Transcript
Page 1: Manual 7SJ62-63-64 v44

C53000-G1140-C147–1

SIPROTEC

Multi-FunctionalProtective Relay withLocal Control7SJ62/63/64V4.4

Manual

PrefaceTable of Contents

Introduction 1Functions 2Installation and Commissioning 3Technical Data 4Appendix AIndex

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Siemens Aktiengesellschaft Buch-Nr. C53000-G1140-C147–1

Liability Statement

We have checked the text of this manual against thehardware and software described. Exclusions and de-viations cannot be ruled out; we accept no liability forlack of total agreement.

The information in this manual is checked periodically,and necessary corrections will be included in futureeditions. We appreciate any suggested improvements.

We reserve the right to make technical improvementswithout notice.

Release 4.40.02

Copyright

Copyright © Siemens AG 2002. All rights reserved.

Dissemination or reproduction of this document, or evalu-ation and communication of its contents, is not authorizedexcept where expressly permitted. Violations are liable fordamages. All rights reserved, particularly for the purposesof patent application or trademark registration.

Registered trademarks

SIPROTEC®, SIMATIC®, SIMATIC NET ®, SINAUT ®, SI-CAM®, and DIGSI® are registered trademarks of SiemensAG. Other designations in this manual may be trademarksthat if used by third parties for their own purposes may vi-olate the rights of the owner.

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Preface

Purpose of ThisManual

This manual describes the functions, operation, installation, and placing into serviceof the devices 7SJ62, 7SJ63 and 7SJ64. In particular, one will find:

• Descriptions of device functions and settings → Chapter 2;

• Instructions for mounting and commissioning → Chapter 3;

• Compilation of technical specifications → Chapter 4;

• As well as a compilation of the most significant data for experienced users in theAppendix.

General information about design, configuration, and operation of SIPROTEC® devic-es are laid down in the SIPROTEC® 4 system manual, order no. E50417–H1176–C151.

Target Audience Protection engineers, commissioning engineers, personnel concerned with adjust-ment, checking, and service of selective protective equipment, automatic and controlfacilities, and personnel of electrical facilities and power plants.

Applicability ofThis Manual

This manual is valid for: SIPROTEC® 4 7SJ62/63/64 Multifunction Protective Relays;firmware version 4.4.

Indication of Conformity

This product complies with the directive of the Council of the European Communitieson the approximation of the laws of the member states relating to electromagneticcompatibility (EMC Council Directive 89/336/EEC) and concerning electrical equip-ment for use within certain voltage limits (Low-voltage Directive 73/23/EEC).

This conformity is proved by tests conducted by Siemens AG in accordance with Ar-ticle 10 of the Council Directive in agreement with the generic standards EN 50081and EN 50082 for EMC directive, and with the standard EN 60255–6 for the low-volt-age directive.

The product conforms with the international standard of the series IEC 60255 and theGerman standard DIN 57435 /Part 303 (corresponds to VDE 0435/Part 303).

ANSI This product has been designed according to ANSI C37.90.* standards.

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Preface

This product is UL–certified with the data as stated in Section 4.1:

Additional Support Should further information be desired or should particular problems arise which arenot covered sufficiently for the purchaser's purpose, the matter should be referred tothe local Siemens representative.

Training Courses Individual course offerings may be found in our Training Catalogue, or questions maybe directed to our training center. Please contact your Siemens representative.

Instructions andWarnings

The warnings and notes contained in this manual serve for your own safety and for anappropriate lifetime of the device. Please observe them!

The following terms are used:

DANGERindicates that death, severe personal injury or substantial property damage will resultif proper precautions are not taken.

Warningindicates that death, severe personal injury or substantial property damage can resultif proper precautions are not taken.

Cautionindicates that minor personal injury or property damage can result if proper precau-tions are not taken. This particularly applies to damage on or in the device itself andconsequential damage thereof.

Noteindicates information about the device or respective part of the instruction manualwhich is essential to highlight.

IND. CONT. EQ.TYPE 169CA

IND. CONT. EQ.TYPE 1

Warning!Hazardous voltages are present in this electrical equipment during operation. Non–observance of the safety rules can result in severe personal injury or property dam-age.

Only qualified personnel shall work on and around this equipment after becoming thor-oughly familiar with all warnings and safety notices of this manual as well as with theapplicable safety regulations.

The successful and safe operation of this device is dependent on proper handling, in-stallation, operation, and maintenance by qualified personnel under observance of allwarnings and hints contained in this manual.

In particular the general erection and safety regulations (e.g. IEC, DIN, VDE, EN orother national and international standards) regarding the correct use of hoisting gearmust be observed. Non–observance can result in death, personal injury or substantialproperty damage.

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Preface

QUALIFIED PERSONNEL

For the purpose of this instruction manual and product labels, a qualified person is onewho is familiar with the installation, construction and operation of the equipment andthe hazards involved. In addition, he has the following qualifications:

• Is trained and authorized to energize, de-energize, clear, ground and tag circuitsand equipment in accordance with established safety practices.

• Is trained in the proper care and use of protective equipment in accordance with es-tablished safety practices.

• Is trained in rendering first aid.

Typographic andSymbol Conven-tions

The following text formats are used when literal information from the device or to thedevice appear in the text flow:

Parameter names, i.e. designators of configuration or function parameters whichmay appear word-for-word in the display of the device or on the screen of a personalcomputer (with operation software DIGSI® 4), are marked in bold letters of a mono-space type style.

Parameter options, i.e. possible settings of text parameters, which may appearword-for-word in the display of the device or on the screen of a personal computer(with operation software DIGSI® 4), are written in italic style, additionally.

“Annunciations”, i.e. designators for information, which may be output by the relayor required from other devices or from the switch gear, are marked in a monospacetype style in quotation marks.

Deviations may be permitted in drawings when the type of designator can be obviouslyderived from the illustration.

The following symbols are used in drawings:

Besides these, graphical symbols are used according to IEC 60617–12 andIEC 60617–13 or similar. Some of the most frequently used are listed below:

address 1234 and the possible settings On and Off

UL1–L2

Earth fault device-internal logical input signal

Earth fault device-internal logical output signal

internal input signal of an analogue quantity

>Release external binary input signal with function number Fno

Dev. Trip external binary output signal with function number Fno

On

Off

1234 FUNCTION

Parameter addressParameter name

Parameter options

example of a parameter switch designated FUNCTION with the

FNo 567

FNo 5432

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Preface

Furthermore, the graphic symbols according IEC 60617–12 and IEC 60617–13 orsimilar are used in most cases.

Input signal of an analogue quantity

or OR gate

& AND gate

signal inversion

=1Exclusive–OR gate (antivalence): output is active, if only oneof the inputs is active

=Coincidence gate (equivalence): output is active, if both input areactive or inactive at the same time

Dynamic inputs (edge–triggered)above with positive, below with negative edge

Formation of one analogue output signal froma number of analogue input signals (example: 3)

Iph>

2610 Iph>>

Limit stage with setting address and parameter designator (name)

0T

2611 T Iph>>

Timer (pickup delay T, example adjustable)with setting address and parameter designator (name)

0 TTimer (dropout delay T, example non-adjustable)

T Dynamic triggered pulse timer T (monoflop)

S

R

Q Static memory (RS–flipflop) with setting input (S),resetting input (R), output (Q) and inverted output (Q)Q

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Table of Contents

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

1.1 Overall Operation ................................................................................................................... 2

1.2 Applications ............................................................................................................................ 6

1.3 Characteristics........................................................................................................................ 9

2 Functions............................................................................................................................................ 15

2.1 General................................................................................................................................. 172.1.1 Configuration of Functions.................................................................................................... 192.1.2 General Device Data ............................................................................................................ 232.1.2.1 Setting Notes........................................................................................................................ 242.1.2.2 Information Overview............................................................................................................ 24

2.1.3 Power System Data 1........................................................................................................... 262.1.3.1 Power System ...................................................................................................................... 262.1.3.2 Current Transformers (CT’s) ................................................................................................ 282.1.3.3 Voltage Transformers (VT’s) ................................................................................................ 282.1.3.4 Circuit Breaker (CB) ............................................................................................................. 292.1.3.5 Information .......................................................................................................................... 30

2.1.4 Waveform Capture ............................................................................................................... 312.1.4.1 Information ........................................................................................................................... 32

2.1.5 Setting Groups ..................................................................................................................... 332.1.5.1 Settings ................................................................................................................................ 332.1.5.2 Information ........................................................................................................................... 33

2.1.6 Power System Data 2........................................................................................................... 342.1.6.1 Settings ................................................................................................................................ 362.1.6.2 Information .......................................................................................................................... 37

2.2 Overcurrent Protection (50, 50N, 51, 51N)........................................................................... 382.2.1 Description ........................................................................................................................... 392.2.1.1 Definite Time, Instantaneous Overcurrent Protection (50, 50N)........................................... 392.2.1.2 Inverse Time-Overcurrent Protection (51, 51N) ................................................................... 432.2.1.3 Dynamic Cold Load Pick-up Function .................................................................................. 462.2.1.4 Inrush Restraint .................................................................................................................... 472.2.1.5 Reverse Interlocking Bus Protection .................................................................................... 49

2.2.2 Programming Time-Overcurrent Settings............................................................................. 502.2.2.1 General................................................................................................................................. 502.2.2.2 Definite-Time Overcurrent Protection (50-2, 50-1) ............................................................... 512.2.2.3 Inverse-Time Overcurrent Protection (51) ............................................................................ 532.2.2.4 Programming Settings for Time-Overcurrent Ground Protection ......................................... 572.2.2.5 Inverse-Time Overcurrent Protection (51N) ......................................................................... 58

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2.2.2.6 Inrush Restraint .................................................................................................................... 58

2.2.3 Settings................................................................................................................................. 592.2.3.1 Information List ..................................................................................................................... 61

2.3 Directional Overcurrent Protection (67, 67N)........................................................................ 642.3.1 Description of Directional Overcurrent Protection................................................................. 662.3.1.1 Definite Time, Directional Overcurrent Protection ................................................................ 662.3.1.2 Inverse Time, Directional Overcurrent Protection (67-TOC, 67N-TOC) ............................... 682.3.1.3 Determination of Direction .................................................................................................... 702.3.1.4 Reverse Interlocking for Looped Lines ................................................................................. 73

2.3.2 Programming Directional Overcurrent Settings .................................................................... 752.3.2.1 General ................................................................................................................................. 752.3.2.2 Definite-Time, Directional Overcurrent Protection (67-2, 67-1) ............................................ 772.3.2.3 Inverse-Time Directional Overcurrent Protection (67-TOC) ................................................. 782.3.2.4 Programming Settings for Directional Overcurrent Ground Protection................................. 812.3.2.5 Inverse-Time Directional Overcurrent Protection (67N-TOC)............................................... 82

2.3.3 Settings................................................................................................................................. 832.3.3.1 Information List for Directional Ground Overcurrent Protection............................................ 85

2.4 Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc).................................. 872.4.1 Description of Dynamic Cold Load Pick-Up Function ........................................................... 872.4.2 Programming Settings .......................................................................................................... 902.4.2.1 General ................................................................................................................................. 902.4.2.2 Non-Directional Phase Elements.......................................................................................... 912.4.2.3 Non-Directional Ground Elements ........................................................................................ 912.4.2.4 Directional Phase Elements.................................................................................................. 912.4.2.5 Directional Ground Element.................................................................................................. 922.4.2.6 Settings for Dynamic Cold Load Adjustments ...................................................................... 922.4.2.7 Information List for Dynamic Cold Load Setting Adjustments............................................... 93

2.5 Voltage Protection (27, 59) ................................................................................................... 942.5.1 Description of Voltage Protection ......................................................................................... 942.5.1.1 Measurement Principle ......................................................................................................... 942.5.1.2 Overvoltage Protection (59).................................................................................................. 952.5.1.3 Undervoltage Protection (27)................................................................................................ 96

2.5.2 Programming Settings ........................................................................................................ 1002.5.2.1 Voltage Protection – General.............................................................................................. 1002.5.2.2 Undervoltage Protection ..................................................................................................... 1002.5.2.3 Overvoltage Protection ....................................................................................................... 1012.5.2.4 Settings for Voltage Protection .......................................................................................... 1022.5.2.5 Information List for Voltage Protection................................................................................ 102

2.6 Negative Sequence Protection (46).................................................................................... 1042.6.1 Description of Negative Sequence Protection .................................................................... 1042.6.1.1 Determination of Unbalanced Load .................................................................................... 1042.6.1.2 Definite Time Elements (46-1, 46-2)................................................................................... 1042.6.1.3 Inverse Time Element (46-TOC)......................................................................................... 105

2.6.2 Programming Settings ........................................................................................................ 1072.6.2.1 General ............................................................................................................................... 1072.6.2.2 Definite Time Elements....................................................................................................... 1072.6.2.3 Inverse Time Element 46-TOC........................................................................................... 1092.6.2.4 Settings for Negative Sequence (Phase Balance) Current Protection ............................... 1102.6.2.5 Information List for Negative Sequence Current Protection ............................................... 111

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2.7 Motor Protection (Motor Starting Protection, 48 and Start Inhibit for Motors, 66/68).......... 1122.7.1 Description of Motor Starting Protection............................................................................. 1122.7.2 Description of Start Inhibit for Motor ................................................................................... 1142.7.3 Programming Settings........................................................................................................ 1182.7.3.1 General............................................................................................................................... 1182.7.3.2 Motor Starting Protection (48) ............................................................................................ 1192.7.3.3 Start Inhibit for Motors (66, 86)........................................................................................... 1202.7.3.4 Settings .............................................................................................................................. 1232.7.3.5 Information ......................................................................................................................... 124

2.8 Frequency Protection (81 O/U)........................................................................................... 1262.8.1 Description of Frequency Protection .................................................................................. 1262.8.2 Programming Settings........................................................................................................ 1272.8.2.1 General............................................................................................................................... 1272.8.2.2 Frequency Protection Settings ........................................................................................... 1272.8.2.3 Settings for Frequency Protection ...................................................................................... 1282.8.2.4 Information List for Frequency Protectio............................................................................. 129

2.9 Thermal Overload Protection (49) ...................................................................................... 1302.9.1 Description of Thermal Overload Protection....................................................................... 1302.9.2 Programming Settings........................................................................................................ 1342.9.2.1 General............................................................................................................................... 1342.9.2.2 Overload Settings............................................................................................................... 1342.9.2.3 Settings for Thermal Overload Protection .......................................................................... 1382.9.2.4 Information List for Thermal Overload Protection............................................................... 139

2.10 Monitoring Functions .......................................................................................................... 1402.10.1 Description of Measured Values Monitoring....................................................................... 1402.10.1.1 Hardware Monitoring .......................................................................................................... 1402.10.1.2 Software Monitoring............................................................................................................ 1412.10.1.3 Monitoring of External Current Transformer Circuits .......................................................... 1422.10.1.4 Description of Fuse-Failure-Monitor ................................................................................... 144

2.10.2 Programming Settings for Measured Values Monitoring .................................................... 1442.10.2.1 General............................................................................................................................... 1442.10.2.2 Measured Values Monitoring.............................................................................................. 1442.10.2.3 Fuse-Failure-Monitor .......................................................................................................... 1452.10.2.4 Settings for Measured Values Monitoring........................................................................... 1452.10.2.5 Information List for Measured Values Monitoring............................................................... 146

2.10.3 Description of Trip Circuit Monitor (74TC) .......................................................................... 1472.10.4 Programming Settings for Trip Circuit Monitor ................................................................... 1502.10.4.1 Setting for Trip Circuit Monitor............................................................................................ 1522.10.4.2 Information ......................................................................................................................... 152

2.10.5 Malfunction Responses of the Monitoring Functions.......................................................... 1522.10.6 Group Alarms ..................................................................................................................... 154

2.11 Sensitive Ground Fault Detection (64, 50Ns, 67Ns)........................................................... 1552.11.1 Description of Sensitive Ground Fault Detection................................................................ 1552.11.1.1 Voltage Element ................................................................................................................. 1552.11.1.2 Current Elements................................................................................................................ 1562.11.1.3 Determination of Direction .................................................................................................. 1562.11.1.4 Location of Ground Connections........................................................................................ 160

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2.11.2 Programming Settings ........................................................................................................ 1612.11.2.1 General Settings................................................................................................................. 1612.11.2.2 Definite Current Stage (50Ns-2, 50Ns-1)............................................................................ 1622.11.2.3 Inverse Current Stage (51Ns)............................................................................................. 1622.11.2.4 Phase-to-Ground Voltage................................................................................................... 1642.11.2.5 Direction.............................................................................................................................. 1642.11.2.6 Current Transformer ........................................................................................................... 1662.11.2.7 Settings for Sensitive Ground Fault Detection.................................................................... 1662.11.2.8 Information List for Sensitive Ground Fault Detection ........................................................ 168

2.12 Intermittent Ground Fault Protection................................................................................... 1702.12.1 Functional Description ........................................................................................................ 1702.12.2 Functional Settings ............................................................................................................. 1752.12.2.1 Settings of the Intermittent Ground Fault Protection........................................................... 1762.12.2.2 Information List of the Intermittent Ground Fault Protection .............................................. 176

2.13 Automatic Reclosing System (79M).................................................................................... 1772.13.1 Description of Automatic Reclosing System....................................................................... 1772.13.1.1 General ............................................................................................................................... 1772.13.1.2 Program Execution ............................................................................................................. 1782.13.1.3 Controlling Protective Stages ............................................................................................. 1842.13.1.4 Zone Sequence Coordination1) .......................................................................................... 186

2.13.2 Programming Settings ........................................................................................................ 1882.13.2.1 General Settings................................................................................................................. 1882.13.2.2 Configuration ...................................................................................................................... 1902.13.2.3 First Reclosing Attempt....................................................................................................... 1912.13.2.4 Second to Fourth Reclosuring Attempt............................................................................... 1912.13.2.5 Fifth to Ninth Reclosing Attempt ......................................................................................... 1922.13.2.6 Blocking .............................................................................................................................. 1922.13.2.7 Zone Sequencing1)............................................................................................................. 1932.13.2.8 Controlling Directional/Non-Directional Overcurrent Protection Stages via

