131 stVal VB131 Virtual Bit 131 VBGGIO2 Ind254 stVal VB254 Virtual B...

Page 1394: ...16 defines the service support requirement and restrictions of the MMS services in the SEL 400 series devices Generally only those services whose implementation is not mandatory are shown Refer to the IEC 61850 standard Part 8 1 for more information configRev Always 0 1dNs IEC 61850 7 4 2007A Table 17 13 SEL Nameplate Data Sheet 2 of 2 Data Attribute Value Table 17 14 PICS for A Profile Support Pr...

Page 1395: ...butes deleteNamedType input output takeControl relinquishControl defineSemaphore deleteSemaphore reportPoolSemaphoreStatus reportSemaphoreStatus initiateDownloadSequence downloadSegment terminateDownloadSequence initiateUploadSequence uploadSegment terminateUploadSequence requestDomainDownload requestDomainUpload loadDomainContent storeDomainContent deleteDomain getDomainAttributes Y createProgram...

Page 1396: ...llmentAttributes acknowledgeEventNotification getAlarmSummary getAlarmEnrollmentSummary readJournal writeJournal initializeJournal reportJournalStatus createJournal deleteJournal fileOpen Y fileRead Y fileClose Y fileRename fileDelete Y fileDirectory Y unsolicitedStatus informationReport Y eventNotification attachToEventCondition attachToSemaphore conclude Y cancel Y getDataExchangeAttributes exch...

Page 1397: ...C 61850 stan dard Part 8 1 for more information deleteAccessControlList alterAccessControl reconfigureProgramInvocation Table 17 17 MMS Parameter CBB MMS Parameter CBB Client CR Server CR Supported Supported STR1 Y STR2 Y VNAM Y VADR Y VALT Y TPY Y VLIS Y CEI Table 17 18 AlternateAccessSelection Conformance Statement AlternateAccessSelection Client CR Server CR Supported Supported accessSelection ...

Page 1398: ...Supported name Y address variableDescription scatteredAccessDescription invalidated Table 17 21 Read Conformance Statement Read Client CR Server CR Supported Supported Request specificationWithResult variableAccessSpecification Response variableAccessSpecification Y listOfAccessResult Y Table 17 22 GetVariableAccessAttributes Conformance Statement GetVariableAccessAttributes Client CR Server CR Su...

Page 1399: ...variableSpecification Y alternateAccess Y Table 17 25 DeleteNamedVariableList Conformance Statement DeleteNamedVariableList Client CR Server CR Supported Supported Request Scope listOfVariableListName domainName Response numberMatched numberDeleted DeleteNamedVariableList Error Table 17 23 DefineNamedVariableList Conformance Statement Sheet 2 of 2 DefineVariableAccessAttributes Client CR Server CR...

Page 1400: ...on 2 B23 SCSM IEC 6185 9 2 used B24 SCSM other Generic Substation Event GSE Model B31 Publisher side Y B32 Subscriber side Y Transmission of Sampled Value Model SVC B41 Publisher side B42 Subscriber side Y Table 17 28 ACSI Models Conformance Statement Sheet 1 of 2 Client Subscribera Server Publishera Value Comments If Server Side B11 and or Client Side B12 Supported M1 Logical device Y M2 Logical ...

Page 1401: ...trol Y M17 File transfer Y M18 Application association M19 GOOSE control block Y M20 Sampled Value control block If GSE B31 32 Is Supported M12 GOOSE Y M13 GSSE Deprecated in Edition 2 If SVC B41 42 Is Supported M14 Multicast SVC M15 Unicast SVC For All IEDs M16 Time Y Time source with required accuracy shall be available Only the time master is an SNTP Mode 4 response time server All other client...

Page 1402: ...S8 1 2 GetDataValues TP Y S9 1 2 SetDataValues TP S10 1 2 GetDataDirectory TP Y S11 1 2 GetDataDefinition TP Y Data Set S12 1 2 GetDataSetValues TP Y S13 1 2 SetDataSetValues TP S14 1 2 CreateDataSet TP S15 1 2 DeleteDataSet TP S16 1 2 GetDataSetDirectory TP Y Substitution S17 1 SetDataValues TP Setting Group Control S18 1 2 SelectActiveSG TP Y S19 1 2 SelectEditSG TP S20 1 2 SetEditSGValues TP S2...

Page 1403: ...1 2 GetGoReference TP S37 1 2 GetGOOSEElementNumber TP S38 1 2 GetGoCBValues TP Y S39 1 2 SetGoCBValues TP GSSE S40 1 SendGSSEMessage MC Deprecated in Edition 2 GSSE CONTROL BLOCK S41 1 GetReference TP Deprecated in Edition 2 S42 1 GetGSSEElementNumber TP Deprecated in Edition 2 S43 1 GetGsCBValues TP Deprecated in Edition 2 S44 1 SetGsCBValues TP Deprecated in Edition 2 Transmission of Sampled Va...

Page 1404: ... application adheres to the Control S51 1 2 Select S52 1 2 SelectWithValue TP Y S53 1 2 Cancel TP Y S54 1 2 Operate TP Y S55 1 2 CommandTermination TP Y S56 1 2 TimeActivatedOperate TP File Transfer S57 1 2 GetFile TP Y S58 1 2 SetFile TP S59 1 2 DeleteFile TP S60 1 2 GetFileAttributeValues TP Y S61 1 2 GetServerDirectory FILE SYSTEM TP Y Time T1 1 2 Time resolution of internal clock 20 Nearest ne...

Page 1405: ...thod was used to specify the operate time out of control objects in the CID files A client or automation application that relies on this proprietary method will fail to find the operate time out in the CID file A workaround is to use the Ed1 CID file to configure the IED You can also resolve this by reconfig uring the client or automation application to accept the Ed2 control object operate time o...