Cold Load Pickup................................................................................................................ 1932.13.2.9 Settings for Automatic Reclosing........................................................................................ 1942.13.2.10Information List for Automatic Reclosing ............................................................................ 199

2.14 Fault Location ..................................................................................................................... 2012.14.1 Description of Fault Location .............................................................................................. 2012.14.2 Setting The Functional Parameters .................................................................................... 2032.14.2.1 Settings for Fault Locator.................................................................................................... 2042.14.2.2 Information List for Fault Location ...................................................................................... 204

2.15 Breaker Failure Protection (50BF) ...................................................................................... 2052.15.1 Description of Breaker Failure Protection ........................................................................... 2052.15.2 Programming Settings ........................................................................................................ 2082.15.2.1 Settings for Breaker Failure Protection .............................................................................. 2092.15.2.2 Information List for Breaker Failure Protection ................................................................... 209

2.16 Synchronism and Voltage Check (7SJ64 only) .................................................................. 2102.16.1 Functional Description ........................................................................................................ 2102.16.2 Functional Settings ............................................................................................................. 2172.16.2.1 General Settings................................................................................................................. 2172.16.2.2 Power System Data ............................................................................................................ 2192.16.2.3 Asynchronous Conditions................................................................................................... 221

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2.16.2.4 Synchronous Conditions..................................................................................................... 2212.16.2.5 Synchrocheck..................................................................................................................... 222

2.16.3 Settings .............................................................................................................................. 2222.16.4 List of Information............................................................................................................... 224

2.17 Temperature Detection via RTD-boxes.............................................................................. 2262.17.1 Functional Description........................................................................................................ 2262.17.2 Configuration Notes............................................................................................................ 2272.17.2.1 Settings .............................................................................................................................. 2292.17.2.2 List of Information............................................................................................................... 233

2.18 Phase Rotation................................................................................................................... 2352.18.1 Description of Phase Rotation ............................................................................................ 2352.18.2 Programming Settings........................................................................................................ 235

2.19 Protection Function Logic ................................................................................................... 2362.19.1 Pickup Logic for the Entire Device...................................................................................... 2362.19.2 Tripping Logic of the Entire Device..................................................................................... 2362.19.2.1 Description ......................................................................................................................... 2362.19.2.2 Programming Settings for Tripping Logic ........................................................................... 237

2.19.3 Statistical Counters............................................................................................................. 2372.19.3.1 Description ......................................................................................................................... 2372.19.3.2 Reading/Setting/Resetting.................................................................................................. 238

2.20 Auxiliary Functions ............................................................................................................. 2392.20.1 Message Processing .......................................................................................................... 2392.20.1.1 Event Log (Operating messages)....................................................................................... 2402.20.1.2 Trip Log (Fault messages).................................................................................................. 2402.20.1.3 Ground Fault Messages ..................................................................................................... 2412.20.1.4 General Interrogation ......................................................................................................... 2412.20.1.5 Spontaneous Messages..................................................................................................... 2412.20.1.6 Statistics ............................................................................................................................. 242

2.20.2 Measurements.................................................................................................................... 2422.20.3 Commissioning Aids........................................................................................................... 2452.20.3.1 Test Messages to the SCADA Interface during Test Operation ......................................... 2452.20.3.2 Testing System Ports ......................................................................................................... 2462.20.3.3 Checking the Binary Inputs and Outputs............................................................................ 2462.20.3.4 Triggering Oscillographic Recordings................................................................................. 246

2.20.4 Programming Settings........................................................................................................ 2472.20.4.1 Settings for Auxiliary Functions .......................................................................................... 2472.20.4.2 Information List for Auxiliary Functions............................................................................... 248

2.21 Breaker Control .................................................................................................................. 2522.21.1 Types of Commands .......................................................................................................... 2532.21.2 Steps in the Command Sequence...................................................................................... 2542.21.3 Interlocking ......................................................................................................................... 2552.21.3.1 Interlocked/Non-Interlocked Switching ............................................................................... 255

2.21.4 Recording and acknowledgement of commands................................................................ 262

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3 Installation and Commissioning..................................................................................................... 265

3.1 Installation and Connections............................................................................................... 2663.1.1 Installation .......................................................................................................................... 2663.1.2 Connections........................................................................................................................ 2753.1.2.1 Connection Examples for 7SJ62 ........................................................................................ 2753.1.2.2 Connection Examples for 7SJ63 ........................................................................................ 2753.1.2.3 Connection Examples for 7SJ64 ........................................................................................ 2763.1.2.4 General Connections for 7SJ62/63/64................................................................................ 276

3.1.3 Hardware Modifications ...................................................................................................... 2793.1.3.1 General ............................................................................................................................... 2793.1.3.2 Disassembly of the Device ................................................................................................. 2813.1.3.3 Jumper Settings on Printed Circuit Boards of 7SJ62.......................................................... 2883.1.3.4 Switching Elements on the Printed Circuit Boards of 7SJ63 .............................................. 2943.1.3.5 Switching Elements on the Printed Circuit Boards of 7SJ64 .............................................. 3023.1.3.6 Interface Modules ............................................................................................................... 3133.1.3.7 Reassembly of Device ........................................................................................................ 317

3.2 Checking Connections........................................................................................................ 3183.2.1 Data Connections ............................................................................................................... 3183.2.2 Checking Power Plant Connections ................................................................................... 321

3.3 Commissioning ................................................................................................................... 3233.3.1 Testing mode and transmission blocking............................................................................ 3243.3.2 Checking the System (SCADA) Interface........................................................................... 3243.3.3 Checking the Binary Inputs and Outputs ............................................................................ 3263.3.4 Tests for the Circuit Breaker Failure Protection.................................................................. 3293.3.5 Testing User-Defined Functions ......................................................................................... 3303.3.6 Current, Voltage, and Phase Rotation Testing ................................................................... 3313.3.7 Testing the Reverse Interlocking Scheme (if applicable).................................................... 3323.3.8 Directional Checks with Load Current ................................................................................ 3333.3.9 Polarity check for the voltage input U4 (only 7SJ64) .......................................................... 3343.3.10 Ground Fault Check in a Non-Grounded System............................................................... 3363.3.11 Polarity Check for the Current Measuring Input IN............................................................................... 337

3.3.12 Checking the Temperature Measurement via RTD-Box..................................................... 3393.3.13 Measuring the operating time of the circuit breaker (only 7SJ64) ...................................... 3413.3.14 Switching Check for the Configured Operating Devices..................................................... 3413.3.15 Triggering Oscillographic Recordings................................................................................. 342

3.4 Final Preparation of the Device .......................................................................................... 344

4 Technical Data.................................................................................................................................. 345

4.1 General Device Data .......................................................................................................... 3464.1.1 Analog Inputs...................................................................................................................... 3464.1.2 Power Supply...................................................................................................................... 3464.1.3 Binary Inputs and Outputs .................................................................................................. 3474.1.4 Communications Interfaces ................................................................................................ 3494.1.5 Electrical Tests ................................................................................................................... 3534.1.6 Mechanical Stress Tests..................................................................................................... 355

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4.1.7 Climatic Stress Tests.......................................................................................................... 3564.1.8 Service Conditions.............................................................................................................. 3564.1.9 Certifications....................................................................................................................... 3574.1.10 Construction ....................................................................................................................... 357

4.2 Definite-Time Overcurrent Protection (50 and 50N Elements) ........................................... 359

4.3 Inverse-Time Overcurrent Protection (51 and 51N Elements) ........................................... 360

4.4 Directional Time Overcurrent Protection (67 and 67N Elements) ...................................... 370

4.5 Inrush Restraint .................................................................................................................. 371

4.6 Dynamic Cold Load Pick-up Function (50c, 50Nc, 51Nc, 67c, 67Nc) ................................ 371

4.7 Voltage Protection (27 and 59)........................................................................................... 372

4.8 Negative Sequence Protection (46).................................................................................... 3734.8.1 Definite–Time Elements (46-1 and 46-2)............................................................................ 3734.8.2 Inverse–Time Elements (46-TOC)...................................................................................... 373

4.9 Motor Starting Protection (48) ............................................................................................ 379

4.10 Start Inhibit for Motors (66/68)............................................................................................ 380

4.11 Frequency Protection (81 Over-Frequency and Under-Frequency) ................................... 381

4.12 Thermal Overload Protection (49) ...................................................................................... 382

4.13 Sensitive Ground Fault Detection (64, 50Ns, 67Ns)........................................................... 384

4.14 Intermittent Ground Fault Protection .................................................................................. 387

4.15 Automatic Reclosing System (79M) ................................................................................... 388

4.16 Fault Location..................................................................................................................... 389

4.17 Breaker Failure Protection (50BF)...................................................................................... 389

4.18 Synchronism and Voltage Check (25) (7SJ64 only)........................................................... 390

4.19 RTD-Boxes for Temperature Detection ............................................................................. 391

4.20 User Defined Functions with CFC ...................................................................................... 392

4.21 Additional Functions ........................................................................................................... 395

4.22 Breaker Control .................................................................................................................. 399

4.23 Dimensions......................................................................................................................... 400

A Appendix .......................................................................................................................................... 409

A.1 Ordering Information and Accessories ............................................................................... 410A.1.1 Ordering Information 7SJ62 V4.4 (present release .../EE and higher) ............................... 410A.1.2 Ordering Information 7SJ62 V4.2 (releases to date until .../DD) ........................................ 413A.1.3 Ordering Information 7SJ63 V4.4 (present release .../EE and higher) ............................... 415A.1.4 Ordering Information 7SJ63 V4.2 (releases to date until .../DD) ........................................ 418

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A.1.5 Ordering Information 7SJ64 V4.4 ....................................................................................... 420A.1.6 Accessories ........................................................................................................................ 423

A.2 Elementary Diagrams ......................................................................................................... 426A.2.1 Elementary Diagrams for 7SJ62......................................................................................... 426A.2.1.1 Housing for panel flush mounting or cubicle installation..................................................... 426A.2.1.2 Panel Surface Mounting ..................................................................................................... 428

A.2.2 Elementary Diagrams for 7SJ63......................................................................................... 432A.2.2.1 Housing for panel flush mounting or cubicle installation..................................................... 432A.2.2.2 Housing for panel surface mounting ................................................................................... 437A.2.2.3 Devices With Detached Operation Unit .............................................................................. 446A.2.2.4 Devices for panel surface mounting without Operation Unit............................................... 451

A.2.3 Elementary Diagrams for 7SJ64......................................................................................... 456A.2.3.1 Housing for panel flush mounting or cubicle installation..................................................... 456A.2.3.2 Housing for panel surface mounting ................................................................................... 460A.2.3.3 Housing for Mounting with Detached Operator Panel ........................................................ 464A.2.3.4 Devices for panel surface mounting without Operator Panel.............................................. 467

A.3 Connection Examples......................................................................................................... 470A.3.1 Connection Examples for 7SJ62 ........................................................................................ 470A.3.2 Connection Examples for 7SJ63 ........................................................................................ 476A.3.3 Connection Examples for 7SJ64 ........................................................................................ 484A.3.4 Connection Examples for RTD-Box.................................................................................... 493

A.4 Default Settings .................................................................................................................. 494A.4.1 LED Displays ...................................................................................................................... 494A.4.2 Binary Inputs....................................................................................................................... 494A.4.3 Binary Outputs .................................................................................................................... 496A.4.4 Function Keys..................................................................................................................... 497A.4.5 Standard Default Display .................................................................................................... 498A.4.6 Spontaneous Display Annunciations .................................................................................. 499A.4.7 Pre-Defined CFC Charts..................................................................................................... 500

A.5 Interoperability List.............................................................................................................. 503

A.6 Protocol-dependent functions............................................................................................. 505

A.7 Functions Overview ............................................................................................................ 506

A.8 Settings............................................................................................................................... 508

A.9 Overview of the masking features of the user defined information..................................... 541

A.10 Information List ................................................................................................................... 545

A.11 Measured Values................................................................................................................ 582

Index.................................................................................................................................................. 589

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Introduction 1The SIPROTEC® 4 7SJ62/63/64 devices are introduced in this section. An overviewof the devices is presented in their application, characteristics, and scope of functions.

1.1 Overall Operation 2

1.2 Applications 6

1.3 Characteristics 9

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Introduction

1.1 Overall Operation

The SIPROTEC® 4 7SJ62/63/64 are numerical, multi-functional, protective and con-trol devices equipped with a powerful microprocessor. All tasks, such as the acquisi-tion of the measured quantities, issuing of commands to circuit breakers and other pri-mary power system equipment, are processed in a completely digital way. Figure 1-1illustrates the basic structure of the devices 7SJ62/63, Figure 1-1 illustrates the basicstructure of the device 7SJ64.

Analog Inputs The measuring inputs (MI) section consists of current and voltage transformers. Theyconvert the signals from the measuring transducers to levels appropriate for the inter-nal processing of the device.

Four current inputs are available in the MI section. Three inputs are used for measur-ing of the phase currents. The use of the fourth input depends on the version of thedevice ordered. The fourth input can be used for measuring the ground current as theresidual of the phase current transformers (In), or for measuring the ground currentfrom a separate current transformer (INs/3I0). The latter is used in a highly sensitive

µC

A

D

ERROR

RUN

OutputRelays, User-Programmable

LEDson the FrontPanel, User-Programmable

Display onthe Front Panel

FrontPC Port

ToPC

SystemSerial Interface

ToSCADA

Ia

Ib

Ic

In / INs

Va

Vb

Vc / 3V0

7 8 94 5 6

1 2 3. 0 +/-

ESC ENTER

OperatorControl Panel

Uaux.

Binary Inputs,

Power Supply

RearService Port

MI IA AD µC AV

Figure 1-1 Hardware Structure of the Numerical Device 7SJ62/63

Status

PC/Modem/RTD-Box

Programmable

CTRL

TimeSynchronization

DCF 77/IRIG B

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Overall Operation

ground fault protective scheme (INs) or as a polarizing 3I0 current to determine the faultdirection.

The 7SJ62/63 has three voltage inputs in the MI section. The inputs can either be usedto measure the three phase-ground voltages, or two phase-phase voltages and 3V0from, for example, open delta voltage transformers. Displacement voltage is anotherterm used for 3V0. It is also possible to connect two phase-to-phase voltages in open-delta connection.

The 4 voltage transformers of 7SJ64 can either be applied for the input of 3 phase-ground voltages, one displacement voltage Uen or a further voltage for the synchroniz-ing function.

The analog input quantities from the MI stage are passed on to the input amplification(IA) stage, which provides high-resistance terminations for the analog quantities. TheIA stage consists of filters for processing the measured values. The filters are opti-mized with regard to bandwidth and processing speed.

µC

A

D

ERROR

RUN

OutputRelays, User-Programmable

LEDson the FrontPanel, User-Programmable

Display onthe Front Panel

FrontPC Port

ToPC

SystemSerial Interface

ToSCADA

Ia

Ib

Ic

In / INs

Va

Vb

Vc

7 8 94 5 6

1 2 3. 0 +/-

ESC ENTER

OperatorControl Panel

Uaux.

Binary Inputs,

Power Supply

RearService Port

MI IA AD µC AV

Figure 1-2 Hardware Structure of the Numerical Device 7SJ64

Status

PC/Modem/RTD-Box

Programmable

CTRL

TimeSynchronization

DCF 77/IRIG B

Vsyn/3V0

AdditionalPort RTD-Box

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Introduction

The analog-to-digital (AD) stage consists of memory components, a multiplexer, andan analog-to-digital (A/D) converter. The A/D converter processes the analog signalsfrom the IA stage. The digital signals from the converter are input to the microcomputersystem where they are processed as numerical values in the residing algorithms.

MicrocomputerSystem

The actual protection and control functions of the 7SJ62/63/64 are processed in themicrocomputer system (µC). In addition, the µC controls the measured quantities.Specifically, the µC performs:

− Filtering and preparation of the measured quantities

− Continuous monitoring of the measured quantities

− Monitoring of the pickup conditions for the individual elements and functions

− Evaluation of limit values and sequences in time

− Control of signals for the logic functions

− Decision for trip, close, and other control commands

− Output of control commands for switching devices (output contacts)

− Recording of messages and data for events, alarms, faults, and control actions, andprovision of their data for analysis

− Management of the operating system and the associated functions such as data re-cording, real-time clock, communications, interfaces, etc.

Binary Inputs andOutputs

The µC obtains external information through the binary inputs such as blocking com-mands for protective elements or position indications of circuit breakers. The µC is-sues commands to external equipment via the output contacts. These output com-mands are generally used to operate circuit breakers or other switching devices. Theycan also be connected to other protective devices, annunciators, or external carrierequipment for use in Pilot-Relaying schemes.

Front Elements The devices with integrated or detached operator panel light-emitting diodes (LEDs)and a display screen (LCD) on the front panel providing information such as messagesrelated to events and functional status of the device.

Integrated control and numeric keys in conjunction with the LCD facilitate local inter-action with the 7SJ62/63/64. All information of the device can be accessed using theintegrated control and numeric keys. The information includes protective and controlsettings, operating and fault messages, and metering values (see also Chapter 2).The settings can be modified; the procedures are discussed in Chapter 2. In addition,control of circuit breakers and other equipment is possible from the 7SJ62/63/64 frontpanel.

Serial Interfaces A serial PC Port on device is provided for local communications with the 7SJ62/63/64 through a personal computer. Convenient operation of all functions of the device ispossible. The operating program DIGSI® 4 is required which facilitates a comfortablehandling of all device functions.

A separate Service Port can be provided for remote communications via a modem,or substation computer. The operating program DIGSI® 4 is required. This port is es-pecially well suited for the fixed wiring of the devices to the PC or operation via a mo-

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Overall Operation

dem. The service port can also be used to connect a RTD-Box (= resistance temper-ature detector) for entering external temperatures (e.g. for overload protection).

The additional port (only 7SJ64) is exclusively designed for the connection of a RTD-Box (= resistance temperature detector) for entering external temperatures.

All 7SJ62/63/64 data can be transferred to a central control and monitor system (RTU/SCADA) through the Scada Port. Various protocols and physical interfaces are avail-able to suit the particular application.