Page 1406: ...n operate time out error after the operate time out expired However in Ed2 any such test com mands will fail immediately with an error indicating that the command is blocked because the IED is not in the appropriate mode Clients or automation applica tions that depend on the Ed1 behavior might fail You can resolve this by recon figuring the client or automation application No Reports Ed2 specifies...

Page 1407: ...a allows multiple devices such as a number of relays to synchronize the gathering of power system data The accurate clock allows precise event report triggering and other offline analysis functions The Global settings class contains the synchrophasor settings including the choice of Synchrophasor Protocol and the synchrophasor data set the relay will transmit The Port settings class selects which ...

Page 1408: ...s with an internal logic engine and sends control command to external devices to perform user defined actions Additionally the SVP can send calculated or derived data to devices such as other SVPs phasor data concentrators PDCs and monitoring systems In any installation the relay can use only one of the synchrophasor message for mats SEL Fast Message Synchrophasor or C37 118 as selected by Global ...

Page 1409: ... absolute time reference for the synchrophasor Also an angular compensation factor compen sates for the phase shift introduced by the PMU hardware and software The modulated data are filtered using low pass filters The filter coefficients are based on NFREQ PMAPP and MRATE The filtered data provides good attenu ation for harmonics and interharmonics For PMAPP F and N the attenuation is 20 dB For P...

Page 1410: ...ystem frequency Accuracy The following phasor measurement accuracy is valid when frequency based pha sor compensation is enabled Global setting PHCOMP Y and when the pha sor measurement application setting is in the narrow bandwidth mode Global setting PMAPP N NOTE When the PMU is in the fast response mode Global setting PMAPP F the TVE is within specified limits only when the out of band interfer...

Page 1411: ...n the STAT field indicating cur rent data have errors and therefore synchrophasor data are invalid For an explanation of other bits in the STAT field refer to the IEEE C37 118 standard Synchrophasor Frequency The PMU calculates frequency deviation and rate of change of frequency from the synchrophasor positive sequence voltage angle V1nPMA where n PMFRQST as follows First the PMU calculates the fr...

Page 1412: ...e which terminals are available to synchrophasors Synchrophasors are primarily configured through the Global settings There are also a few port settings necessary to enable synchrophasor communications Global Settings The Global enable setting EPMU must be set to Y before the remaining synchro phasor settings are available The PMU is disabled when EPMU N FREQPMk favgk NFREQ analog DFDTPMk dfdtk an...

Page 1413: ...0 and as many as 50 messages per second if NFREQ 50 NUMPHDC Number of Data Configurations 1 5 PMSTNqc Station Name 16 characters PMIDqc PMU Hardware ID 1 65534 PHDVqc Phasor Data Set Voltages V1 PH ALL PHDIqc Phasor Data Set Currents I1 PH ALL PHNRqc Phasor Num Representation I Integer F Float PHFMTqc Phasor Format R Rectangular P Polar FNRqc Freq Num Representation I Integer F Float TREA 1 4 Trig...

Page 1414: ...es the non legacy settings NUMPHDC Enables as many as five unique synchrophasor data configurations The four serial ports Port 1 2 3 and F and two Ethernet sessions TCP UDP sessions 1 and 2 can be mapped to any of these five data configurations In other words each port can be configured to send unique synchrophasor data streams PMSTNq and PMIDq Defines the station name and number of the PMU for da...

Page 1415: ... point F of voltage and current phasor data in the synchrophasor data stream q This setting affects the synchrophasor data packet size PHNRq I sends each voltage and or current synchrophasor as 2 two byte integer values The PMU uses 7 INOM CT Ratio 32768 100000 for the current phasor scaling factor and uses 150 PTR 32768 100000 for the voltage phasor scaling factor INOM is 1 A or 5 A PHNRq F sends...

Page 1416: ...the synchrophasor data stream q If a phasor is not assigned a descriptive name it will be described using the phasor name Analog Quantities in Data Configuration q Analog Quantity Name Alias Name This is a freeform setting category with two arguments Specify the analog quan tity name and an optional 16 character descriptive name to be included in the syn chrophasor data stream q See Section 12 Ana...

Page 1417: ...EA1 TREA4 or PMTRIG Relay Word bits these bits must be programmed These bits may be used to send various messages at a low bandwidth via the syn chrophasor message stream Digital Status Words may also be used to send binary information directly without the need to manage the coding of the trigger reason messages in SELOGIC Use these Trigger Reason bits if your synchrophasor system design requires ...

Page 1418: ...quency fluctuations PHCOMP Enables or disables frequency based compensation for synchrophasors For most applications set PHCOMP Y to activate the algorithm that compen sates for the magnitude and angle errors of synchrophasors for frequencies that are off nominal For PMAPP F or N the PMU only compensates if the estimated frequency is 5 Hz of nominal frequency For PMAPP 1 the PMU compensates if the...

Page 1419: ...rol on page 18 36 PMODC NOTE If PMODC is set to a number that exceeds the setting for NUMPHDC the port sends the data for the first PMU configuration Select the data configuration 1 NUMPHDC for synchrophasor data transmis sion on the specific serial port This setting affects the synchrophasor data packet size See Communications Bandwidth on page 18 24 for detailed information Through the use of th...

Page 1420: ...rnet Port 5 Settings for Synchrophasors Setting Description Default EPMIP Enable PMU Processing Y N N PMOTS1 PMU Output 1 Transport Scheme OFF TCP UDP_S UDP_T UDP_U OFF PMODC1 PMU Output 1 Data Configuration 1 5 1 PMOIPA1 PMU Output 1 Client IP Remote Address www xxx yyy zzz 192 168 1 3 PMOTCP1 PMU Output 1TCP IP Local Port Number 1 65534 4712 PMOUDP1 PMU Output 1 UDP IP Data Remote Port Number 1 ...

Page 1421: ...tion 1 NUMPHDC for synchrophasor data transmis sion on the specific session 1 and 2 Using this setting each Ethernet session can be configured to stream unique synchrophasor data PMOIPA 2 Defines the PMU Output Client IP address for session 1 and 2 respectively PMOTCP 2 Defines the TCP IP Local port number for session 1 and 2 respectively These port numbers must all be unique PMOUDP 2 Defines the ...

Page 1422: ...lects the voltage sources for the synchrophasor data selected by PHDATAV Use the PHVOLT setting to select any combination of available voltage terminals PHCURR and PHDATAI PHDATAI and PHCURR select which current synchrophasors to include in the data packet PHDATAI I1 will transmit only positive sequence current I1 PHDATAI PH transmits phase currents IA IB IC PHDATAI ALL will transmit I1 IA IB and ...

Page 1423: ...nd the relay does not send any user definable analog values NUMDSW Selects the number of user definable digital status words to be included in the synchrophasor data stream Setting NUMDSW 0 sends no user definable binary status words Setting NUMDSW 1 2 3 or 4 sends the user definable binary status words as listed in Table 18 6 If MFRMT FM this is forced to 1 Table 18 5 User Defined Analog Values S...

Page 1424: ...V63 PSV49 2 2 PSV64 PSV63 PSV49 PSV48 PSV47 PSV33 4 3 PSV64 PSV63 PSV49 PSV48 PSV47 PSV33 PSV32 PSV31 PSV17 6 4 PSV64 PSV63 PSV49 PSV48 PSV47 PSV33 PSV32 PSV31 PSV17 PSV16 PSV15 PSV01 8 Table 18 7 Synchrophasor Trigger Relay Word Bits Name Description PMTRIG Trigger SELOGIC control equation TREA4 Trigger Reason Bit 4 SELOGIC control equation TREA3 Trigger Reason Bit 3 SELOGIC control equation TREA...

Page 1425: ... Asserts for one processing interval when data for all enabled channels are aligned Use this bit to condition general usage of the aligned synchrophasor data RTCDLYA This bit is asserted when the last received valid message on Channel A is older than MRTCDLY RTCDLYB This bit is asserted when the last received valid message on Channel B is older than MRTCDLY RTCSEQA This bit is asserted when the pr...

Page 1426: ... d n current terminal Phase k synchrophasor current M magnitude A Angle R Real I Imaginary Terminal n A Primary degrees A Primary A Primary I1nPMM I1nPMA I1nPMR I1nPMI Positive sequence synchrophasor current M magnitude A Angle R Real I Imaginary Terminal n A Primary degrees A Primary A Primary SODPM Second of the day of the PM data s FOSPM Fraction of the second of the PM data s Table 18 12 Synch...

Page 1427: ...ommand will only operate when the relay is in the HIRIG time keeping mode as indicated by Relay Word bit TSOK logical 1 RTCDFB Remote frequency rate of change for Channel B Hz s VkmPMMD VkmPMAD VkmPMRD VkmPMIDa b Aligned phase k synchrophasor voltage M magnitude A Angle R Real I Imaginary Terminal m kV Primary degrees kV Primary kV Primary V1mPMMD V1mPMAD V1mPMRD V1mPMIDb Aligned positive sequence...

Page 1428: ...mplete command options and error messages MET PM Enter Relay 1 Date 04 20 2015 Time 22 02 12 000 Station A Serial Number 1152490016 Time Quality Maximum time synchronization error 0 000 ms TSOK 1 Serial Port Configuration Error N PMU in TEST MODE N Synchrophasors VV Phase Voltages Pos Sequence Voltage VA VB VC V1 MAG kV 127 266 126 972 127 148 127 128 ANG DEG 73 542 46 400 166 103 73 677 VZ Phase ...

Page 1429: ...Rq selects the numeric format to use for these two quantities The relay can include as many as sixteen user programmable analog values in the synchrophasor message and 0 16 32 48 or 64 digital status values The relay always includes the results of four synchrophasor trigger reason SELOGIC equations TREA1 TREA2 TREA3 and TREA4 and the trigger SELOGIC control equation result PMTRIG in the synchropha...

Page 1430: ... add to the byte requirements Table 18 13 can be used to cal culate the number of bytes in a synchrophasor message Table 18 14 lists the bps settings available on any relay serial port setting SPEED and the maximum message size that can fit within the port bandwidth Blank entries indicate bandwidths of less than 20 bytes Table 18 13 Size of a C37 118 Synchrophasor Message Item Possible number of q...

Page 1431: ...processor The synchrophasor processor controls the PMU functions of the relay with IEEE C37 118 commands including commands to start and stop synchro phasor data transmission and commands to request a configuration block from the relay so the synchrophasor processor can automatically build a database structure Transmit Mode Control The relay will not begin transmitting synchrophasors until an enab...

Page 1432: ... out of a substation UDP_S uses the least amount of overhead and provides some additional security as the PMU or PDC using this method is only sending data and ignores any messages coming in TCP TCP stands for Transmission Control Protocol and is a connection oriented pro tocol which means that it requires handshaking to set up end to end communica tions Once a connection is set up user data may b...

Page 1433: ...e synchrophasor data and rectangular coordinates The system designer specified integer numeric representation for the frequency data The system designer specified fast synchrophasor response because the data are being used for system monitoring The protection settings and RTD serial port settings will not be shown Determining Settings The protection engineer performs a bandwidth check using Table ...