A further port is provided for the time synchronization of the internal clock via externalsynchronization sources.

Further communications protocols can be realized via additional interface modules.

Power Supply The 7SJ62/63/64 can be supplied with any of the common power supply voltages from24 VDC to 250 VDC. The device can also be supplied with 115 VAC. Momentary dipsof the supply voltage up to 50 ms are bridged by a capacitor (see Technical Data, Sub-section 4.1). Voltage dips can occur, for example, if the voltage supply system (sub-station battery) becomes short-circuited or experiences a severe variation in load.

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Introduction

1.2 Applications

The numerical, multi-functional SIPROTEC® 4 7SJ62/63/64 are versatile devices de-signed for many applications. The 7SJ62/63/64 can be used as protective, control,and monitoring devices for distribution feeders and transmission lines of any voltagein networks that are grounded, low-resistance grounded, ungrounded, or of a compen-sated neutral point structure. The devices are suited for networks that are radial orlooped, and for lines with single or multi-terminal feeds. The 7SJ62/63/64 areequipped with motor protection applicable for asynchronous machines of all sizes.

The 7SJ62/63/64 includes the functions that are necessary for protection, monitoringof circuit breaker positions, and control of the circuit breakers in straight bus applica-tions or breaker-and-a-half configurations; therefore, the devices can be universallyemployed. The 7SJ62/63/64 provides excellent backup facilities of differential protec-tive schemes of lines, transformers, generators, motors, and busbars of all voltage lev-els.

ProtectiveFunctions

Non-directional overcurrent protection (50, 50N, 51, 51N) is the basis of the 7SJ62/63/64. Four definite-time overcurrent protective elements exist, two for the phase and twofor the ground (50 and 50N) currents. The elements can be set with no time delay,where instantaneous tripping is desired. Inverse-time overcurrent protective elementsare also available for both the phase and the ground (51 and 51N) currents. The com-mon U.S. ANSI time-characteristics are also available. Alternatively, user-definedcharacteristics can be programmed or IEC characteristics can be selected.

Depending on the version of the device that is ordered, the non-directional overcurrentprotection can be supplemented with directional overcurrent protection (67, 67N),breaker failure protection (50BF), and sensitive ground fault detection for high-resis-tance ground faults or systems that are resistively grounded (50 Ns, 67Ns). The highlysensitive ground fault detection can be directional or non-directional.

Other protective functions are available, some of which depend on the version of thedevice that is ordered. These additional functions include negative sequence (phasebalance) current protection (46), automatic reclosing (79), thermal overload protection(49), overvoltage protection (59), undervoltage protection (27), and over/under fre-quency protection (81O/U). For motor protection, starting time supervision (48), startinhibit (66/68), and undercurrent monitoring (37) are optionally available. Finally, the7SJ62/63/64 is equipped with a fault locator.

A protection feature can be ordered for the detection of intermittent ground faultswhich detects and accumulates transient ground faults.

External detectors account for ambient temperatures or coolant temperatures (bymeans of an external RTD-box).

Before reclosing after three-pole tripping 7SJ64 can verify the validity of the reclosureby voltage check and/or synchronous check. The synchronization function can also becontrolled externally.

Control Functions The 7SJ62/63/64 supports all control and monitoring functions that are required for op-erating medium to high-voltage substations. A major application is the reliable controlof switchgear or circuit breakers. Such control can be accomplished via the integratedoperator panel, the system interface, the binary inputs, and the serial port using a per-sonal computer with DIGSI® 4.

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Applications

The status of the primary equipment or auxiliary devices can be transmitted to the7SJ62/63/64 via auxiliary contacts connected to binary inputs. The present status (orposition) of the primary equipment can be displayed on the 7SJ62/63/64, and used forinterlocking or, if applicable, plausibility monitoring. Only the quantity of binary inputsand outputs available in the 7SJ62/63/64 limits the number of primary devices that canbe operated. Depending on the primary equipment being controlled, one binary input(single indication) or two binary inputs (double indication) can be used in the positionmonitoring process.

The capability of switching primary equipment can be restricted by a setting associat-ed with switching authority – Local, DIGSI® 4 PC, or Remote, and by the operatingmode – Interlocked or Non-Interlocked, with password request. Processing of inter-locking conditions for switching (e.g. switching error protection) can be establishedwith the aid of integrated, user-configurable logic functions.

Messages andMeasured Values;Recording of Eventand Fault Data

The operating messages provide information about conditions in the power systemand the 7SJ62/63/64. Measurement quantities and values that are calculated can bedisplayed locally and communicated via the serial interfaces.

Messages of the 7SJ62/63/64 can be indicated by a number of programmable LEDson the front panel, externally processed through programmable output contacts, andcommunicated via the serial interfaces (see Communication below).

Important events and changes in conditions are saved under Annunciation in theEvent Log or the Trip Log, the latter being used for faults. Waveform capture is avail-able, as an option.

Communication Serial interfaces are available for communications with PC’s, RTU’s, and SCADA sys-tems.

A 9-pin D-subminiature female connector on the front panel is used for local commu-nications with a personal computer. DIGSI® 4 software is required to communicate viathis port. Using the DIGSI® 4 software, settings and configuration can be made to therelay, Realtime operating quantities can be viewed, Waveform capture and Event Logrecords can be displayed, and controls can be issued.

A DIGSI® 4 service interface port, a system (SCADA) port and a time-sync port (IRIG-B or DCF77) are optionally available on the rear of the device.

A rear service interface can be supplied as RS-232, RS-485, or multimode fiber opticstype ST. DIGSI® 4 software is required to communicate via this port.

The additional port (only 7SJ64) is designed exclusively for connection of a RTD-Box(= resistance temperature detector) for entering external temperatures. It can also beoperated via data lines or fibre optic cables.

A rear system interface can be supplied as RS-232, RS-485, or multimode fiber opticstype ST for communications between the 7SJ62/63/64 and a PC’s, RTU’s, or SCADAsystems Standard Protocols, IEC 60870–5–103 are available via the system port. In-tegration of the devices into the automation systems SINAUT® LSA and SICAM® alsotake place with this profile.

Alternatively, a field bus coupling with PROFIBUS FMS is available for the 7SJ62/63/64. The PROFIBUS FMS is performed in accordance with IEC 61850, is an open com-munications standard that particularly has wide acceptance in process control and au-tomation engineering, with especially high performance. A profile has been defined forthe PROFIBUS communication that covers all of the information types required for

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Introduction

protective and process control engineering. The integration of the devices into the en-ergy automation system SICAM® can also take place with this profile.

Besides the field-bus connection with PROFIBUS FMS, further couplings are possiblewith PROFIBUS DP and the protocols DNP3.0 and MODBUS. These protocols do notsupport all possibilities which are offered by PROFIBUS FMS.

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Characteristics

1.3 Characteristics

GeneralCharacteristics

• Powerful 32-bit microprocessor system.

• Complete digital processing and control of measured values, from the sampling ofthe analog input quantities to the initiation of outputs for, as an example, tripping orclosing circuit breakers or other switchgear devices.

• Total electrical separation between the processing stages of the 7SJ62/63/64 andthe external transformer circuits, control circuits, and DC supply circuit because ofthe design of the binary inputs, outputs, and the DC converters.

• Complete set of functions necessary for the proper protection of lines, feeders, mo-tors, and busbars.

• Easy devise operation through an integrated operator panel or by means of a con-nected personal computer running DIGSI® 4.

• Continuous calculation and display of measured quantities on the front of the de-vice.

• Storage of min/max measured values (slave pointer function) and storage of long-term mean values;

• Recording of event data, fault data, and waveform captures with SER informationto be used for analysis and troubleshooting.

• Constant monitoring of the measurement quantities, as well as continuous self-di-agnostics covering the hardware and software.

• Communication with SCADA or substation controller equipment via serial interfacesthrough the choice of data cable, modem, or optical fibers.

• Battery-buffered clock that can be synchronized with an IRIG-B (or DCF77) signal,binary input signal, or system interface command;

• Recording of circuit breaker statistics including the number of trip signals sent andthe accumulated, interrupted currents of each pole of the circuit breaker;

• Tracking of operating hours (time when load is supplied) of the equipment beingprotected;

• Commissioning aids such as connection check, direction determination, status in-dication of all binary inputs/outputs and display of test recordings.

Time-OvercurrentProtection

• Two instantaneous (Definite-Time) overcurrent elements and an inverse-time over-current element, for both phase protection and ground protection (50-1, 50-2, 51,50N-1, 50N-2, and 51N);

• The 50 and 50N elements can be set with definite-time delay;

• Common ANSI and IEC time overcurrent curves are available for 51 and 51N, oruser defined characteristics can be employed.

• Blocking capability for reverse-interlocking busbar protection, or directional com-parison line protection;

• Second harmonic inrush restraint of 50, 50N, 51, and 51N for transformer energiz-ing;

• Instantaneous tripping by any overcurrent element upon manual closure of a circuitbreaker, if selected (Switch-Onto-Fault-Protection).

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Introduction

Directional Time-OvercurrentProtection

• Three directional time-overcurrent elements for both phase protection and groundprotection (67-1, 67-2, 67-TOC, 67N-1, 67N-2, and 67N-TOC). The 67 and 67N el-ements can have instantaneous or definite-time tripping. The 67-TOC and 67N-TOC elements have inverse-time characteristics. The directional time-overcurrentelements are independent of the non-directional time-overcurrent elements;

• Fault direction is calculated for each phase and direction is determined indepen-dently for phase faults (using phase-phase voltage opposite of the current beingcompared) and for ground faults (using zero sequence quantities).

Dynamic Cold LoadSetting Adjustment

• Dynamic adjustments of the pickup values and the tripping times of both the direc-tional and non-directional time-overcurrent functions when cold load conditions areanticipated;

• Cold load conditions are anticipated when the circuit breaker has been in the openposition for an extended period of time. Circuit breaker position is determined byauxiliary contacts or the state of a sensitive overcurrent element.

• Activation via automatic reclosure (AR) possible;

• Start also possible via binary input.

Voltage Protection • Two undervoltage elements 27-1 and 27-2 measuring positive sequence voltage;

• Choice of current supervision for 27-1 and 27-2;

• Adjustable dropout voltage for 27-1;

• Separate two overvoltage elements 59-1 and 59-2.

Negative SequenceCurrent Protection

• Two definite-time elements 46-1 and 46-2 and one inverse-time element 46-TOC;

• Common U.S. ANSI time-characteristics or IEC characteristics are available for 46-TOC.

Starting TimeMonitoring forMotors

• Current dependent tripping based on an evaluation of the motor starting current.

• Blocked rotor protection.

Start Inhibitfor Motors

• Rotor temperature is calculated based on the stator currents;

• Start-up is permitted only if the rotor has sufficient thermal reserves for a completestart-up;

• Disabling of the start inhibit is possible if an emergency start-up is required.

FrequencyProtection

• Four elements that are independently adjustable for function - underfrequency oroverfrequency, pickup, and time delay;

• Insensitive to harmonics and abrupt phase angle changes;

• Adjustable undervoltage blocking.

Thermal OverloadProtection

• Temperature rise of the protected equipment is calculated using a thermal homo-geneous-body model that takes into account energy entering the equipment andenergy losses. Thermal overload protection has full memory capability;

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Characteristics

• True r.m.s. calculation;

• Adjustable warning levels based on temperature rise and current magnitude;

• Additional time constant setting for motors to accommodate both the motor rotatingand the motor at standstill.

• Integration of ambient temperature or coolant temperature is possible via externaltemperature sensors and RTD-Box.

MonitoringFunctions

• Availability of the 7SJ62/63/64 is greatly increased because of self-monitoring ofthe internal measurement circuits, power supply, hardware, and software;

• Current transformer and voltage transformer secondary circuits are monitored us-ing summation and symmetry check techniques;

• Trip circuit monitoring;

• Phase rotation.

Sensitive GroundFault Detection

• Ideal for sensing a grounded phase on ungrounded networks;

• Displacement voltage (3V0) is calculated from the measurements of the threephase-ground voltages, or measured from the output of, for example, voltage trans-formers connected in a open delta configuration;

• Ground fault detection optionally with high sensitivity or for large current range;

• Two sensitive ground fault instantaneous overcurrent elements 50Ns-1 and 50Ns-2 that can have definite time delay;

• Pickup currents of 50Ns-1 and 50Ns-2 are adjustable and can be set very sensitive(as low as 1 mA);

• Sensitive ground fault time-overcurrent element 51Ns is available instead of 50Ns-1, if selected;

• Time-current characteristic curve for 51Ns is defined by the user;

• Two ground fault elements 67Ns-1 and 67Ns-2 that can be set as non-directional,forward sensing directional, or reverse sensing directional;

• Fault direction is determined by calculating the zero sequence real power or reac-tive power, as determined by a setting;

• Directional characteristics of 67Ns-1 and 67Ns-2 are adjustable;

• Optionally applicable as additional ground fault protection.

IntermittentGroundFault Protection

• Detects and accumulates intermittent ground faults;

• Tripping after configurable total time.

AutomaticReclosing

• Single-shot or multi-shot;

• Dead times associated with the first, second, third, and fourth shots are program-mable and can be different from one another. Dead times for the remaining shotsare identical to the dead time for the fourth shot;

• Protective elements that initiate automatic reclosing are selectable. The choicescan be different for phase faults and ground faults;

• Different programs for phase and ground faults;

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Introduction

• Monitoring of the circuit breaker response during reclosing sequence is possible.

• Interaction to time overcurrent protection stages and ground fault stages. They canbe blocked in dependence of the reclosing cycle or released instantaneously;

• Synchronous reclosing is possible (only 7SJ64) in combination with the integratedsynchronizing feature.

Fault Location • Triggers include a trip command, reset of the trip command, operation of a protec-tive element, and an external command via a binary input;

• Fault distance is calculated and given in secondary ohms, miles, or kilometers.

Breaker FailureProtection

• Breaker failure condition determined by current flow and/or evaluation of the circuitbreaker auxiliary contacts after a trip signal has been issued;

• Breaker failure protection initiated by the tripping of any integrated protective ele-ment that trips the circuit breaker (internal start);

• Initiation possible through a binary input from an external protective device (exter-nal start);

• Initiation possible through the integrated control function (control start).

SynchronizingFunction (only7SJ64)

• Verification of the synchronous conditions before reclosing after three-pole tripping;

• Fast measurement of the voltage difference ∆U, the phase angle difference ∆ϕ andthe frequency difference ∆f;

• Alternatively, check of the de-energized state before reclosing;

• Switching possible for asynchronous system conditions with prediction of the syn-chronization time;

• Settable minimum and maximum voltage;

• Verification of the synchronous conditions or de-energized state also possible be-fore the manual closing of the circuit breaker, with separate limit values;

• Measurement also possible via transformer without external intermediate matchingtransformer;

• Measuring voltages optionally phase–phase or phase–ground.

RTD-Boxes • Detection of any ambient temperatures or coolant temperatures by means of RTD-Boxes and external temperature sensors.

Phase Rotation • Selectable ABC or ACB with a setting (static) or binary input (dynamic).

User-definedFunctions

• Internal and external signals can be logically combined to establish user-definedlogic functions;

• All common logic functions are available for programming (AND, OR,NOT, Exclu-sive OR, etc.);

• Time delays and limit value inquiries are available;

• Processing of measured values, including zero suppression, adding a knee charac-teristic for a transducer input, and live-zero monitoring.

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Characteristics

Breaker Control • Circuit breakers can be opened and closed via the process control keys (modelswith graphic displays only) or the programmable function keys on the front panel,through the SCADA, or through the front PC interface using a personal computerwith DIGSI® 4;

• Circuit breakers are monitored via the breaker auxiliary contacts;

• Plausibility monitoring of the circuit breaker position and check of interlocking condi-tions.

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Functions 2This chapter describes the numerous functions available on the SIPROTEC® 7SJ62/63/64 relay. The setting options for each function are defined, including instructions forreporting setting values and formulas where required.

2.1 General 17

2.2 Overcurrent Protection (50, 50N, 51, 51N) 38

2.3 Directional Overcurrent Protection (67, 67N) 64

2.4 Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc) 87

2.5 Voltage Protection (27, 59) 94

2.6 Negative Sequence Protection (46) 104

2.7 Motor Protection (Motor Starting Protection, 48 and Start Inhibit for Motors,66/68) 112

2.8 Frequency Protection (81 O/U) 126

2.9 Thermal Overload Protection (49) 130

2.10 Monitoring Functions 140

2.11 Sensitive Ground Fault Detection (64, 50Ns, 67Ns) 155

2.12 Intermittent Ground Fault Protection 170

2.13 Automatic Reclosing System (79M) 177

2.14 Fault Location 201

2.15 Breaker Failure Protection (50BF) 205

2.16 Synchronism and Voltage Check (7SJ64 only) 210

2.17 Temperature Detection via RTD-boxes 226

2.18 Phase Rotation 235

2.19 Protection Function Logic 236

2.20 Auxiliary Functions 239

2.21 Breaker Control 252

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Functions

Regionalization The SIPROTEC® 7SJ62/63/64 devices are offered in regional versions. The preparedfunctions are adapted to the technical requirements of the regions. The user shouldpurchase only the functional scope that is needed.

Legend

(X) – Selectable Option

(–) – Function not available for this region

Table 2-1 Regionalization

Function Region DEGermany

Region WorldwideWorldwide

Region USUSA

Language German English American English

Frequency 50 Hz 50 Hz / 60 HzDefault 50 Hz

60 Hz

Unit of distance given byFault Locator

km km / MilesDefault km

Miles

Disk-emulation for resetcharacteristics of inversetime-overcurrent elements(emulation of(electromechanicalelements)

X for IEC- and ANSICurves

X

Characteristic curves forinverse time-overcurrentelements

IEC Curves

ANSI Curves

X

X

Default IECCharacteristic Curves

X

X

AutomaticReclosing

Automatic Reclosingwith zone sequencecoordination

X

X

X

Control Buttons on FrontPanel (7SJ63, 7SJ64)

Red, GreenControl Buttons

Red, Green ControlButtons

Gray ColoredControl Buttons

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General

2.1 General

The settings associated with the various device functions may be modified using thecontrols on the front panel of the device or by using the operator interface in DIGSI® 4in conjunction with a personal computer. The SIPROTEC® 4–System Manual gives adetailed description of the procedure. Therefore, it will only be described briefly here.Password No. 5 is required to modify individual settings.