Page 1434: ... S W X Y Z X PHDV1 Phasor Data Set Voltages I1 PH ALL V1 VYCOMP Voltage Angle Compensation Factor 179 99 to 180 degrees 4 20 PHDI1 Phasor Data Set Currents I1 PH ALL ALL IWCOMP IW Angle Compensation Factor 179 99 to 180 degrees 3 50 IXCOMP IX Angle Compensation Factor 179 99 to 180 degrees 5 50 PHNR1 Phasor Numeric Representation I Integer F Floating point F PHFMT1 Phasor Format R Rectangular coor...

Page 1435: ...16 Example Synchrophasor Protection Freeform Logic Settings Setting Value PSV64 NOT 3PO OR SPO Line breaker status Table 18 17 Example Synchrophasor Port Settings Setting Description Value PROTO Protocol SEL DNP MBA MBB MBGA MBGB RTD PMU PMU SPEED Data Speed 300 to 57600 19200 STOPBIT Stop Bits 1 2 bits 1 RTSCTS Enable Hardware Handshaking Y N N FASTOP Enable Fast Operate Messages Y N N PMU MODE P...

Page 1436: ...a single syn chrophasor positive sequence voltage for example at a message period of one second places little burden on the communications channel As more synchro phasors are added or if the message rate is increased some communications channel restrictions come into play Table 18 19 PMU Settings in the Relay for SEL Fast Message Protocol in Global Settings Setting Description EPMU Enable Synchron...

Page 1437: ...chrophasor message Table 18 21 lists the bps settings available on any relay serial port setting SPEED and the maximum message size that can fit within the port bandwidth Blank entries indicate bandwidths of less than 40 bytes Referring to Table 18 20 and Table 18 21 it is clear that the lower SPEED set tings are very restrictive Some observations from Table 18 21 follow A serial port set with SPE...

Page 1438: ...sor The relay will stop synchrophasor transmission on a particular serial port when the disable command is received from the synchrophasor processor or when the relay settings for that port are changed The relay will stop synchrophasor transmission on all serial ports when any Global or Group settings change is made The relay will respond to configuration block request messages regardless of the p...

Page 1439: ...in the Fast Operate Configuration Block A change to any FOPp_n value will cause the client to transmit a Fast Operate remote bit control message on Port p If the FOP control bit asserts the message will contain the opcode to set the corresponding control bit in the PMU If it deasserts the message will contain the opcode to clear the control bit The remote device will send a Fast Operate message no...

Page 1440: ... load from the system To set the relay for such a control scenario first configure synchrophasors for the C37 118 protocol Figure 18 8 depicts one way to configure synchrophasors for transport In this SEL 487E example all of the S and T terminal phase currents and Z terminal voltages along with the positive sequence values are being trans mitted in polar floating point format at a message rate of ...

Page 1441: ...Name 1 Z 2 S 3 T PHDV1 ALL PHDI1 ALL PHNR1 F PHFMT1 P FNR1 F Phasor Aliases in Data Configuration 1 Phasor Name Alias Name Synchrophasor Analog Quantities in Data Configuration 1 Analog Quantity Name Alias Name Synchrophasor Digitals in Data Configuration 1 Digital Name Alias Name TREA1 NA TREA2 NA TREA3 NA TREA4 NA PMTRIG NA PMTEST NA VZCOMP 0 00 ISCOMP 0 00 ITCOMP 0 00 PMFRQA S PHCOMP Y Synchron...

Page 1442: ...of synchro phasor data set this setting to SERVER The Global setting MFRMT determines the format of the transmitted data When using the port to receive synchrophasor data from another device set this setting to either CLIENTA or CLIENTB Only two ports may be configured as client ports and they must be uniquely configured for Channel A or Channel B When a port is configured to receive synchrophasor...

Page 1443: ...plus add some margin for internal delays in both the remote and local relay When you use the PMU for synchrophasor acquisition the delayed and aligned analog quantities specific to that relay are available Be aware that these quanti ties are only valid when RTCROK is asserted and only for the enabled channels The specific channel quantities are also valid whenever their respective RTCROKp Relay Wo...

Page 1444: ...el A within the window you set with the local MRTCDLY setting 100 ms in this example If the RTCDLYA asserts consider three options First the MRTCDLY setting can be increased However the MRTCDLY setting is your way of guaranteeing operation within a certain time Increasing MRTCDLY allows for communications channels with longer transmission delay but at the cost of increasing the maximum time of ope...

Page 1445: ...ophasor message is received For purposes of this example we need it to hold true until the next message is received To achieve this lines 11 13 implement a timer to extend this bit by 1 75 cycles A message is expected every 1 cycle the additional 0 75 cycles covers any jitter that may occur in the rate or message receipt Line 14 calculates a qual ification signal consisting of the local and remote...

Page 1446: ...gs according to Figure 18 16 It is important for synchrophasors to be enabled EPMU Y the application to be fast PMAPP F the compensation settings to be set correctly VYCOMP VZCOMP IWCOMP and IXCOMP and for IRIGC C37 118 Set MRTCDLY for the maximum expected communications channel delay in milliseconds Any data arriving later than this time are rejected The RTCDLYA Relay Word bit indicates this cond...

Page 1447: ...to the SER The RTCCFGA Relay Word bit is asserted after the two relays have communi cated configuration data successfully RTCCFGA deassertion indicates that the system has changed perhaps because of a setting change in one of the relays Synchronized Phasor Measurement Settings MFRMT C37 118 MRATE 60 PMAPP F PHCOMP Y PMSTN LOCAL RTC PMID 4 PHDATAV V1 VCOMP 0 00 PHDATAI NA IWCOMP 0 00 IXCOMP 0 00 PH...

Page 1448: ...n the SER provides warning The COM RTC command also provides information for monitoring system sta tus Figure 18 19 shows a COM RTC command response Use the maximum packet delay field to monitor the communications channel delay This informa tion can help you choose an appropriate value for the MRTCDLY setting PMU Recording Capabilities The PMU can be configured to record synchrophasor data by sett...

Page 1449: ...s Additional PMTRIG assertions are ignored during recording Table 18 26 shows the setting name description and default value to help config ure the data recording Descriptions for the settings in Table 18 26 are as follows EPMDR Use the EPMDR setting to enable synchrophasor data recording This setting is hidden when EPMU N When EPMDR Y phasor measurement data record ing will begin on the rising ed...

Page 1450: ...ile name The CONAM setting is three characters long The settings allows all printable characters except PMLER PMLER sets the total length of the synchrophasor data recording in seconds The PMLER time includes the PMPRE time For example if PMLER is set for 30 seconds of PMU recorded data and PMPRE is set for 10 seconds of pretrigger data the final recording will contain 10 seconds of pretrigger dat...

Page 1451: ...ion process Some of the benefits of a TiDL system include Use ACSELERATOR QuickSet SEL 5030 Software to set the relay as you would conventional SEL 400 series relays Firmware for the SEL 400 series relays was modified for the implementation of TiDL however the settings and protection algorithms were unchanged Decrease costs through copper reduction Simplify the installation process Increase safety...

Page 1452: ...supports TiDL all output settings for I O are available Correctly set these outputs for what is installed because all output settings will be available but all may not be physically installed in your system Relay Word bits IO300OK IO400OK and IO500OK indicate the status of installed I O boards in standard relays or whether a remote module is commis sioned such as in a TiDL system These bits can al...

Page 1453: ...s requires a SEL 2243 Power Coupler see Figure 19 4 This module supplies power to the rest of the node and transmits the data to the relay through fiber optic communication See the SEL 2240 Axion Instruction Manual for more information The SEL 2244 2 Digital Input Module see Figure 19 5 consists of 24 optoiso lated inputs that are not polarity dependent These inputs can be configured to respond to...

Page 1454: ...alog Input Module see Figure 19 7 provides protec tion class ac analog input CT PT and can accept three voltage and three current inputs The module samples at 24 kHz and is 1 A or 5 A software selectable Depending on the supported fixed topology multiple CT PT input modules can function in each node Some topologies only support one CT PT module per node See the supported topologies in Section 2 In...

Page 1455: ...relay location IEC 61850 9 2 Sampled Values SV Some SEL 400 series relays are available with the capability to either publish or subscribe to remote analogs in accordance with the UCA International Users Group s Implementation Guideline for Digital Interface to Instrument Trans formers Using IEC 61850 9 2 This type of remote data acquisition is a subset of IEC 61850 9 2 and specifies among other t...

Page 1456: ...E requires time synchronization for all devices This can also be accomplished over either the process bus or the station bus network via IEEE 1588 or Precision Time Protocol PTP Alternately SEL SV devices can be synchronized via IRIG B Because of the bandwidth requirements and message types that can be present on the process bus optimal SV performance requires a well engineered process bus and sta...

Page 1457: ...ionality of the device The SV publica tion capability of each SEL SV publishing devices is identical so throughout this section SEL devices with SV publication enabled are referred to as SV publish ers The SV publisher digitizes the data from its voltage and current inputs records its current state of time synchronization scales these values to primary units by using the CT and PT ratio settings a...

Page 1458: ...er via a GUI This interface provides the most flexible configuration of SV publications including the creation of customized SV datasets This mechanism is very similar to the configuration of GOOSE publications For more information see IEC 61850 Configuration on page 17 22 Architect includes an ICD file for the SEL 401 and an ICD file for the SEL 421 with SV publication capability ICD files of bot...

Page 1459: ... publisher is configured via Port 5 set tings the dataset name remains blank because it is not used in Port 5 settings and therefore unavailable For more information on the COM SV command see Section 9 ASCII Command Reference in the product specific manual The TEST SV command places the SV publisher into TEST SV mode In this mode it replaces the current and voltage data of all SV configured stream...

Page 1460: ...l phases from each SV stream SEL SV relays can subscribe to as many as seven SV streams Once SV subscriptions are configured and are being received the SV subscriber relay provides a suite of protection functionality Please refer to the specific prod uct instruction manual for a list of available protection functions Note that IEC 61850 9 2LE only covers the publication and subscription of remote ...

Page 1461: ...ickly configure SV subscriptions that do not require much customization All phases A B C of a current or voltage terminal must be mapped to an SV subscription Please note that regardless of the configuration method you cannot map a current or voltage phase value into more than one subscriber slot SV Subscriber Startup When initially turned on the SV subscriber ENABLED LED illuminates as soon as pr...

Page 1462: ... code to indicate when it has had to interpolate for missing or lost data If more than three consecutive SV packets are delayed or missing the COM SV command uses the error message SV STREAM LOST to indicate any subscriptions in this condition If any subscribed SV streams are lost the SV subscriber can still be able to pro vide some subset of metering and protection functionality depending on what...

Page 1463: ...r being received lost One or more subscribed SV streams have a subscription status SVSmmOK bit that is not set The SV subscriber also provides analog channel status Relay Word bits which are useful for supervising protection based on the state of SV communications for each current and voltage channel These bits include nnnOK and nnnBK bits where nnn is the product specific current or voltage chann...

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Page 1465: ...SV Remote Data Acquisition Updated Generating Raw Data Oscillograms and added Figure 9 7 An Overcurrent Application Via Remote Data Acquisition through Figure 9 9 Filtered Event Reports From SEL 401 and SEL 421 Section 10 Added Sequence of Events Recorder to Table 10 6 Troubleshooting Procedures Added Table 10 7 Troubleshooting for Relay Self Test Warnings and Failures Section 11 Added PTP Over PR...