From PC withDIGSI® 4

To select a function, the user should double-click on Settings, and then double-clickon the desired setting function (e.g. Power System Data 1 is selected by double-clicking Settings, and then double-clicking Power System Data 1 as illustratedin Figure 2-1).

Figure 2-1 Navigating Using DIGSI® 4 — Example

A dialog box associated with the selected function is displayed (e.g., if Power Sys-tem Data 1 function is selected, the dialog box shown in Figure 2-2 will appear). Ifa function contains many settings, the dialog box may include multiple windows. In thissituation, the user can select individual windows via tabs located at the top of the dia-log box (e.g., In Figure 2-2, tabs exist for Power System, CTs, VTs, and Break-er).

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Figure 2-2 Power System Data Dialog Box in DIGSI® 4 — Example

The left column of the dialog box (identified as the No. column) contains the four-digitaddress number of the setting. The middle column of the dialog box (identified as theSettings column) contains the title of the setting, and the right column of the dialogbox (identified as the Value column) contains the current value of the setting in textor numerical format. When the mouse cursor is positioned over a numerical field in theValue column, the allowable range is shown.

To modify a setting, the user must click on the setting value which is displayed in theValue column.

Text Values When a text setting value is selected, a pull-down menu of possible setting options isdisplayed. To modify the setting, the user simply clicks on the desired option. The pull-down menu closes, and the new setting value appears in the Value column.

Numerical Values(including ∞)

When a numerical setting value is selected, the setting is modified using the numberkeys, if applicable, with a decimal comma (not a decimal point). A value of “infinity”may be entered by pressing the small o key twice. The setting modification is con-firmed by clicking on Apply, or the user may select another setting to modify.

If the value entered is outside the allowable range, a message block appears on thescreen describing the error and displaying the acceptable range of values. To ac-knowledge the message, the user should click OK, and the original value reappears.A new entry can be made or another setting value can be modified.

Primary orSecondary Values

Setting values can be entered and displayed in primary terms or secondary terms, asdesired. DIGSI® 4 automatically performs the conversions. For this, the station datahave to be entered correctly.

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To switch between primary values and secondary values:

Click on Options in the menu bar, as shown in Figure 2-3.

Click on the desired alternative.

Figure 2-3 Selection of Primary or Secondary Value Entry — Example

Additional Settings Those settings that are modified only in special cases are typically hidden. They maybe made visible by checking on Display Additional Settings.

2.1.1 Configuration of Functions

General The 7SJ62/63/64 relay contains selectable protection functions as well as many otherfunctions, based on the options purchased. The first step in configuring the relay is todetermine which functions are required.

Example for the configuration of functional scope:

A protected system consists of overhead and underground feeders. Since automaticreclosing is only needed for the overhead feeders, the automatic reclosing function isnot configured or “Disabled” for the relays protecting the underground feeders.

The available functions must be configured as enabled or disabled. For individualfunctions, the choice between several alternatives may be presented, as describedbelow.

Functions configured as disabled are not processed by the 7SJ62/63/64. There areno messages, and corresponding settings (functions, limit values) are not displayedduring detailed settings.

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Determination ofFunctional Scope

Configuration settings must be entered using a PC and the software programDIGSI® 4 and transferred via the front serial port, or via the DIGSI® 4 serial port inter-face. Operation via DIGSI® 4 is described in the SIPROTEC® 4 System Manual.

Entry of password No. 7 (for setting modification) is required to modify configurationsettings (see Section 4). Without the password, the settings may be read, but may notbe modified and transmitted to the device.

The functional scope with the available alternatives is set in the Device Configu-ration dialog box to match equipment requirements.

SpecialCharacteristics

Most settings are self-explaining. Peculiarities will be explained in the following.

If use of the setting group change function is desired, address 0103 Grp Chge OP-TION should be set to Enabled. In this case, up to four different groups of settings(see Chapter 6) may be entered quickly and easily during device operation. Only onesetting group may be selected and used if the setting is Disabled.

For the relay elements associated with non-directional overcurrent protection (bothphase and ground), various tripping characteristics may be selected at the addresses0112 Charac. Phase and 0113 Charac. Ground. If only the definite time char-acteristic is desired, then Definite Time should be selected. Additionally, depend-ing on the relay model ordered, various inverse time characteristics are available(based on either IEC (TOC IEC) standards or ANSI (TOC ANSI) standards), or userdefined characteristics may be specified. The dropout behavior of the IEC and ANSIcurves will be specified later during the setting (addresses 1210 and 1310), however,for the user-defined characteristic you determine in address 0112 and 0113 whetherto specify only the pick-up characteristic (User Defined PU) or the pick-up and thedropout characteristic (User def. Reset).

The superimposed high-current stage 50-2 is available in all these cases. Non-direc-tional overcurrent protection may be defeated during configuration by selecting Dis-abled.

For directional overcurrent protection, the same information can be entered at ad-dresses 0115 67/67-TOC (phase) and 0116 67N/67N-TOC (ground) that was en-tered for the non-directional overcurrent protection at addresses 0112 and 0113.

For sensitive ground fault protection, address 0131 Sens. Gnd Fault is used tospecify whether the function should be Disabled, enabled with definite time trippingcharacteristics only (Definite Time), or enabled with a user defined inverse timecharacteristic (User Defined PU).

For the intermittent ground-fault protection specify in address 0133 INTERM.EF themeasured quantity (with Ignd, with 3I0 or with Ignd,sens.) which is to beused by this protection function.

For negative sequence protection, address 0140 46 is used to specify whether thefunction should be Disabled, enabled with Definite Time tripping characteristicsonly, or enabled with an inverse time characteristic (TOC IEC or TOC ANSI).

Note:

Available functions and default settings are depending on the ordering code of the re-lay (see table 2-1 and ordering code in the appendix for details).

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Set in address 0142 49 for the overload protection whether (With amb. temp.) ornot (No ambient temp) the thermal replica of the overload protection will accountfor a coolant temperature or ambient temperature or whether the entire function is setto Disabled.

Up to four function groups are available for the synchronizing function. They are en-abled in address 016x (x = 1 ... 4). Parameters 0161 25 Function 1 to 0164 25 Function 4 indicate whether a synchronizing function is to be Disabled or en-abled. The latter is determined by pre-selecting the operating mode ASYN/SYNCHRON(switching takes place for asynchronous and synchronous conditions) or SYNCHRO-CHECK (corresponds to the classical synchro-check function). The function groupswhich are configured to enabled via ASYN/SYNCHRON or SYNCHROCHECK are dis-played when you select the synchronizing function; function groups set to Disabledare hidden.

For trip circuit monitoring, address 00182 74 Trip Ct Supv is used to specifywhether two binary inputs should be utilized (2 Binary Inputs), one binary inputshould be utilized (1 Binary Input), or the function should be Disabled.

If you want to detect an ambient temperature or a coolant temperature and send theinformation to the overload protection, specify in address 0190 RTD-BOX INPUT theport to which the RTD-box is connected. For 7SJ62/63 Port C (service port) is usedfor this purpose, for 7SJ64 either Port C (service port) or Port D (additional port).The number and transmission type of the temperature detectors (RTD = ResistanceTemperature Detector) can be specified in address 0191 RTD CONNECTION: 6 RTD simplex or 6 RTD HDX (with one RTD-box) or 12 RTD HDX (with two RTD-boxes).Appendix A.3.4 gives design examples. The settings in address 0191 has to complywith those at the RTD-box (see Subsection 2.17.2).

Addr. Setting Title Setting Options Default Setting Comments

103 Grp Chge OPTION DisabledEnabled

Disabled Setting Group Change Option

104 OSC. FAULT REC. DisabledEnabled

Disabled Oscillographic Fault Records

112 Charac. Phase DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and Reset Curve

Definite Time only 50/51

113 Charac. Ground DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and Reset Curve

Definite Time only 50N/51N

115 67/67-TOC DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and Reset Curve

Definite Time only 67, 67-TOC

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116 67N/67N-TOC DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and Reset Curve

Definite Time only 67N, 67N-TOC

117 Coldload Pickup DisabledEnabled

Disabled Cold Load Pickup

122 InrushRestraint DisabledEnabled

Disabled 2nd Harmonic Inrush Res-traint

131 Sens. Gnd Fault DisabledDefinite Time onlyUser Defined Pickup Curve

Disabled sensitive Ground fault

133 INTERM.EF Disabledwith Ignd (measured)with 3I0 (calculated)with Ignd,sensitive (measured)

Disabled Intermittent earth fault protec-tion

140 46 DisabledTime Overcurrent Curve ANSITime Overcurrent Curve IECDefinite Time only

Disabled 46 Negative Sequence Pro-tection

141 48 DisabledEnabled

Disabled 48 Startup Supervision ofMotors

142 49 DisabledWithout ambient temperature measu-rementWith ambient temperature measure-ment

Disabled 49 Thermal Overload Protec-tion

143 66 #of Starts DisabledEnabled

Disabled 66 Startup Counter for Motors

150 27/59 DisabledEnabled

Disabled 27, 59 Under/OvervoltageProtection

154 81 O/U DisabledEnabled

Disabled 81 Over/Underfrequency Pro-tection

161 25 Function 1 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 1

162 25 Function 2 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 2

163 25 Function 3 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 3

164 25 Function 4 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 4

Addr. Setting Title Setting Options Default Setting Comments

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2.1.2 General Device Data

The device requires some general information such as the type of annunciation to beissued in the event a power system fault occurs.

The required data can be entered directly at the device if it features an integrated ordetached operator panel: Select the MAIN MENU by pressing the key. Using the

key, select Settings, and then press the key to navigate to the SETTINGSdisplay. There use the key to select the Device submenu.

Double-click SETTINGS in DIGSI® 4 and the corresponding menu appears. A dialogbox will open under the option Device in which you can configure the individual pa-rameters.

“No Trip – No Flag”Option

The indication of messages masked to local LEDs, and the maintenance of spontane-ous messages, can be made dependent on whether the device has issued a trip sig-nal. In this situation, messages are not reported, if one or more protective functionshave picked up on a fault, but a trip signal has not been issued yet by the device be-cause the fault was cleared by another device (for instance, in another line). Thesemessages are then limited to faults in the line to be protected.

Figure 2-4 shows the logic diagram for this function. When the relay drops off, station-ary conditions (fault display on every pickup/on trip only; trip/no trip) decide whetherthe new fault will be stored or reset.

170 50BF DisabledEnabled

Disabled 50BF Breaker Failure Protec-tion

171 79 Auto Recl. DisabledEnabled

Disabled 79 Auto-Reclose Function

180 Fault Locator DisabledEnabled

Disabled Fault Locator

182 74 Trip Ct Supv Disabledwith 2 Binary Inputswith 1 Binary Input

Disabled 74TC Trip Circuit Supervision

190 RTD-BOX INPUT DisabledPort CPort D (only 7SJ64)

Disabled External Temperature Input

191 RTD CONNEC-TION

6 RTD simplex operation6 RTD half duplex operation12 RTD half duplex operation

6 RTD simplex ope-ration

Ext. Temperature Input Con-nection Type

Addr. Setting Title Setting Options Default Setting Comments

MENU

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Figure 2-4 Generation of Reset Command for LED and LCD Display Memory

SpontaneousAnnunciations onthe Display

You can determine whether or not the most important data of a fault event is displayedautomatically after the fault has occurred (see also Subsection 2.20.1.2).

2.1.2.1 Setting Notes

Pickup of a new protective function generally turns off any previously set light displays,so that only the latest fault is displayed at any time. It can be selected whether thestored LED displays and the spontaneous messages on the display appear upon re-newed pickup, or only after a renewed trip signal is issued. In order to enter the desiredtype of display, select the sub-menu Device in the SETTINGS menu. The two alter-natives (Target on PU or Target on TRIP) are selected at address 0610 FltDisp.LED/LCD.

Use parameter 0611 Spont. FltDisp. to specify whether or not a spontaneousfault annunciation will appear on the display.

2.1.2.2 Information Overview

&

0610 FltDisp.LED/LCD

Relay TRIP

“1“

Trip Signal drop out

Reset LED und LCD-Messages

F# 00511

Targets on every PU

Targets on Trip only

Addr. Setting Title Setting Options Default Setting Comments

610 FltDisp.LED/LCD Display Targets on everyPickupDisplay Targets on TRIP only

Display Targets onevery Pickup

Fault Display on LED / LCD

611 Spont. FltDisp. YESNO

NO Spontaneous display offlt.annunciations

F.No. Alarm Comments

00003 >Time Synch >Synchronize Internal Real Time Clock

00005 >Reset LED >Reset LED

---- >Light on >Back Light on

00051 Device OK Device is Operational and Protecting

00052 ProtActive At Least 1 Protection Funct. is Active

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00055 Reset Device Reset Device

00056 Initial Start Initial Start of Device

00060 Reset LED Reset LED

00067 Resume Resume

00068 Clock SyncError Clock Synchronization Error

00069 DayLightSavTime Daylight Saving Time

00110 Event Lost Event lost

00113 Flag Lost Flag Lost

00125 Chatter ON Chatter ON

00140 Error Sum Alarm Error with a summary alarm

00160 Alarm Sum Event Alarm Summary Event

00178 I/O-Board error I/O-Board Error

00144 Error 5V Error 5V

00145 Error 0V Error 0V

00146 Error -5V Error -5V

00147 Error PwrSupply Error Power Supply

00177 Fail Battery Failure: Battery empty

00070 Settings Calc. Setting calculation is running

00071 Settings Check Settings Check

00072 Level-2 change Level-2 change

00073 Local change Local setting change

00183 Error Board 1 Error Board 1

00184 Error Board 2 Error Board 2

00185 Error Board 3 Error Board 3

00186 Error Board 4 Error Board 4

00187 Error Board 5 Error Board 5

00188 Error Board 6 Error Board 6

00189 Error Board 7 Error Board 7

00301 Pow.Sys.Flt. Power System fault

00302 Fault Event Fault Event

00303 sens Gnd flt sensitive Ground fault

---- DataStop Stop data transmission

00016 >DataStop >Stop data transmission

---- Test mode Test mode

F.No. Alarm Comments

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2.1.3 Power System Data 1

The device requires certain basic data regarding the protected equipment, so that thedevice will be compatible with its desired application. Phase sequence data, nominalsystem frequency data, CT&PT ratios and their physical connections, as well as,breaker operating times and minimum current thresholds are selected in the Power System Data 1 display.

To modify these settings from the front of the device, the user should press the keyand wait for the MAIN MENU to appear. From the MAIN MENU, the user should use the

key to select Settings, and then use the key to navigate to the SETTINGSdisplay. To obtain the P.System Data1 display, the user should use the key toselect P.System Data1 in the SETTINGS display, and then press the key.

To modify settings associated with Power System Data 1 using DIGSI® 4, the usershould double-click Settings, and then Power System Data 1, and the desiredselection options will be displayed. A dialog box opens under Power System Data 1 which contains the tabs “Power System”, “CT’s”, “VT’s” and “Circuit Breaker”. Inthese tabs individual settings are configured. Thus the following Subsections arestructured accordingly.

2.1.3.1 Power System

Nominal Frequency Address 0214 Rated Frequency corresponds to the frequency at which the pro-tected equipment operate. The setting is dependent on the model number of the relaypurchased, and must be in accordance with the nominal frequency of the power sys-tem.

Phase Sequence Address 0209 PHASE SEQ. is used to establish phase rotation. The default phasesequence is “A B C”. For systems that use a phase sequence of “A C B”, address0209 should be set accordingly. A temporary reversal of rotation is also possible usingbinary inputs (see Section 2.18).

Temperature Unit Address 0276 TEMP. UNIT allows you to display the temperature values either in de-gree Celsius or in degree Fahrenheit.

00015 >Test mode >Test mode

---- Feeder gnd Feeder GROUNDED

---- Brk OPENED Breaker OPENED

---- HWTestMod Hardware Test Mode

---- SynchClock Clock Synchronization

---- Error FMS1 Error FMS FO 1

---- Error FMS2 Error FMS FO 2

F.No. Alarm Comments

MENU

ENTER

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Polarity of CurrentTransformers

At address 0201 CT Starpoint, the polarity of the wye-connected current trans-formers is specified (see Figure 2-5 for options). Modifying this setting also results ina polarity reversal of the ground current inputs IN or INS.

Figure 2-5 Current Transformer Polarity

Voltage Connection Address 0213 VT Connection specifies how the voltage transformers are connect-ed. When the voltage transformers are connected in a wye configuration, address0213 is set at Van, Vbn, Vcn. VT Connection = Vab, Vbc, VGnd meaning thattwo phase-to-phase voltages (V-connection) and Vgnd are connected. The latter set-ting is also selected when only two phase-to-phase voltage transformers are utilizedor when only the displaced voltage (zero sequence voltage) is connected to the de-vice.

7SJ64 features 4 voltage measuring inputs which enable further options besides theabove mentioned connection types: VT Connection = Van,Vbn,Vcn,VGn is se-lected if the three phase voltages in wye-connection and Vgnd are connected to thefourth voltage input of the device. Select VT Connection = Van,Vbn,Vcn,VSy ifthe fourth voltage input is used for the synchronizing function.

Units of Length Address 0215 Distance Unit corresponds to the units of length (km or Miles) ap-plicable to fault locating. If a fault locator is not included with the device, or if the faultlocating function is disabled, this setting has no effect on operation of the device.Changing the length unit will not result in an automatic conversion between the sys-tems. Such conversions must be entered at the appropriate addresses.

ATEX100 Parameter 0235A ATEX100 allows to fulfil the requirements for the protection of haz-ardous-duty motors for thermal replicas. Set this parameter to YES to save all thermalreplicas of 7SJ62/63/64 in the event of a power supply failure. After the supply voltagehas been restored the thermal replicas will resume operation using the stored values.Set the parameter to NO to reset the calculated overtemperatures of all thermal repli-cas to zero if the power supply fails.