Page 1466: ...ommunications for information on MMS inactivity Appendix B Updated TiDL Firmware Upgrade 20161215 Preface Updated to describe the new section Section19 Remote Data Acquisition Section 1 Updated to introduce TiDL technology Section 3 Added information on TiDL system input and output handling Section 7 Added information about leading and lagging power factor Relay Word bits Section 9 Described the i...

Page 1467: ...S Connection Section 19 Added as a new section Appendix B Updated to describe firmware upgrades to the TiDL system Appendix C Updated to describe cybersecurity aspects of EtherCAT ports Glossary Added terms related to TiDL systems 20160518 Initial version Table A 1 Instruction Manual Revision History Sheet 3 of 3 Date Code Summary of Revisions ...

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Page 1469: ...t release A stan dard release adds new functionality to the firmware beyond the specifications of the existing version A point release is reserved for modifying firmware function ality to conform to the specifications of the existing version A standard release is identified by a change in the R number of the device firm ware identification FID string Existing firmware FID SEL 411L R100 V0 Z001001 ...

Page 1470: ...manages IEC 61850 GOOSE MMS and SV CID files Appropriate SEL 400 series relay manual Important Considerations If upgrading an SEL 451 5 SEL 421 4 or SEL 421 5 relay from firmware revi sion R309 or earlier to firmware revision R312 and later make sure you save all relay settings including IEC 61850 CID configurations if applicable prior to the firmware upgrade as indicated in Save Settings and Othe...

Page 1471: ... Firmware Loader you must have QuickSet See Section 2 PC Software for instructions on how to obtain and install the software Once the software is installed perform the firmware upgrade as follows A Obtain Firmware File NOTE The Firmware Loader can be used to load only relay firmware Rnnn4xx or Rnnn Vy4xx If you need to upgrade relay SELBOOT firmware use Method Two The firmware file is usually prov...

Page 1472: ...relay serial port and to the PC C Establish Communications With the Relay NOTE Once serial port communication is established it is recommended to set the SELBOOT Max Baud setting to the highest possible port speed available typically 115200 bps This will reduce the time needed to read settings and events from the relay Use the Communications Parameters menu of QuickSet to establish a con nection u...

Page 1473: ...ettings was selected the Firmware Loader reads all of the settings from the relay The software may ask if you want to merge the settings read from the relay with existing design templates on the PC Click No do not merge settings with Design Template The Firmware Loader will suggest a name for the settings but the suggested name can be modified as desired If Save events was selected the Event Histo...

Page 1474: ...irmware Upload progress will be shown in the Transfer Status window The entire firmware upload process can take longer than 10 minutes to complete When the firmware upload is complete the relay will restart The Firmware Loader automatically re establishes communications and issues an STA com mand to the relay In cases where the relay does not restart within two minutes of the firmware upload compl...

Page 1475: ...oader If status failures are shown open the terminal and see Troubleshooting on page B 17 Click Next to go to the completion step I Verify Relay Settings If there are no failures the relay will enable In the Step 4 of 4 window see Figure B 4 the Firmware Loader will give you the option to compare the device settings If any differences are found the software will provide the opportunity to restore ...

Page 1476: ...atch check the relay settings and wiring Step 9 Autoconfigure the SEL communications processor port if you have an SEL communications processor connected to the relay This step re establishes automatic data collection between the SEL communi cations processor and the relay Failure to perform this step can result in automatic data collection failure when cycling communications processor power Step ...

Page 1477: ...vel 1 prompt Step 3 Type 2AC Enter and then type the correct password to go to Access Level 2 You will see the Access Level 2 prompt For more information see Making an EIA 232 Serial Port Connection on page 3 4 Backup Relay Settings The relay preserves the settings and passwords during the firmware upgrade pro cess However if relay power is interrupted during the firmware upgrade process the relay...

Page 1478: ... the SELBOOT prompt type BAU 115200 Enter see Figure B 5 Step 2 Set your terminal program for a data speed of 115200 bps Step 3 Press Enter to check for the SELBOOT prompt indicating that serial communication at 115200 bps is successful E Upload New SELBOOT Firmware to the Relay NOTE Loading the incorrect SELBOOT firmware to the relay may cause the relay to malfunction requiring factory repair Upg...

Page 1479: ...lay response is Are you sure you want to erase the existing firmware Y N Step 2 Type Y Enter The relay responds Erasing and erases the existing firmware The front panel LCD shows ERASING MEMORY When finished erasing the relay responds Erase successful and prompts you to press any key to begin transferring the new firmware The front panel LCD shows only the SELBOOT program revision number Step 3 Pr...

Page 1480: ...he SELBOOT prompt Step 2 Type BAU 9600 Enter to reduce the data speed to your nominal serial communications speed 9600 bps in this example Step 3 Set your terminal emulation program to match the nominal data speed Step 4 Type Enter to confirm that you have reestablished communication with the relay The relay responds with the SELBOOT prompt Step 5 Type EXI Enter to exit the SELBOOT program After a...

Page 1481: ...on manual for information on the SHOW and SET commands Step 5 Type STA Enter to check relay status Step 6 Verify that all relay self test parameters are within tolerance J Return the Relay to Service Step 1 Follow your company procedures for returning a relay to service Step 2 Type MET Enter to view power system metering Step 3 Verify that the current and voltage signals are correct Step 4 Type TR...

Page 1482: ...ersion b Run Architect and open the project that contains the existing CID file for the relay Use Architect to download the CID from the relay and select File Download CID in the menu bar to save the CID file c If using embedded settings create an updated rdb file with the settings read in I Verify Relay Settings on page B 7 Update the reference in the Settings Link tab and save the new CID file d...