Ground FaultProtection

With Parameter 0613A 50N/51N/67N w. You can specify whether the ground faultprotection function operates with measured values (Ignd (measured)) or with thevalues calculated from the three phase currents (Ignd (measured)) .

In the first case the measured quantities applying at the fourth current input are eval-uated, the latter case calculates the summation current from the three phase current

IAIBIC

IGIAIBIC

IG

Address 0201 = Address 0201=

Busbar

Line Line

towards Line towards Busbar

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inputs. If the device features a sensitive ground current input (measuring range startsat 1 mA), the ground fault protection generally uses the calculated quantity 3I0.

2.1.3.2 Current Transformers (CT’s)

CT’s Nominal Val-ues

At addresses 0204 CT PRIMARY and 0205 CT SECONDARY, information is enteredregarding the primary and secondary ampere ratings of the current transformers. It isimportant to note that the primary ampere rating of the current transformers is basedon the actual tapped connection of the current transformers’ secondary winding (i.e.for a 1200/5 ampere multi-ratio current transformer connected at a 600/5 ampere tap,the user should enter a value of 600 for CT PRIMARY and a value of 5 for CT SEC-ONDARY). It is also important to ensure that the rated secondary current of the currenttransformer matches the rated current of the device, otherwise the device will incor-rectly calculate primary amperes.

Addresses 0217 Ignd-CT PRIM and 0218 Ignd-CT SEC provide the device withinformation on the primary and secondary rated current of the ground CT. In case ofa normal connection (starpoint current connected to Ignd-transformer)0217 Ignd-CT PRIM and 0204 CT PRIMARY must be set to the same value.

If the device is equipped with a sensitive ground fault current input, parameter 0218 Ignd-CT SEC is preset to 1 A. In this case the setting cannot be modified.

2.1.3.3 Voltage Transformers (VT’s)

VT’s Nominal Val-ues

At addresses 0202 Vnom PRIMARY and 0203 Vnom SECONDARY, information is en-tered regarding the rated primary nominal voltage and rated secondary nominal volt-ages (L-L) of the connected voltage transformers.

VT’s Ratio Address 0206A Vph / Vdelta corresponds to the factor by which the secondaryphase-to-ground voltage must be adjusted relative to the secondary displacementvoltage (zero sequence voltage), and only applies in situations where the displace-ment voltage is actually measured by the device as opposed to calculated by the de-vice.

If the voltage transformer set provides open delta windings and if these windings areconnected to the device, this must be specified accordingly in address 0213 (seeabove margin heading “Voltage Connection“). The relationships between the second-ary device input voltages and the primary phase-to-ground and displacement voltagesare given as follows:

For the secondary input voltages representing phase-to-phase voltages:

For the secondary input voltage representing displacement voltage:

Vsec-input Vprim-φφVT Ratio------------------------ 3 Vprim-φg

VT Ratio------------------------⋅= =

Vsec-input 3 Vprim-dispVT Ratio

----------------------------×=

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Since the per unit base values of the phase-to-ground voltage and the displacementvoltage are equivalent, Vsec-input / Vprim-φg should equal Vsec-input / Vprim-disp.To compensate for the voltage transformer connection, the device must adjust thesecondary phase-to-ground voltage upward by a factor of √3. Therefore, in this case,address 0206A Vph / Vdelta would be set at 1.73 (= √3).

For situations where displacement voltage is measured by the device and other typesof voltage transformer connections are utilized, the setting at address 0206A shouldbe modified accordingly.

2.1.3.4 Circuit Breaker (CB)

Trip and CloseCommand Duration

Address 0210A TMin TRIP CMD is used to set the minimum time the tripping con-tacts will remain closed. This setting applies to all protective functions that initiate trip-ping.

Address 0211A TMax CLOSE CMD is used to set the maximum time the closing con-tacts will remain closed. This setting applies to the integrated reclosing function andmust be long enough to allow the circuit breaker contacts to reliably engage. An ex-cessive duration causes no problem since the closing command is interrupted in theevent another trip is initiated by a protective function.

Current Flow Moni-toring

Address 0212 BkrClosed I MIN corresponds to the threshold value of the integrat-ed current flow monitoring system. This setting is used by several protective functions(e.g., voltage protection with current supervision, breaker failure protection, overloadprotection, and restart block for motors). If the threshold value set at address 0212 isexceeded, the circuit breaker is considered closed.

The threshold value setting applies to all three phases, and takes precedence over allother protective functions.

With regard to breaker failure protection, the threshold value must be set at a level be-low the minimum fault current for which breaker failure protection must operate. Onthe other hand, the current threshold should not be set more sensitive than necessaryto avoid extended resetting times on transient phenomena of the current transformersafter interruption of high short–circuit currents. A setting of 10% below the minimumfault current for which breaker failure protection must operate is recommended.

When using the device for motor protection, overload protection, and restart blocking;the protective relay can distinguish between a running motor and a stopped motor, aswell as take into account the varying motor cool-down behavior. Under this application,the set value must be lower than the minimum no-load current of the motor.

Addr. Setting Title Setting Options Default Setting Comments

214 Rated Frequency 50 Hz60 Hz

50 Hz Rated Frequency

209 PHASE SEQ. A B CA C B

A B C Phase Sequence

276 TEMP. UNIT Degree CelsiusDegree Fahrenheit

Degree Celsius Unit of temparature measure-ment

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*) 7SJ64 only

2.1.3.5 Information

201 CT Starpoint towards Linetowards Busbar

towards Line CT Starpoint

213 VT Connection Van, Vbn, VcnVab, Vbc, VGndVan, Vbn, Vcn, VGnd *)Van, Vbn, Vcn, VSyn *)

Van, Vbn, Vcn VT Connection

215 Distance Unit kmMiles

km Distance measurement unit

235A ATEX100 NOYES

NO Storage of th. Replicas w/oPower Supply

613A 50N/51N/67N w. Ignd (measured)3I0 (calculated)

Ignd (measured) 50N/51N/67N Ground Overcur-rent with

204 CT PRIMARY 10..50000 A 100 A CT Rated Primary Current

205 CT SECONDARY 1A5A

1A CT Rated Secondary Current

217 Ignd-CT PRIM 1..50000 A 60 A Ignd-CT rated primary current

218 Ignd-CT SEC 1A5A

1A Ignd-CT rated secondary current

202 Vnom PRIMARY 0.10..800.00 kV 12.00 kV Rated Primary Voltage

203 Vnom SECON-DARY

100..225 V 100 V Rated Secondary Voltage (L-L)

206A Vph / Vdelta 1.00..3.00 1.73 Matching ratio Phase-VT ToOpen-Delta-VT

210A TMin TRIP CMD 0.01..32.00 sec 0.15 sec Minimum TRIP Command Dura-tion

211A TMax CLOSE CMD 0.01..32.00 sec 1.00 sec Maximum Close CommandDuration

212 BkrClosed I MIN 0.04..1.00 A 0.04 A Closed Breaker Min. CurrentThreshold

Addr. Setting Title Setting Options Default Setting Comments

F.No. Alarm Comments

05145 >Reverse Rot. >Reverse Phase Rotation

05147 Rotation ABC Phase rotation ABC

05148 Rotation ACB Phase rotation ACB

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2.1.4 Waveform Capture

The 7SJ62/63/64 relay is equipped with an oscillographic data saving feature. Themomentary values for the measurement quantities

Ia, Ib, Ic, IG, and INs, and Va, Vb, Vc, 3V0 and VSYN (only 7SJ64)

(voltages depending on the connection) are scanned at intervals of 1.04 ms for 60 Hz(1.25 ms for 50 Hz) and stored in a revolving buffer (16 samples per cycle). For a fault,the data are stored for an adjustable period of time, but not more than 5 seconds. Upto 8 fault records can be recorded in this buffer. The memory is automatically updatedwith every new fault, so no acknowledgment for previously recorded faults is required.Waveform capture can also be started with protection pickup, via binary input, via PC-interface, or SCADA.

Using the PC-interface or the rear service port, data can be retrieved by a personalcomputer and processed, using the protective data processing program DIGSI® 4,and the graphics program DIGRA® 4. DIGRA® 4 graphically prepares the data gener-ated during the fault, and calculates additional quantities, such as impedance or rmsvalues, from the delivered measured values. The currents and voltages can be repre-sented as primary or secondary quantities. In addition, relay sequence of events sig-nals are recorded as well.

Fault data may be retrieved via the serial interface of a PC. Data evaluation is per-formed by the PC using the respective programs. For this, the currents and voltagesare related to their maximum values, are standardized to the nominal value, and pre-pared for graphical display. Additionally, events such as the pickup of a relay elementor the initiation of a trip signal can be displayed as well.

If configured in SCADA, data are transferred automatically to the SCADA computer.

Programming Settings

Waveform Capture Waveform capture of faults is executed only when Address 0104 OSC. FAULT REC.is set for Enabled. Other settings pertaining to waveform capture are found underthe OSC. FAULT REC. sub-menu of the SETTINGS menu.

The trigger for an oscillographic record and the criterion to save the record are deter-mined with the setting of Address 0401 WAVEFORMTRIGGER. With the setting Save w. Pickup, the trigger and the criterion for saving are the same – the pickup of aprotective element. Another option for Address 0401 is Start w. TRIP. A trip com-mand issued by the device is both the trigger and the criterion to save the record withthis setting. The final — and more commonly used — option for Address 0401 is Save w. TRIP. The trigger under this setting is the pickup of a protective element (firstelement to pick up) and saving of the waveforms occurs only if the device issues a tripcommand. Each setting for Address 0401 has specific advantages. The choice de-pends primarily on the expected duration of faults, the time period of a complete faultduration that is of most interest (e.g. inception or clearing), and the frequency of wave-form capturing that is to be expected.

There are two options available for the coverage of oscillographic recording. The se-lection is made under Address 0402 WAVEFORM DATA and is based on the user’spreference for recording events that occur while automatic reclosing is performed bythe device. With the setting Fault event, waveform capturing occurs each timethe recording trigger and save criterion are established. If automatic reclosing in thedevice is employed, the second option Pow.Sys.Flt. can be selected if desired.

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With this setting, the entire course of a fault - from inception, through reclosing, toclearing - is captured. This option provides detailed data for analysis of the entire faulthistory; however, the option also requires considerable memory for recording duringdead times.

An oscillographic record includes data recorded prior to the time of trigger, and dataafter the dropout of the recording criterion. The user determines the length of pre-trig-ger time and post-dropout time to be included in the fault record with the settings inAddress 0404 PRE. TRIG. TIME and Address 0405 POST REC. TIME. The set-tings depend on Address 0401 and the information desired. For example, consider thetrigger being a pickup of a protective element and the save criterion being a trip. Thepre-trigger time is set based on the amount of pre-fault information that is desired. Thepost-dropout time is set based on the amount of information desired after clearing (e.g.checking for restrikes).

The maximum length of time of a record is entered in Address 0403 MAX. LENGTH. The largest value here is 5 seconds. A total of 8 records can be saved. However thetotal length of time of all fault records in the buffer may not exceed 5 seconds. Oncethe capacity of the buffer is exceeded the oldest fault is deleted, whereas the new faultis saved in the buffer.

An oscillographic record can be triggered and saved by a change in status of a binaryinput or via the operating interface connected to a PC. The trigger is dynamic. Thelength of a record for these special triggers is set in Address 0406 BinIn CAPT.TIME (upper bound is Address 0403). Pre-trigger and post-dropout settings inAddresses 0404 and 0405 do not apply. If Address 0406 is set for “∞,” then the lengthof the record equals the time that the binary input is activated (static), or the MAX. LENGTH setting in Address 0403, whichever is shorter.

2.1.4.1 Information

Addr. Setting Title Setting Options Default Setting Comments

401 WAVEFORMTRIG-GER

Save with PickupSave with TRIPStart with TRIP

Save with Pickup Waveform Capture

402 WAVEFORM DATA Fault eventPower System fault

Fault event Scope of Waveform Data

403 MAX. LENGTH 0.30..5.00 sec 2.00 sec Max. length of a Waveform Cap-ture Record

404 PRE. TRIG. TIME 0.05..0.50 sec 0.25 sec Captured Waveform Prior toTrigger

405 POST REC. TIME 0.05..0.50 sec 0.10 sec Captured Waveform after Event

406 BinIn CAPT.TIME 0.10..5.00 sec; ∞ 0.50 sec Capture Time via Binary Input

F.No. Alarm Comments

00004 >Trig.Wave.Cap. >Trigger Waveform Capture

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General

2.1.5 Setting Groups

Purpose of SettingGroups

A setting group is nothing more than a collection of setting values to be used for a par-ticular application. In the 7SJ62/63/64 relay, 4 independent setting groups (A ~ D) arepossible. The user can switch back and fourth between setting groups locally, via bi-nary inputs (if so configured), via the operator or service interface using a personalcomputer, or via the system interface. For reasons of safety it is not possible to changebetween setting groups during a power system fault.

A setting group includes the setting values for all functions that have been selected asEnabled during configuration (see Chapter 5). While setting values may vary amongthe 4 setting groups, the selected functions of each setting group remain the same.

Multiple setting groups allows a specific relay to be used for more than one application.While all setting groups are stored in the relay, only one setting group may be activeat a given time.

If multiple setting groups are not required, Group A is the default selection, and thefollowing paragraph is not applicable.

If multiple setting groups are desired, address 0103 Grp Chge OPTION must be setto Enabled in the relay configuration. For the setting of the function parameters, youconfigure each of the required setting groups A to D, one after the other. A maximumof 4 is possible. Please refer to the DIGSI® 4–System Manual, Order No. E50417–H1176–C151 to learn how to copy setting groups or reset them to their status at deliv-ery and also what you have to do to change from one setting group to another.

Subsection 3.1.2 tells you how to change between several setting groups externallyvia binary inputs.

2.1.5.1 Settings

2.1.5.2 Information

00203 Wave. deleted Waveform data deleted

---- FltRecSta Fault Recording Start

F.No. Alarm Comments

Addr. Setting Title Setting Options Default Setting Comments

302 CHANGE Group AGroup BGroup CGroup DBinary InputProtocol

Group A Change to Another SettingGroup

F.No. Alarm Comments

00007 >Set Group Bit0 >Setting Group Select Bit 0

00008 >Set Group Bit1 >Setting Group Select Bit 1

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2.1.6 Power System Data 2

General protective data (P.SYSTEM DATA2) includes settings associated with allfunctions rather than a specific protective or monitoring function. In contrast to theP.SYSTEM DATA1 as discussed in Sub-section 2.1.3, these settings can be changedover with the setting groups. To modify these settings, the user should select SET-TINGS menu option Group A (setting group A), and then P.System Data2.

The other setting groups are Group B, Group C, and Group D, as described inSubsection 2.1.5.

Definition ofNominal RatedValues

At addresses 1101 FullScaleVolt. and 1102 FullScaleCurr., the referencevoltage (phase-to-phase) and reference current (phase) of the protected equipment isentered (e.g., motors). These values do not effect pickup settings. If these referencevalues match the primary VT’s and CT’s, they correspond to the settings in address0202 and 0204 (Subsection 2.1.3). They are generally used to show values in refer-ence to full scale. For example, if a CT ratio of 600/5 is selected and the full load cur-rent of a motor is 550 amps, a value of 550 amps should be entered forFullScaleCurr. if monitoring in reference to full load current is desired. 550 ampsare now displayed as 100 % in the percentage metering display.

Ground ImpedanceRatios (only forfault location)

The ground impedance ratios must be entered to facilitate line fault location. At ad-dress 1103 RG/RL Ratio, the resistance ratio of the line is entered, and at address1104 XG/XL Ratio, the reactance ratio of the line is entered. The ground impedanceratios are calculated separately, and do not correspond to the real and imaginary com-ponents of Z0/Z1. Therefore, no complex calculations are necessary. The ground im-pedance ratios are obtained from conductor data using the following formulas:

Resistance Ratio: Reactance Ratio:

Where

R0 = Zero sequence resistance of the line

X0 = Zero sequence reactance of the line

R1 = Positive sequence resistance of the line

X1 = Positive sequence reactance of the line

The ground impedance ratios may be calculated using the impedance values for theentire line or the impedance per mile values associated with the conductor, since the

---- Group A Group A

---- Group B Group B

---- Group C Group C

---- Group D Group D

F.No. Alarm Comments

RG

RL-------- 1

3---

R0

R1------- 1– ⋅=

XG

XL------- 1

3---

X0

X1------ 1– ⋅=

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General

length of the line is factored out in the formulas above.

Calculation example:

20 kV free line 120 mm2 with the following data:

R1/s = 0.39 Ω/mileX1/s = 0.55 Ω/mile Positive sequence impedance

R0/s = 1.42 Ω/mileX0/s = 2.03 Ω/mile Zero sequence impedance

For ground impedance ratios, the following emerge:

These values are set at addresses 1103 and 1104 respectively.

Reactance Setting(only for fault loca-tion)

The reactance setting must be entered if line fault location is desired. The reactancesetting enables the protective relay to report fault location in terms of distance.

The reactance value is entered as a secondary value at address 1105 in ohms permile if address 0215 is set to Miles, or at address 1106 in ohms per kilometer if ad-dress 0215 is set to Kilometers (see Subsection 2.1.3 under “Units of Length”). If thesetting of address 0215 is modified after entry of a reactance value at address 1105or 1106, the reactance value must be modified and reentered accordingly.

The calculation of primary ohms in terms of secondary ohms is accomplished usingthe following formula:

Because the reactance value must be entered in secondary ohms per unit length, theformula above must be used to convert primary ohms per unit length into secondaryohms per unit length as shown below:

Example calculation:

The same example used to illustrate calculation of ground impedance ratios will beused to illustrate calculation of the reactance setting, with the following additional dataon the current transformers and voltage transformers:

Current transformer 500 A / 5 AVoltage transformer 20 kV / 0.1 kV

RG

RL--------

13---

R0

R1------- 1– ⋅ 1

3---

1.42 Ω mile⁄0.39 Ω mile⁄-------------------------------- 1–

0.89=⋅= =

XG

XL-------

13---

X0

X1------ 1–

⋅ 13---

2.03 Ω mile⁄0.55 Ω mile⁄-------------------------------- 1–

0.90=⋅= =

Z ondarysecCurrent-Transformer-Ratio

Voltage-Transformer - Ratio-------------------------------------------------------------------------- Zprimary⋅=

X’sec

NCTR

NVTR-------------- X’prim⋅= where:

NCTR = Current transformer ratioNVTR = Voltage transformer ratio

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The secondary reactance value is calculated as follows:

This value is entered at Address 1106.