Page 1483: ... determined by issuing the VERSION command in the relay see Figure B 6 To upgrade the firmware perform the following steps Remove From Service Step 1 Remove the unit from service Step 2 Turn the unit off Step 3 Remove the front panel Upgrade Step 1 Copy the ECB and SEL 2245 firmware zds files from the upgrade CD to an SD card Step 2 Install the SD card in the SD card slot indicated in Figure B 7 S...

Page 1484: ... 6H is the right most LED As each module is updated its corresponding LED blinks four times per second The upgrade process usually completes in less than 10 minutes If remote Axion modules are being upgraded and there is more than one Axion module connected to a port the upgrade may take longer The upgrade has successfully completed when all of the LEDs are either on or off not blinking The left f...

Page 1485: ...E command to the relay This tells the relay to bypass the model number check at the start of the firmware upload process Once the REC OVERRIDE command is issued the firmware upload process can be continued following the procedures in F Upload New Relay Firmware on page B 11 starting with Step 2 on page B 11 Resolving Status Failure Message Response to STA Command If a status failure message is ret...

Page 1486: ...act SEL for assistance If using Method Two and the settings do not match the settings contained in the text file you recorded in B Prepare the Relay on page B 9 contact SEL for assistance Step 12 Use the PAS n n 0 1 2 B P A O C command to set the relay passwords Step 13 Restore the relay settings a If you have SEL 5010 Relay Assistant software or QuickSet restore the original settings by following...

Page 1487: ...rable All IP ports can be dis abled and are disabled by default Table C 1 describes each of these Note that IP traffic is only supported on station bus ports so process bus ports have no open IP ports See Ethernet Communications on page 15 6 for more infor mation on these settings Table C 1 IP Port Numbers IP Port Default Port Selection Setting Network Protocol DefaultPort State Port Enable Settin...

Page 1488: ...e relay to disable Authentication and Authorization Controls Local Accounts SEL 400 series relays support eight levels of access as described in the Access Levels and Passwords on page 3 7 Refer to this section to learn how each level is accessed and what the default passwords are It is good security practice to change the default passwords of each access level and to use a unique password for eac...

Page 1489: ...bedded Devices located at selinc com mitigating_malware SEL 400 series relays run in an embedded environment for which there is no commercial anti virus software available Software Firmware Verification SEL 400 series relays have the ability to install firmware updates in the field Authenticity and integrity of firmware updates can be verified by using the Firm ware Hash page at selinc com product...

Page 1490: ...a common concern Typically relays are installed within a control enclosure that provides physical security Other times they are installed in boxes within the switch yard The relay provides some tools that may be useful to help manage physical security especially when the unit is installed in the switch yard You can monitor physical ingress by wiring a door sensor to one of the relay con tact input...

Page 1491: ...lay using the following procedure Step 1 Go to Access Level 2 Step 2 Execute the R_S command to restore the device to factory default settings Step 3 Allow the relay to restart Step 4 Go to Access Level 2 Step 5 Execute the R_S command again to set the backup copy of settings to factory default Step 6 Allow the relay to restart Once this procedure is complete all internal instances of all user set...

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Page 1493: ... substation battery charger has failed Acceptance Testing Testing that confirms that the relay meets published critical performance specifications and requirements of the intended application Such testing involves testing protection elements and logic functions when qualifying a relay model for use on the utility system Access Level A relay command level with a specified set of relay information a...

Page 1494: ...log to Digital Converter A device that converts analog signals into digital signals Admittance The reciprocal of impedance I V Advanced Settings Settings for customizing protection functions these settings are hidden unless you set EADVS Y and EGADVS Y Alias An alternative name assigned to Relay Word bits analog quantities default terminals and bus zone names Analog Quantities Variables represente...

Page 1495: ...o the true state logical 1 of that condition To apply a closed contact to a relay input To close a normally open output contact To open a normally closed output contact AT Modem Command Set Dialing String Standard The command language standard that Hayes Microcomputer Products Inc developed to control autodial modems from an ASCII terminal usually EIA 232 connected or a PC containing software allo...

Page 1496: ...c Statements Statements consisting of variables that behave according to Boolean logic operators such as AND NOT and OR Breaker Auxiliary Contact An electrical contact associated with a circuit breaker that opens or closes to indicate the breaker position A Form A breaker auxiliary contact ANSI Standard Device Number 52A closes when the breaker is closed and opens when the breaker is open A Form B...

Page 1497: ...itor Element Device consisting of two electrodes separated by a dielectric Capacitor Unit Assembly of a number of capacitor elements Category A collection of similar relay settings CCVT Coupling capacitor voltage transformer that uses a capacitive voltage divider to reduce transmission voltage to a level safe for metering and relaying devices See CVT Checksum A method for checking the accuracy of ...

Page 1498: ... Data Classes include Status information Measured information Controllable status Controllable analog Status settings Analog settings and Description information Common Inputs Relay control inputs that share a common terminal Common Time Delay Both ground and phase distance protection follow a common time delay on pickup Common Zone Timing Both ground and phase distance protection follow a common ...

Page 1499: ...rent signals to nullify any standing unbalance current Current Reversal Guard Logic Under this logic the relay does not key the transmitter and ignores reception of a permissive signal from the remote terminal when a reverse looking element detects an external fault Current Transformer Saturation The point of maximum current input to a CT any change of input beyond the saturation point fails to pr...

Page 1500: ...ks the period when relay contacts continue to move after closing debounce time covers this indeterminate state Default Data Map The default map of objects and indices that the relay uses in DNP3 protocol Delta A phase to phase series connection of circuit elements particularly voltage transformers or loads Demand Meter A measuring function that calculates a rolling average or thermal average of in...

Page 1501: ...eaker as well as simultaneous transmission of a tripping signal to the relay at the opposite end of the line The scheme is said to be underreaching because the Zone 1 relays at both ends of the line reach only 80 percent typically of the entire line length Dynamic Zone Selection The process by which the currents from the CTs are assigned to or removed from the differential calculations as a functi...

Page 1502: ...t location maximum fault phase current active group at the trigger instant and targets Event Report A text based collection of data stored by the relay in response to a triggering condition such as a fault or ASCII TRI command The data show relay measurements before and after the trigger in addition to the states of protection elements relay inputs and relay outputs each processing interval After ...

Page 1503: ...onvolatile data Flashover A disruptive discharge over the surface of a solid dielectric in a gas or liquid Float High The highest charging voltage supplied by a battery charger Float Low The lowest charging voltage supplied by a battery charger Free Form Logic Custom logic creation and execution order Free Form SELOGIC Control Equations Free form relay programming that includes mathematical operat...

Page 1504: ...isions relay setting ORDER Ground Distance Element A mho or quadrilateral distance element the relay uses to detect faults involving ground along a transmission line Ground Fault Loop Impedance The impedance in a fault caused electric circuit connecting two or more points through ground conduction paths Ground Overcurrent Elements Elements that operate by comparing a residual ground calculation of...

Page 1505: ...ge System voltage greater than or equal to 100 kV and less than 230 kV Hybrid Control Output Contacts that use an insulated gate bipolar junction transistor IGBT in parallel with a mechanical contact to interrupt break high inductive dc currents The contacts can carry continuous current while eliminating the need for heat sinking and providing security against voltage transients These contacts are...

Page 1506: ...ated abrupt spurious variations in duration magnitude or frequency L R Circuit inductive resistive ratio LAN Local Area Network A network of IEDs interconnected in a relatively small area such as a room building or group of buildings Latch Bits Nonvolatile storage locations for binary information LED Light emitting diode Used as indicators on the relay front panel Left Side Value LVALUE Result sto...

Page 1507: ...culations for automation or extended protection functions Math Operators Operators that you use in the construction of math SELOGIC control equations to manipulate numerical values and provide a numerical base 10 result Maximum Dropout Time The maximum time interval following a change of input conditions between the deassertion of the input and the deassertion of the output Maximum Minimum Meter T...

Page 1508: ...negative sequence set of voltage sources Negative Sequence Overcurrent Elements Elements that operate by comparing a negative sequence calculation of the three phase secondary inputs with negative sequence overcurrent setting thresholds The relay asserts these elements when a relay negative sequence calculation exceeds negative sequence current setting thresholds Negative Sequence Voltage Polarize...

Page 1509: ...e breaker CTs are part of two bus zones i e a fault between the tie breaker CTs is common to two bus zones Override Values Test values you enter in Fast Meter DNP3 and communications card database storage Parentheses Operator Math operator Use paired parentheses to control the execution of operations in a SELOGIC control equation PC Personal computer Peak Demand Metering Maximum demand and a time ...

Page 1510: ... Bits Positive Sequence A configuration of three phase currents and voltages The currents and voltages have equal magnitude and a phase displacement of 120 With conventional rotation in the counter clockwise direction the positive sequence current and voltage maxima occur in ABC order Positive Sequence Current Restraint Factor a2 This factor compensates for highly unbalanced systems with many untr...

Page 1511: ...lp of qualifier codes DNP3 master devices can compose the shortest most concise messages R_TRIG Rising edge trigger Boolean SELOGIC control equation operator that triggers an operation upon logic detection of a rising edge RAM Random Access Memory Volatile memory where the relay stores intermediate calculation results Relay Word bits and other data Reactance Reach The reach of a distance element i...

Page 1512: ...s five line CTs Retrip A subsequent act of attempting to open the contacts of a circuit breaker after the failure of an initial attempt to open these contacts Reverse Fault A fault operation behind a relay terminal Rising Edge Transition from logical 0 to logical 1 or the beginning of an operation RMS Root mean square This is the effective value of the current and voltage measured by the relay acc...

Page 1513: ...0 sequential events Series Compensated Line A power line on which the addition of series capacitance compensates for excessive inductive line impedance Settle Settling Time Time required for an input signal to result in an unvarying output signal within a specified range Shot Counter A counter that records the number of times a recloser attempts to close a circuit breaker Shunt Admittance The admi...

Page 1514: ...A mix of valid password characters in a six character combination that does not spell common words in any portion of the password Valid password characters are numbers upper and lowercase alphabetic characters period and hyphen Subnet Mask The subnet mask divides the local node IP address into two parts a network number and a node address on that network A subnet mask is four bytes of information ...

Page 1515: ...with more than 21 and as many as 54 per phase CTs require three SEL 487B relays Stations with as many as 21 per phase CTs require only one SEL 487B Tie Breaker See Bus Coupler and Bus Sectionalizer Time Delay on Pickup The time interval between initiation of a signal at one point and detection of the same signal at another point Time Dial A control that governs the time scale of the time overcurre...

Page 1516: ...ment that calculates the percentage difference between the three phase currents Unbalanced Fault All faults that do not include all three phases of a system Unbuffered Report IEC 61850 IEDs can issue immediate unbuffered reports of internal events caused by trigger options data change quality change and data update on a best efforts basis If no association exists or if the transport data flow is n...

Page 1517: ...um is a pared down version of SGML designed especially for web documents It allows designers to create their own customized tags enabling the definition transmission validation and interpretation of data among applications and organizations Zero Sequence A configuration of three phase currents and voltages with currents and voltages that occur simultaneously are always in phase and have equal magn...

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