Recognition ofRunning Condition(only for motors)

Address 1107 I MOTOR START, is used for motor protection applications and corre-sponds to the minimum starting current of the protected motor. The current setting en-tered at address 1107 enables the device to determine if the protected motor is instart-up mode, thus allowing the device to properly perform the start-up time monitor-ing and overload protection functions.

In determining the setting for address 1107, the following should be considered:

• A setting must be selected that is lower than the actual motor start-up current underall load and voltage conditions.

• Because the thermal cure of the overload protection is “frozen” (held constant) dur-ing motor start-up, the setting must be high enough to allow operation of the over-load protection at higher load current levels.

2.1.6.1 Settings

In the list below, the setting ranges and default setting values are for a device with anominal current rating IN = 1 A. Consider the current transformer ratios when settingthe device with primary values

For a nominal current rating IN = 5 A:

− For the pickup current (I MOTOR START), multiply the Setting Options values anddefault setting values by 5.

− For the Ground resistance and reactance ratios, divide Setting Range and SettingIncrements by 5.

X’sec

NCTR

NVTR--------------- X’prim⋅ 500 A/5 A

20 kV/0.1 kV----------------------------------- 0.55 Ω/mile⋅ 0.275 Ω/mile= = =

Addr. Setting Title Setting Options Default Setting Comments

1101 FullScaleVolt. 0.10..800.00 kV 12.00 kV Measurem:FullScaleVol-tage(Equipm.rating)

1102 FullScaleCurr. 10..50000 A 100 A Measurem:FullScaleCur-rent(Equipm.rating)

1103 RG/RL Ratio -0.33..7.00 1.00 RG/RL - Ratio of Gnd to LineResistance

1104 XG/XL Ratio -0.33..7.00 1.00 XG/XL - Ratio of Gnd to LineReactance

1105 x' 0.010..10.000 Ohm / mile 1.000 Ohm / mile x' - Line Reactance per lengthunit

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General

2.1.6.2 Information

1106 x' 0.005..6.215 Ohm / km 0.620 Ohm / km x' - Line Reactance per lengthunit

1107 I MOTOR START 0.60..10.00 A 2.50 A Motor Start Current (Block 49,Start 48)

F.No. Alarm Comments

00356 >Manual Close >Manual close signal

02720 >Enable ANSI#-2 >Enable 50/67-(N)-2 (override 79 blk)

04601 >52-a >52-a contact (OPEN, if bkr is open)

04602 >52-b >52-b contact (OPEN, if bkr is closed)

00533 Ia = Primary fault current Ia

00534 Ib = Primary fault current Ib

00535 Ic = Primary fault current Ic

00501 Relay PICKUP Relay PICKUP

00511 Relay TRIP Relay GENERAL TRIP command

00561 Man.Clos.Detect Manual close signal detected

00126 ProtON/OFF Protection ON/OFF (via system port)

Addr. Setting Title Setting Options Default Setting Comments

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Functions

2.2 Overcurrent Protection (50, 50N, 51, 51N)

General Time-overcurrent protection is the main protective function of the 7SJ62/63/64 relay.It may be enabled or disabled for phase or ground faults, and may be configured withvarious time-overcurrent characteristic curves.

There are four definite time (Instantaneous elements with optional timers) and two in-verse time-overcurrent elements in the device. The definite time elements include twophase elements and two ground elements. The definite time (Instantaneous) phase el-ements are designated 50-2 and 50-1, whereas the definite time (Instantaneous)ground elements are designated 50N-2 and 50N-1. The inverse time elements includea phase element designated as 51 and a ground element designated as 51N.

The overcurrent protection for the ground current can operate either using measuredvalues Ignd or the quantities 310 calculated from the three phase currents dependingon the parameter 0613A 50N/51N/67N w.Devices featuring a sensitive ground cur-rent input, however, use generally the calculated quantity 3I0.

All overcurrent elements, inverse and definite time, enabled in the device may beblocked via the automatic reclosure function (depending on the cycle) or via an exter-nal signal to the binary inputs of the device. Removal of the external signal to the bi-nary input will re-enable these elements. Also, a feature described as Manual CloseMode can be configured to improve fault clearing times associated with Switch-on-to-Fault Conditions. Under this situation, the time delay may be bypassed for one of thethree time-overcurrent phase elements and one of the three time-overcurrent groundelements via an impulse from the external control switch, thus resulting in high speedtripping. This impulse is prolonged by a period of 300 ms. The phase and ground ele-ments utilized for high speed tripping in this situation are selected at addresses 1213and 1313 respectively.

The automatic reclosure function may also initiate the immediate tripping for the over-current stages and high-current stages depending on the cycle.

Pickup and delay settings may be quickly adjusted to system requirements via ColdLoad Pickup function (see Section 2.4).

Tripping by the 50-1, 51, 50N-1, and 51N elements may be blocked for inrush condi-tions by utilizing the inrush restraint feature.

Table 2-2 gives an overview of the interconnection to other functions of 7SJ62/63/64..

Table 2-2 Interconnection to other functions

Time OvercurrentStages

Connection toAutomaticReclosure

ManualCLOSE

DynamicCold-Load-

Pick-up

InrushRestraint

50-1 • • • •

50-2 • • •

51 • • • •

50N-1 • • • •

50N-2 • • •

51N • • • •

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Overcurrent Protection (50, 50N, 51, 51N)

2.2.1 Description

2.2.1.1 Definite Time, Instantaneous Overcurrent Protection (50, 50N)

50-2, 50N-2 The 50-2 and 50N-2 overcurrent elements, phase and ground currents are comparedseparately with the pickup values of the 50-2 (50-2 PICKUP) and 50N-2 (50N-2 PICKUP) relay elements. Currents above the pickup values are detected and recordedwithin the protective relay. After the user-configured time delay has elapsed, a trip sig-nal is issued.

Figures 2-6 and 2-7 show the logic diagrams for the 50-2 and 50N-2 protection.

Figure 2-6 Logic Diagram for 50-2 Relay Element

If the parameter MANUALCLOSEMODE is set to 50N-2 instant. and if manual closemode is applied, the pick-up is tripped instantaneously, also for blocking of the stagevia binary input. The same applies to 79 AR 50-2 instant. and the binary inputfor instantaneous tripping.

1213A MANUALCLOSEMODE

Inactive51 instant.50 -1 instant.50-2 instant.

>BLOCK 50-2

„1“

or

„1“

Manual Close&

50-2 PhA PU

&

T 0

or

or

or

AB

C

>BLK 50/51 50/51 PH BLK

or50/51 PH OFF

Measurement/Logic

&

50-2 picked up

50-2 TRIP

50-2 TimeOut

79 AR 50-2 blkor 50-2 BLOCKED

or79 AR 50-2 instant.

>INSTANT. 50-2

1201 Charac. Phase

1203 50-1 DELAY

FNo. 01800

FNo. 01805

FNo. 01804

FNo. 01852

FNo. 01752

FNo. 01751

FNo. 01721

FNo. 01704

OFF

ON

FNo. 01910

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Functions

I

Figure 2-7 Logic Diagram for 50N-2 Relay Element

If the parameter MANUALCLOSEMODE is set to 50N-2 instant. and if manual closemode is applied, the pick-up is tripped instantaneously, also for blocking of the stagevia binary input. The same applies to 79 AR 50N-2 instant. and the binary inputfor instantaneous tripping.

50-1, 50N-1 The 50-1 and 50N-1 overcurrent elements, phase and ground currents are comparedseparately with the pickup values of the 50-1 (50-1 PICKUP) and 50N-1 (50N-1 PICKUP) relay elements. Currents above the pickup values are detected and recordedwithin the protective relay. After the user-configured time delay has elapsed, a trip sig-nal is issued.

If the inrush restraint feature is enabled (see below), and an inrush condition exist, notripping takes place, but a message is recorded and displayed indicating when theovercurrent element time delay elapses.

Different messages are recorded and displayed appear depending on whether trippingtakes place or the time delay expires without tripping.

The dropout value of the definite time, time-overcurrent elements is roughly equal to95 % of the pickup value for currents greater than or equal to 30 % of the nominal cur-rent of the device.

These stages may be blocked by the automatic reclosure function.

Figures 2-8 and 2-9 show the logic diagrams for the 50-1 and 50N-1 protection.

1301 FCT 50N/51N

Inactive51N instant.50N-1 instant.50N-2 instant.

50N-2 PU

&

T 0

or

50N/51N BLK

50N/51N OFF

&

50N-2 TRIP

50N-2 picked up

„1“

Manual Close&

50N-2 TimeOut

„1“

>BLOCK 50N-2

>BLK 50N/51N

or

79 AR 50N-2 blkor 50N-2 BLOCKED

or79 AR 50N-2 inst.

>INSTANT. 50N-2.

1303 50N-2 DELAY

1313A MANUALCLOSEMODE

FNo. 01831

FNo. 01833

FNo. 01832

FNo. 01854

FNo. 01757

FNo. 01756

FNo. 01724

FNo. 01714

OFF

ON

FNo. 01916

Measurement/Logic

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Overcurrent Protection (50, 50N, 51, 51N)

Pickup and delay settings for the 50-1, 50-2, 50N-1, and 50N-2 elements may be in-dividually programmed.

Figure 2-8 Logic Diagram for the 50-1 Relay Element

If the parameter MANUAL CLOSE is set to 50 -1 instant. and if manual close modeis applied, the pick-up is tripped instantaneously, also for blocking of the stage via bi-nary input. The same applies to 79 AR 50-1 inst. and the binary input for instan-taneous tripping.

1313A MANUALCLOSEMODE

Inactive51 instant.50-2 instant.50 -1 instant.

or

50-1 PhA PU

&

T 0

or

or

or

AB

C

50/51 TRIP

50-1 picked up

50-1 TimeOut

„1“

>BLOCK 50-1

>BLK 50/51 50/51 PH BLK

or

Measurement/Logic

50/51 PH OFF

or79 AR 50-1 blk

50-1 BLOCKED

50-1 InRushPU&

&

&

Inrush Recognition 50-1 (see Figure 2-12)

&

„1“

Manual Close&

or79 AR 50-1 inst.

50-1 INSTANT.

1201 FCT 50/51

1205 50-1 DELAY

FNo. 01810

FNo. 01815

FNo. 01814

FNo. 01722

FNo. 01704

FNo. 01851

FNo. 01752

FNo. 01751

FNo. 01912

FNo. 07551

OFF

ON

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Figure 2-9 Logic Diagram for the 50N-1 Relay Element

If the parameter MANUAL CLOSE is set to 50 -1 instant. and if manual close modeis applied, the pick-up is tripped instantaneously, also for blocking of the stage via bi-nary input. The same applies to 79 AR 50N-1 inst. and the binary input for instan-taneous tripping.

The pickup values of each stage 50-1, 50-2 for the phase currents and 50N-1, 50N-2for the ground current and the valid delay times for each stage can be set individually.

Pickup Logic andTripping Logic

The pick-up signals of the individual phases (or ground) and the individual stages areconnected with each other such that the phase information and the stage are issuedthat have picked up (Table 2-3).

Inactive51N instant.50N-2 instant.50N-1 instant.

„1“

>BLOCK 50N-1

>BLK 50N/51N 50N/51N BLK

or

50N/51N OFF

or79 AR 50N-1 blk

50N-1 BLOCKED

50N-1 PU

&

T 0

or50N-1 TRIP

50N-1 picked up

50N-1 TimeOut

50N-1 InRushPU&

&

&

Inrush Recognition 50N-1 (see Figure 2-12)

&

„1“

Manual Close&

or79 AR 50N-1 inst.

>INSTANT. 50N-1

1305 50N-1 DELAY

1301 FCT 50N/51N

1313A MANUALCLOSEMODE

FNo. 01834

FNo. 01836

FNo. 01835

FNo. 01853

FNo. 01757

FNo. 01756

FNo. 01725

FNo. 01714

FNo. 07552

FNo. 01919

OFF

ON

Measurement/Logic

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Overcurrent Protection (50, 50N, 51, 51N)

Also for the tripping signals the stage is indicated which has initiated the tripping.

2.2.1.2 Inverse Time-Overcurrent Protection (51, 51N)

Inverse time-overcurrent protection, the 51 and 51N relay elements may contain IECcharacteristic curves or ANSI characteristic curves depending on the model ordered.A user-specified curve may also be applied to the inverse-overcurrent relay elements.The curves and associated formulas are given in Technical Specifications (Figures 4-1 to 4-6 in Section 4.3). During configuration of the 51 and 51N characteristic curves,the definite time relay elements (50-2, 50-1, 50N-2, and 50N-1) are enabled (see Sub-section 2.2.1.1).

Pickup and Trip-ping

Each phase and ground current is separately compared with the pickup values of the51 and 51N relay elements. When the current in the 51 and 51N relay elements ex-ceeds the corresponding pickup value by a factor of 1.1, the element picks up and amessage is displayed and recorded within the device. Pickup of a 51 or 51N relay el-ement is based on the rms value of the fundamental harmonic. When the 51 and 51Nelements pickup, the time delay of the trip signal is calculated using an integratedmeasurement process. The calculated time delay is dependent on the actual fault cur-

Table 2-3 Pick-up indications of the time overcurrent protection

Internal indication Figure Output indication FNo.

50-2 Ph A PU50-1 Ph A PU51 Ph A PU

2-62-82-10

50/51 Ph A PU 01762

50-2 Ph B PU50-1 Ph B PU51 Ph B PU

2-62-82-10

50/51 Ph B PU 01763

50-2 Ph C PU50-1 Ph C PU51 Ph C PU

2-62-82-10

50/51 Ph C PU 01764

50N-2 PU50N-1 PU51N PU

2-72-92-11

50N/51NPickedup 01765

50-2 Ph A PU50-2 Ph B PU50-2 Ph C PU50N-2 PU

2-62-62-62-7

50-2 picked up 01800

50-1 Ph A PU50-1 Ph B PU50-1 Ph C PU50N-1 PU

2-82-82-82-9

50-1 picked up 01810

51 Ph A PU51 Ph B PU51 Ph C PU51N PU

2-102-102-102-11

51 picked up 01820

(all pickups) 50(N)/51(N) PU 01761

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Functions

rent flowing and the selected time-current characteristic curve. Once the time delayelapses, a trip signal is issued.

If the inrush restraint feature is enabled, and an inrush condition exist, no trippingtakes place, but a message is recorded and displayed indicating when the overcurrentelement time delay elapses.

These stages can be blocked by the automatic reclosing function.

The characteristic curves of the 51 and 51N relay elements may be selected indepen-dently of each other. In addition, pickup, time multipliers, and time dials for the 51 and51N elements may be individually set.

Figures 2-10 and 2-11 show the logic diagram for the 51 and 51N protection, Figure2-12 the logic diagram of the inrush restraint.

Dropout for ANSIand IEC Curves

For ANSI and IEC curves you can specify whether the dropout of a stage, after it hasfallen below a threshold, takes places instantaneously or via disk emulation. Instanta-neously means that the dropout of a stage which has picked up is performed as soonas the value falls below approximately 95 % of the pickup value. The timer will startagain for all new pick-ups.

Dropout of an element occurs when the current decreases to about 95 % of the pickupvalue if instantaneous reset is selected, or 90 % of the pickup value if disk emulationis selected. When instantaneous reset is selected, reset of the element occurs withoutdelay. When disk emulation is selected, reset occurs just as it would for an electrome-chanical relay utilizing an induction disk.

For disk emulation, the reset process begins after fault current is interrupted. Resetcorresponds to the unwinding of an induction disk. A subsequent pickup of the deviceelement prior to full reset will result in a reduced tripping time delay. The reduced trip-ping time delay will be based on the degree to which the device had reset when thesubsequent pickup occurred. When the current in the relay element is between 90 %and 95 % of the pickup value following dropout, neither disk movement in the trippingor reset direction is simulated. When the current in the relay elements falls below 5 %of the pickup value, disk emulation is canceled and full reset takes place.

Disk emulation offers advantages when the inverse time, time-overcurrent relay ele-ments must be coordinated with conventional electromechanical overcurrent relays lo-cated toward the source.

User SpecifiedCurves

When user specified curves are utilized, the time-current characteristic curve may bedefined point by point. Up to 20 pairs of values (current, time) may be entered. Therelay element then approximates the curve using linear interpolation.

When utilizing user specified time-current curves, the reset curve may user specifiedas well. See reset for ANSI and IEC characteristics in the function description. If userspecified reset curves are not utilized, the relay element drops out when current de-creases to about 95 % of the relay element’s pickup value, and immediate reset takesplace.

44 7SJ62/63/64 ManualC53000-G1140-C147-1

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Overcurrent Protection (50, 50N, 51, 51N)

Figure 2-10 Logic Diagram for the 51 Relay Element

If the parameter MANUAL CLOSE is set to 51 instant. and if manual close mode isapplied, the pick-up is tripped instantaneously, also for blocking of the stage via binaryinput and the binary input for instantaneous tripping. The same applies to 79 AR 51 inst. and the binary input for instantaneous tripping.

Inactive50-2 instant.50 -1 instant.51 instant.

or

„1“

Manual Close&

51 Ph A PU

&

or

or

or

AB

C

51 TRIP

51 picked up

51 Time Out

„1“

>BLOCK 51

>BLK 50/51 50/51 PH BLK

or

measurementpickup/tripping logic

50/51 PH OFF

51 BLOCKED

51 InRushPU&

&

&

&

1208 51 TIME DIAL

1201 FCT 50/51

1213A MANUALCLOSEMODE

FNo. 01820

FNo. 01825

FNo. 01824

FNo. 01855

FNo. 01752

FNo. 01751

FNo. 01723

FNo. 01704

or79 AR 51 inst.

>INSTANT. 51FNo. 01914

FNo. 07553

OFF

ON

or79 AR 51 blk

Inrush Recognition 51 (see Figure 2-12)

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Functions

Figure 2-11 Logic Diagram for the 51N Relay Element

If the parameter MANUAL CLOSE is set to 51N instant. and if manual close modeis applied, the pick-up is tripped instantaneously, also for blocking of the stage via bi-nary input and the binary input for instantaneous tripping. The same applies to 79 AR 51N inst. and the binary input for instantaneous tripping.

2.2.1.3 Dynamic Cold Load Pick-up Function

With the dynamic cold load pick-up feature, it is possible to dynamically increase thepickup values of the directional and non-directional overcurrent relay elements whendynamic cold load pickup conditions are anticipated (i.e. after a long period of zerovoltage). By allowing pickup settings to increase dynamically, it is not necessary to in-corporate dynamic cold load capability in the normal pickup settings, and directionaland non-directional overcurrent protection may be set more sensitive.

This dynamic pick-up value changeover is common to all overcurrent stages and is de-scribed in Section 2.4. The alternative pick-up values can be set individually for eachstage of the time overcurrent protection.

„1“

>BLK 50N/51N 50N/51N BLK

or

measurementpickup/tripping logic

50N/51N OFF

51N BLOCKED

„1“

51N PU

&

or51N TRIP

51N picked up

51N TimeOut

51N InRushPU&

&

&

Inrush Recognition 51N (s. Figure 2-12)

&

Inactive50N-2 instant.50N-1 instant.51N instant.

1308 51N TIME DIAL

1301 FCT 50N/51N

1313A MANUALCLOSEMODE

FNo. 01837

FNo. 01839

FNo. 01838

FNo. 01856

FNo. 01757

FNo. 01756

FNo. 01714

Manual Close&

or79 AR 51N inst.

>INSTANT. 51NFNo. 01983

FNo. 07554

OFF

ON

>BLOCK 51NFNo. 01726 or

79 AR 51N blk.

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Overcurrent Protection (50, 50N, 51, 51N)

477SJ62/63/64 ManualC53000-G1140-C147-1

2.2.1.4 Inrush Restraint

When the 7SJ62/63/64 relay is installed to protect a power transformer, large magne-tizing inrush currents will flow when the transformer is energized. These inrush cur-rents may be several times the nominal transformer current, and, depending on thetransformer size and design, may last from several milliseconds to several seconds.

Although pickup of the relay elements is based only on the fundamental harmoniccomponent of the measured currents, false device pickup due to inrush is still a poten-tial problem since, depending on the transformer size and design, the fundamentalharmonic comprises a large component of the inrush current.

The 7SJ62/63/64 features an integrated inrush restraint function that may be utilizedwhen the device is installed at or near a transformer. It supervises the “normal” trippingof all directional and non-directional overcurrent relay elements with the exception ofthe 50-2, 50N-2, 67-2 and 67N-2 relay elements. For example, when a transformer isenergized the current levels may exceed the normal pickup of the overcurrent ele-ments set in the device. If inrush conditions are identified (the 2nd harmonic contentof current exceeds the value of setting at address 2202 2nd HARMONIC), special in-rush messages are created within the device that will block tripping of the overcurrentelements. Note, that only the tripping elements are affected by harmonic inrush detec-tion, the pickup values and corresponding timers continue to operate normally. If in-rush conditions are still present after the tripping time delay has elapsed, a corre-sponding message is displayed and recorded, but the overcurrent tripping is blocked.(see Figures 2-8 to 2-11).

Inrush current contains a relatively large second harmonic component which is nearlyabsent during a short-circuit fault. Inrush current detection, therefore, is based on theevaluation of the second harmonic component present during inrush conditions. Forfrequency analysis, digital filters are used to conduct a Fourier analysis of all threephase currents and the ground current. As soon as the second harmonic componentof the current flowing in a specific phase or ground relay element exceeds a set value,tripping is blocked for that element (does not apply to 50-2, 50N-2, 67-2, and 67N-2elements). Since quantitative analysis of the harmonic components of the current flow-ing through a specific relay element cannot be completed until a full cycle of inrush cur-rent has been measured, inrush restraint blocking, and the associated inrush detec-tion message, is automatically delayed by one cycle. It is important to note, however,that the tripping time delays associated with the relay elements are started immediate-ly after pickup of the relay element, even if the inrush conditions are detected. If inrushblocking drops out during the time delay, tripping will occur when the time delay of theelement elapses. If inrush blocking drops out after the time delay has elapsed, trippingwill occur immediately. Therefore, utilization of the inrush restraint feature will not re-sult in any additional tripping delays. If a relay element drops out during inrush block-ing, the associated time delay will reset.

Cross Blocking Since inrush restraint operates individually for each phase, inrush restraint will notblock tripping in situations where a power transformer is energized into a single-phasefault and inrush currents are detected on the unfaulted phases. This feature providesmaximum protection, however, inrush restraint can be configured to allow inrush de-tection on one phase to block tripping by the elements associated with the other phas-es. This is referred to as cross-blocking and can be enabled at address 2203. Inrushcurrents flowing in the ground path will not cross-block tripping by the phase elements.

The cross-blocking function may also be limited to a particular time interval, which canbe set at address 2204. After expiration of this time interval, the cross-blocking func-tion will be disabled.

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Functions

The inrush restraint has an upper limit. It no longer takes effect when a (configurable)current value is surpassed since, in this case, it can only be an internal high-currentfault.

Figure 2-12 shows the logic diagram of the inrush restraint including cross-blocking.

Figure 2-12 Logic Diagram for Inrush Restraint

„1“

I2 ⋅ fn Ph A

Ia 1/2 Period

a

b

c

a > b ⋅ c

&

a

ba < b

&

67-1 Ph A PU

67-TOC Ph A PU1 Periodor

Ia InRush PU

or

or

or

&

&

&

&

Inrush Recog.50-1

Inrush Recog.50N-1

Inrush Recog.51

Inrush Recog.51N

Inrush Recog. 50-1

Inrush Recog. 67-TOC

or

&

&

S

R

Q INRUSH X-BLK

Inrush Recognition for phase andground (50-1, 51, 50N-1, 51N,67-1, 67-TOC, 67N-1, 67N-TOC)

1“

>BLOCK InRushPh

measurement/logic

InRushPhBLOCKED

InRush OFF

or

Ib InRush PU

Ic InRush PU

Gnd InRush PU

or50-1 Ph A PU

51 Ph A PU1 Periodor

or

or

&

&

&

Inrush Recog.67-1

Inrush Recog.67N-1

Inrush Recog.67-TOC

&Inrush Recog.67N-TOC

Inrush Recog. 67-1

Inrush Recog. 51T 0

2202 2nd HARMONIC

FNo. 07565

2205 I Max

2204 CROSS BLK TIMER

2203 CROSS BLOCK

2201 INRUSH REST.

FNo. 07566

FNo. 07567

FNo. 07564

FNo. 07557

FNo. 07556

FNo. 07563

YES

NO

ONOFF

FNo. 01843

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Overcurrent Protection (50, 50N, 51, 51N)

2.2.1.5 Reverse Interlocking Bus Protection

Application Exam-ple

The pickup of a time-overcurrent relay element may be blocked via binary inputs. Atthe users option, the binary inputs can be set up to block tripping when DC voltage isapplied or when DC voltage is removed. Reverse interlocking allows for faster protec-tion by eliminating the need for time-current coordination. Reverse interlocking is oftenused, for example, at generating stations in applications where a station supply trans-former supplied from the transmission grid serves internal loads of the generation sta-tion via a medium voltage bus with multiple feeders (see Figure 2-13).

When the 7SJ62/63/64 relay is used as the source-side relay in a reverse interlockingscheme, a short time delay must be set for the 50-2 element so that a load-side relayhas the chance to block tripping (Figure 2-13). The load-side relay should pickup im-mediately for down-line faults so that a blocking signal is immediately sent to thesource-side relay’s binary inputs. The load-side protective device can then initiate atime delayed trip, as long as the time delay is less than the time delay settings of thesource-side relay’s 50-1 and 50N-1 relay elements and the time multiplier settings ofthe source-side relay’s 51 and 51N relay element. The source side relay’s 50-1, 50N-1, 51 and 51N relay elements will provide redundant protection against faults in theload side relay’s zone of protection since their associated time delay settings aregreater than the load side relay’s time delay setting.

Pickup messages generated by the load-side relay are passed to a binary input of thesource-side relay as input message “>50-2 block.”.

Figure 2-13 Reverse Interlocking Protection Scheme

T50-1 T50-2 t1

T50-1 T50-2

t1

TRIP TRIP TRIP TRIP

Fault Location B: Source-side Trip Time = T50-2 = Source side 50-2 Delay

Fault Location A: Load-side Trip Time = t1Source-side Backup Trip Time = T50-1 =Source-side 50-1 Delay

BA

Normal Load Flow

50-2 Block

t1

52

52

52

50-1 50-2 50-1 50-1

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Functions

2.2.2 Programming Time-Overcurrent Settings

Selecting the time-overcurrent protection in DIGSI® 4 opens a dialog box containingthe tabs “General”, “50”, “51”, “50N”, “51N” and “Inrush Restraint” in which you canmodify the individual settings. The setting notes in this manual are structured accord-ingly.

2.2.2.1 General

50/51 The functions associated with time-overcurrent protection were established duringconfiguration of protective functions (Section 2.1.1) at address 0112 Charac. Phase. If address 0112 was set to Definite Time, then only the settings for thedefinite-time elements are available. The selection of TOC IEC or TOC ANSI makesavailable additional inverse characteristics. The superimposed high-current stage 50-2 is available in all these cases.

At address 1201 FCT 50/51, phase time-overcurrent protection may be switched ONor OFF.

50N/51N The functions associated with time-overcurrent protection were established duringconfiguration of protective functions (Section 2.1.1) at address 0113. If address 0113was set equal to Charac. Ground = Definite Time, then only the settings for thedefinite-time elements are available. Inverse characteristics may be available in addi-tion. The superimposed high-set stage 50N-2 is available in all these cases.

Depending on the parameter 0613A 50N/51N/67N w.the overcurrent protection forground currents can either operate with measured values IGnd or with the quantities3I0 calculated from the three phase currents. Devices featuring a sensitive ground cur-rent input, however, generally use the calculated quantity 3I0.

The time-overcurrent protection for ground currents can be switched ON or OFF in ad-dress 1301 FCT 50N/51N independent of the time-overcurrent protection for phasecurrents.

For ground faults characteristic, pick-up value and delay time can be set separatelyfrom those of the phase branches. This allows to use a different grading with shorterdelays and more sensitive settings for ground faults.

Manual Close Mode(Phase, Ground)

When a circuit breaker is closed into a faulted line, a high speed trip by the circuitbreaker is often desired. The manual closing feature is designed to remove the delayfrom one of the time-overcurrent elements when a circuit breaker is manually closedinto a fault. The time delay may be bypassed for one of the three time-overcurrentphase elements and one of the three time-overcurrent ground elements via an impulsefrom the external control switch, thus resulting in high speed tripping. This impulse isprolonged by a period of 300 ms. Address 1213A MANUALCLOSEMODE can be setsuch that the delay is defeated for the 50-2 element, the 50-1 element, the 51 element,or none of the elements (Inactive). Defeating the delay on just one of the three el-ements allows control over what level of fault current is required to initiate high speedtripping of a circuit breaker that is closed into a fault.

Accordingly, address 1313A MANUALCLOSEMODE is taken into account for the groundpath. It specifies for the phase and ground which pick-up value takes effect with whatdelay time if the circuit breaker is closed manually.

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Overcurrent Protection (50, 50N, 51, 51N)

External controlswitch

If the manual closing signal is not from a 7SJ62/63/64, that is, neither via the built-inoperator interface nor via a series interface, but, rather, directly from a control switch,this signal must be passed to a 7SJ62/63/64 binary input, and configured accordinglyso that the element selected for high speed tripping will be effective.

Internal controlfunction

The manual closing information must be routed via CFC (interlocking task-level) usingthe CMD_Information block, if the internal control function is used (see Figure 2-14).

Figure 2-14 Example for manual close feature using the internal control function

Inrush Restraint When applying the protection device to transformers where high inrush currents mustbe expected, 7SJ62/63/64 can make use of an inrush restraint function for the timeovercurrent stages 50-1 PICKUP, 51 PICKUP, 50N-1 PICKUP and 51N PICKUP.The inrush restraint option is enabled or disabled in 2201 INRUSH REST.. Subsec-tion 2.2.2.6 shows the characteristic values of the inrush restraint function.

2.2.2.2 Definite-Time Overcurrent Protection (50-2, 50-1)

50-2 Relay Element The pickup and delay of the 50-2 relay element are set at addresses 1202 50-2 PICKUP and 1203 50-2 DELAY respectively. The 50-2 relay element is typically uti-lized for protection against high magnitude faults. For this reason, the relay elementpickup is often set high while the delay is set short. It is always important to set thepickup and delay such that operation of the 50-2 element will coordinate with otherprotective equipment in the system.

Below is an example of how a 50-2 relay element might be set to protect a powertransformer in a radial distribution system against high magnitude internal faults:

Example: Transformer used to supply distribution bus with the following data:

Based on the data above, the following are calculated:

“IN: Control Device52 Breaker CF_D12”

“OUT: P. System Data 2>Manual Close SP”

Base Transformer Rating 16 MVATransformer Impedance (ZTX) 10%

Nominal High Side Voltage 110 kVNominal Low Side Voltage 20 kVTransformer Connection Delta-Grounded WyeHigh Side Fault MVA 1,000 MVAHigh Side Current Transformer Ratio 100 A / 1 ALow Side Current Transformer Ratio 500 A / 1 A

3-phase high side fault current @ 110kV 5250 A3-phase low side fault current @ 20kV 3928 A3-phase low side fault current @ 110kV 714 A

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Functions

The minimum pickup setting for the 50-2 element can be governed by a single inequal-ity:

If the pickup of the 50-2 relay element is set according to the inequality above, the 50-2 element will never pickup for a fault beyond the transformer’s low-side bushings,even if changing system conditions increase the high side fault MVA. Using the ine-quality above as a guide, a setting of 10.00 amperes is chosen for the 50-2 element.

At address 1203, a short time delay should be entered to prevent inrush currents frominitiating false trips.

For motor protection, the 50-2 relay element must be set smaller than the smallestphase-to-phase fault current and larger than the largest motor starting current. Sincethe maximum motor starting current is generally on the order of 1.6 times the nominalmotor current, the 50-2 phase element should be set as follows:

The potential increase in starting current caused by overvoltage conditions is alreadyaccounted for by the 1.6 factor. The 50-2 phase element may be set with no delaysince, unlike the transformer, no saturation of the cross reactance occurs in a motor.

If the reverse interlocking principle is used (see Subsection 2.2.1.5), the 50-2 elementcan be employed in a high speed bus protection scheme. With a brief safety delay en-tered at address 1203 (50 ms), the 50-2 element can be blocked for faults beyond thebus feeder breakers. The 50-1 element or 51 element will serve as redundant protec-tion for the bus. The pickup values of both the 50-2 unit and the 50-1 or 51 unit are setequal to each other. The time delay associated with the 50-1 or 51 element is thentime-coordinated with the individual bus feeder devices.

The delay set at address 1203 is in addition to the 50-2 pickup time. The delay of the50-2 element may be set to ∞. The 50-2 element will then pickup and generate a mes-sage, but will never trip. If the 50-2 element is not required at all, then the pickup valueshould be set to ∞, thus preventing pickup, trip, and the generation of a message.

50-1 Relay Element The pickup value of the 50-1 relay element (set at address 1204 50-1 PICKUP)should be set above the maximum anticipated load current. Pickup due to overloadshould never occur since the 50-1 relay element is designed only for fault protection.For this reason, a setting equal to 120 % of the expected peak load is recommendedfor line protection, and a setting equal to 140 % of the expected peak load is recom-mended for transformers and motors.

If the 7SJ62/63/64 relay is used to protect transformers with large inrush currents, theenergization stabilization feature may be used to prevent a false trip of the 50-1 relay

Transformer full load current @ 110kV(IBase-110kV)

84 A

Transformer full load current @ 20kV(IBase-20kV)

462 A

High side current transformer ratio (CTR-HS) 100 A / 1 ALow side current transformer ratio (CTR-LS) 500 A / 1 A

50-2 Pickup1

ZTX----------

IBase-110kV

CTR-HS----------------------------×>

1,6 Istartup⋅ 50-2 Pickup Iφφ Min–< <

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Overcurrent Protection (50, 50N, 51, 51N)

element. The configuration data for the inrush restraint feature is programmed at ad-dress block 22 (see Subsection 2.9.2).

The delay of the 50-1 element is set at address 1205 50-1 DELAY and should bebased on system coordination requirements.

The delay set at address 1205 is in addition to the 50-1 element’s pickup time. Thedelay of the 50-1 element may be set to ∞. The 50-1 element will then pickup and gen-erate a message, but will never trip. If the 50-1 element is not required at all, then thepickup value should be set to ∞, thus preventing pickup, trip, and the generation of amessage.

Interaction with Au-tomatic ReclosingEquipment

When reclosing occurs, it is desirable to have high speed protection against temporaryfaults. If the fault still exists after the first reclose, the 50-2 elements can be blockedand the 50-1 and/or 51 elements will provide time delay tripping. At address 1214A50-2 active, it can be specified whether or not the 50-2 elements should be super-vised by the status of an internal or external automatic reclosing device. If address1214A is set to With 79 Active, the 50-2 elements will not operate unless auto-matic reclosing is not blocked. If address 1214A is set to Always, the 50-2 elementswill always operate.

The integrated automatic reclosing function of 7SJ62/63/64 also provides the optionto individually determine for each time overcurrent stage whether tripping or blockingis to be carried out instantaneously or with time delay, unaffected by the AR (see Sub-section 2.13.1.3).

2.2.2.3 Inverse-Time Overcurrent Protection (51)

51 Relay ElementWith IEC or ANSICurves

Having set TOC IEC or TOC ANSI when configuring the protection functions (Subsec-tion 2.1.1) in address 0112 Charac. Phase, also the parameters for the inversecharacteristics are available.

Having set TOC IEC in address 0112 Charac. Phase, specify the desired IECcurve (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse)in address 1211 51 IEC CURVE. If TOC ANSI was selected in address 0112Charac. Phase, specify the desired ANSI curve (Very Inverse,Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. or Definite Inv.) in address 1212 51 ANSI CURVE.

Pickup of the 51 relay element will occur for currents greater than or equal to 110 %of the 51 element’s pickup value, and may or may not occur for currents between100 % and 110 % of the 51 element’s pickup value. Dropout of the 51 relay elementoccurs when the current decreases to 95 % of the 51 element’s pickup value. Select-ing the option Disk Emulation in address 1210 51 Drop-out, the dropout is per-formed according to the dropout characteristic as described in Subsection 2.2.1.2.

The pickup of the 51 element is set at address 1207 51 PICKUP. As is the case forthe 50-1 relay element, the pickup value of the 51 relay element should be set abovethe maximum anticipated load current. Pickup due to overload should never occursince the 51 relay element is designed only for fault protection. For this reason, a set-ting equal to 120 % of the expected peak load is recommended for line protection, anda setting equal to 140 % of the expected peak load is recommended for transformersand motors.

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Functions

The associated time multiplier becomes accessible when selecting an IEC curve ataddress 1208 51 TIME DIAL and an ANSI curve at address 1209 51 TIME DIAL.It must be coordinated with the time grading of the network.

The time multiplication factor may be set to ∞. The 51 element will then pickup andgenerate a message, but will never trip. If the 51 element is not required at all, address0112 should set to Charac. Phase = Definite Time during protective functionconfiguration.

User SpecifiedCharacteristicCurves

If address 0112 Charac. Phase = User Defined PU or User def. Reset dur-ing configuration of the user-specified curve option, a maximum of 20 value pairs (cur-rent and time) may be entered at address 1230 51/51N to represent the time-currentcharacteristic curve associated with the 51 element. This option allows point-by-pointentry of any desired curve. This option allows point-by-point entry of any desiredcurve. If address 0112 was set to User def. Reset during configuration of theuser-specified curve option, additional value pairs (current and reset time) may be en-tered at address 1231 MofPU Res T/Tp to represent the reset curve associatedwith the 51 element.

Since the entered current values are rounded off in a certain grid system of the devicebefore the editing (see Table 2-4), we recommend the use of these exact values.

Current and time values are entered as multiples of the address 1207 and 1208 set-tings. Therefore, it is recommended that addresses 1207 and 1208 be initially set to1.00 to simplify the calculation of these ratios. Once the curve is entered, the settingsat addresses 1207 and 1208 may be modified if necessary.

Upon delivery of the device, all time values are set at ∞, preventing pickup of the de-vice from initiating a trip signal.

When entering a user-specified curve, the following must be observed:

− Enter the data points in ascending order. The time overcurrent functions will sort thedata points by current values in ascending order. The graphical representation dis-plays the data points in the order they are entered.

− As few as 10 pairs of numbers may be entered at the user’s option. Each unusedpair must then be marked as unused by entering “∞” as for the time and current val-ues. It is important to view the curve to ensure that it is clear and constant.

− The current values entered should be those from Table 2-4, along with the matchingtimes. Other values for MofPU are changed to the nearest adjacent value althoughthis is not indicated.

Table 2-4 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 1.94 MofPU = 2 to 4.75 MofPU = 5 to 7.75 MofPU = 8 to 20

1.00 1.50 2.00 3.50 5.00 6.50 8.00 15.00

1.06 1.56 2.25 3.75 5.25 6.75 9.00 16.00

1.13 1.63 2.50 4.00 5.50 7.00 10.00 17.00

1.19 1.69 2.75 4.25 5.75 7.25 11.00 18.00

1.25 1.75 3.00 4.50 6.00 7.50 12.00 19.00

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Overcurrent Protection (50, 50N, 51, 51N)

− Current flows which are less than the smallest current value entered will not lead toan extension of the tripping time beyond the time associated with the smallest cur-rent value entered. The characteristic curve (see Figure 2-15) represents constanttripping time for currents less than the smallest current value entered.

Figure 2-15 Use of a User-Specified Curve

− Current flows which are greater than the largest current value entered will not leadto a reduction of the tripping time below the time associated with the largest currentvalue entered. The characteristic curve (see Figure 2-15) represents constant trip-ping time for currents greater than the largest current value entered.

The time and current value pairs are entered at address 1231 to recreate the drop-down curve. The following must be observed:

− The current values entered should be those from Table 2-5, along with the matchingtimes. Other values for MofPU are changed to the nearest adjacent value althoughthis is not indicated.

1.31 1.81 3.25 4.75 6.25 7.75 13.00 20.00

1.38 1.88 14.00

1.44 1.94

Table 2-4 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 1.94 MofPU = 2 to 4.75 MofPU = 5 to 7.75 MofPU = 8 to 20

t

I

Reset Curve Characteristic Curve

Largest Current Point

Smallest Current Point

Smallest Current Point

Largest Current Point

0.05 0.9 1 1.1 20

Table 2-5 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 0.86 MofPU = 0.84 to 0.67 MofPU = 0.66 to 0.38 MofPU = 0.34 to 0.00

1.00 0.93 0,84 0,75 0.66 0.53 0.34 0.16

0.99 0.92 0.83 0.73 0.64 0.50 0.31 0.13

0.98 0.91 0.81 0.72 0.63 0.47 0.28 0.09

0.97 0.90 0.80 0.70 0.61 0.44 0.25 0.06

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Functions

− Current flows which are less than the smallest current value entered will not lead toa reduction of the reset time below the time associated with the smallest current val-ue entered. The reset curve (see Figure 2-15) represents constant reset time forcurrents smaller than the smallest current value entered

− Current flows which are greater than the largest current value entered will not leadto an extension of the reset time beyond the time associated with the largest currentvalue entered. The reset curve (see Figure 2-15) represents constant reset time forcurrents larger than the largest current value entered.

When using DIGSI® 4 to modify settings, a dialog box is available to enter up to twentypairs of values for a characteristic curve (see Figure 2-16).

Figure 2-16 Entry and Visualization of a User Specified Characteristic Curve in DIGSI® 4

In order to represent the curve graphically, the user should click on Characteris-tic. The pre-entered curve will appear as shown in Figure 2-16.

The characteristic curve shown in the graph can be modified by placing the mouse cur-sor over a point on the curve, holding down the left mouse button, and dragging thedata point to the desired new position. Releasing the mouse button will automaticallyupdate the value in the value table.

The upper limits of the value ranges are shown by dotted lines at the top and right ex-tremes of the coordinate system. If the position of a data point lies outside these limits,the associated value will be set to “infinity”.

0.96 0.89 0.78 0.69 0.59 0.41 0.22 0.03

0.95 0.88 0.77 0.67 0.56 0.38 0.19 0.00

0.94 0.86

Table 2-5 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 0.86 MofPU = 0.84 to 0.67 MofPU = 0.66 to 0.38 MofPU = 0.34 to 0.00

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Overcurrent Protection (50, 50N, 51, 51N)

2.2.2.4 Programming Settings for Time-Overcurrent Ground Protection

General The functions associated with time-overcurrent protection were established duringconfiguration of protective functions (Section 2.1.1) at address 0113 Charac. Ground. If address 0113 was set equal to Definite Time, then only the settingsfor the definite-time elements are available. Inverse characteristics may be availablein addition. The superimposed high-set stage 50N-2 is available in all these cases.

At address 1301 FCT 50N/51N, ground time-overcurrent protection may be switchedON or OFF independent of the phase time-overcurrent protection.

Pickup values, time delays, and characteristic curves for ground protection are setseparately from the pickup values, time delays and characteristic curves associatedwith phase protection. Because of this, relay coordination for ground faults is indepen-dent of relay coordination for phase faults, and more sensitive settings can often beapplied to ground protection.

50N-2 Relay Ele-ment

The pickup and delay of the 50N-2 relay element are set at addresses 1302 50N-2 PICKUP and 1303 50N-2 DELAY respectively. The same considerations apply forthese settings as did for 50-2 settings discussed earlier.

The delay set at address 1303 is in addition to the 50N-2 element’s pickup time. Thedelay of the 50N-2 element may be set to ∞. The 50N-2 element will then pickup andgenerate a message, but will never trip. If the 50N-2 element is not required at all, thenthe pickup value should be set to ∞, thus preventing pickup, trip, and the generationof a message.

50N-1 Relay Ele-ment

The pickup value of the 50N-1 relay element (set at address 1304 50N-1 PICKUP)should be set below the minimum anticipated ground fault current in the relay’s zoneof protection.

If the 7SJ62/63/64 relay is used to protect transformers or motors with large inrush cur-rents, the energization stabilization feature may be used to prevent a false trip of the50N-1 relay element. It can be enabled or disabled for both the phase current and theground current in address 2201 INRUSH REST.. The characteristic values of the in-rush restraint are listed in Subsection 2.2.2.6.

The delay of the 50N-1 element is set at address 1305 50N-1 DELAY and should bebased on system coordination requirements.

The delay set at address 1305 is in addition to the 50N-1 element’s pickup time. Thedelay of the 50N-1 element may be set to ∞. The 50N-1 element will then pickup andgenerate a message, but will never trip. If the 50N-1 element is not required at all, thenthe pickup value should be set to ∞, thus preventing pickup, trip, and the generationof a message.

Interaction with Au-tomatic ReclosingEquipment

When reclosing occurs, it is desirable to have high speed protection against temporaryfaults. If the fault still exists after the first reclose, the 50N-2 elements can be blockedand the 50N-1 and/or 51N elements will provide time delay tripping. At address 1314A50N-2 active, it can be specified whether or not the 50N-2 elements should be su-pervised by the status of an internal or external automatic reclosing device. If address1314A is set to With 79 Active, the 50N-2 elements will not operate unless auto-matic reclosing is not blocked. If address 1314A is set to Always, the 50N-2 elementswill always operate.

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The integrated automatic reclosing function of 7SJ62/63/64 also provides the optionto individually determine for each time overcurrent stage whether tripping or blockingis to be carried out instantaneously or with time delay, unaffected by the AR (see Sub-section 2.13.1.3).

2.2.2.5 Inverse-Time Overcurrent Protection (51N)

51N Relay Elementwith IEC or ANSICurves

Setting TOC IEC in address 0113 Charac. Ground when configuring the protectionfunctions (Subsection 2.1.1), also the parameters for the inverse characteristics areavailable. Set the desired IEC curve (Normal Inverse, Very Inverse, Extreme-ly Inv. or Long Inverse) in address 1311 51 IEC CURVE. Setting TOC ANSI in address 0113 Charac. Ground, specify the desired ANSI curve (Very Inverse,Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. or Definite Inv.) in address 1312 51 ANSI CURVE.

Pickup of the 51N relay element will occur for currents greater than or equal to 110 %of the 51N pickup value, and may or may not occur for currents between 100 % and110 % of the 51 element’s pickup value. Dropout of the 51N relay element occurswhen the current decreases to 95 % of the 51N element’s pickup value. If option Disk Emulation in enabled in address 1310 51 Drop-out, the dropout is performedaccording to the dropout characteristic as described in Subsection 2.2.1.2.

The pickup value of the 51N element is set at address 1307 51N PICKUP. As is thecase for the 50N-1 relay element, the pickup value of the 51N relay element should beset below the minimum anticipated ground fault current in the relay’s zone of protec-tion.

The 51N element time multiplication factor for an IEC curve is set at address 130851N TIME DIAL and in address 1309 51N TIME DIAL for an ANSI curve andshould be based on system coordination requirements.

The time multiplication factor may also be set to ∞. The 51N element will then pickupand generate a message, but will never trip. If the 51N element is not required at all,address 0113 should be set to Definite Time during protective function configura-tion (see Section 2.1.1).

2.2.2.6 Inrush Restraint

Inrush restraint will only operate, and is only accessible, if enabled at address 0122InrushRestraint during configuration of protective functions. If the function is notrequired, address 0122 should be set to Disabled. In address 2201 INRUSH REST.the function is switched ON or OFF jointly for the overcurrent stages 50-1 PICKUP, 51 PICKUP, 50N-1 PICKUP and 51N PICKUPON.

The inrush restraint is based on the evaluation of the 2nd harmonic present in the in-rush current. Upon delivery from the factory, the device is programmed to initiate in-rush restraint when the second harmonic component of the measured current exceeds15 % of the total current. This value is identical for all phases and ground, and may bemodified at address 2202. Under normal circumstances, this setting will not need tobe changed. However, in special situations, this setting may be as low as 12 %.

The effective duration of the cross-blocking 2203 CROSS BLK TIMER can be set toa value between 0 s (harmonic restraint active for each phase individually) and a max-

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Overcurrent Protection (50, 50N, 51, 51N)

imum of 180 s (harmonic restraint of a phase blocks also the other phases for thespecified duration).

The maximum current where inrush restraint can operate is set at address 2205 I Max

2.2.3 Settings

In the list below, the setting ranges and default setting values for the pickup currentsare for a device with a nominal current rating IN = 1 A. For a nominal current rating IN= 5 A, multiply the Setting Options values and Default Setting values by 5. Considerthe current transformer ratios when setting the device with primary values.

Note: Addresses to which the letter “A“ is attached can only be modified via theDIGSI® 4 software at “Additional Settings“.

Addr. Setting Title Setting Options Default Setting Comments

1201 FCT 50/51 ONOFF

ON 50, 51 Phase Time Overcurrent

1213A MANUAL CLOSE 50-2 instantaneously50 -1 instantaneously51 instantaneouslyInactive

50-2 instantane-ously

Manual Close Mode

1301 FCT 50N/51N ONOFF

ON 50N, 51N Ground Time Overcur-rent

1313A MANUALCLOSE-MODE

50N-2 instantaneously50N-1 instantaneously51N instantaneouslyInactive

50N-2 instantane-ously

Manual Close Mode

2201 INRUSH REST. OFFON

OFF Inrush Restraint

1202 50-2 PICKUP 0.10..35.00 A; ∞ 2.00 A 50-2 Pickup

1203 50-2 DELAY 0.00..60.00 sec; ∞ 0.00 sec 50-2 Time Delay

1204 50-1 PICKUP 0.10..35.00 A; ∞ 1.00 A 50-1 Pickup

1205 50-1 DELAY 0.00..60.00 sec; ∞ 0.50 sec 50-1 Time Delay

1214A 50-2 active Alwayswith 79 active

Always 50-2 active

1207 51 PICKUP 0.10..4.00 A 1.00 A 51 Pickup

1208 51 TIME DIAL 0.05..3.20 sec; ∞ 0.50 sec 51 Time Dial

1209 51 TIME DIAL 0.50..15.00; ∞ 5.00 51 Time Dial

1210 51 Drop-out InstantaneousDisk Emulation

Disk Emulation Drop-out characteristic

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1211 51 IEC CURVE Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1212 51 ANSI CURVE Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1230 51/51N 1.00..20.00 I / Ip; ∞0.01..999.00 Time Dial

51/51N

1231 MofPU Res T/Tp 0.05..0.95 I / Ip; ∞0.01..999.00 Time Dial

Multiple of Pickup <-> T/Tp

1302 50N-2 PICKUP 0.05..35.00 A; ∞ 0.50 A 50N-2 Pickup

1303 50N-2 DELAY 0.00..60.00 sec; ∞ 0.10 sec 50N-2 Time Delay

1304 50N-1 PICKUP 0.05..35.00 A; ∞ 0.20 A 50N-1 Pickup

1305 50N-1 DELAY 0.00..60.00 sec; ∞ 0.50 sec 50N-1 Time Delay

1314A 50N-2 active Alwayswith 79 Active

Always 50N-2 active

1307 51N PICKUP 0.05..4.00 A 0.20 A 51N Pickup

1308 51N TIME DIAL 0.05..3.20 sec; ∞ 0.20 sec 51N Time Dial

1309 51N TIME DIAL 0.50..15.00; ∞ 5.00 51N Time Dial

1310 51N RESET InstantaneousDisk Emulation

Disk Emulation Drop-Out Characteristic

1311 51N IEC CURVE Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1312 51N ANSI CURVE Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1330 50N/51N 1.00..20.00 I / Ip; ∞0.01..999.00 Time Dial

50N/51N

1331 MofPU Res T/TEp 0.05..0.95 I / Ip; ∞0.01..999.00 Time Dial

Multiple of Pickup <-> T/TEp

2202 2nd HARMONIC 10..45 % 15 % 2nd. harmonic in % of funda-mental

2203 CROSS BLOCK NOYES

NO Cross Block

Addr. Setting Title Setting Options Default Setting Comments

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Overcurrent Protection (50, 50N, 51, 51N)

2.2.3.1 Information List

2204 CROSS BLK TIMER 0.00..180.00 sec 0.00 sec Cross Block Time

2205 I Max 0.30..25.00 A 7.50 A Maximum Current for InrushRestraint

F.No. Alarm Comments

01761 50(N)/51(N) PU 50(N)/51(N) O/C PICKUP

01791 50(N)/51(N)TRIP 50(N)/51(N) TRIP

01704 >BLK 50/51 >BLOCK 50/51

01721 >BLOCK 50-2 >BLOCK 50-2

01722 >BLOCK 50-1 >BLOCK 50-1

01723 >BLOCK 51 >BLOCK 51

01751 50/51 PH OFF 50/51 O/C switched OFF

01752 50/51 PH BLK 50/51 O/C is BLOCKED

01753 50/51 PH ACT 50/51 O/C is ACTIVE

01762 50/51 Ph A PU 50/51 Phase A picked up

01763 50/51 Ph B PU 50/51 Phase B picked up

01764 50/51 Ph C PU 50/51 Phase C picked up

01800 50-2 picked up 50-2 picked up

01805 50-2 TRIP 50-2 TRIP

01810 50-1 picked up 50-1 picked up

01815 50/51 TRIP 50/51 I> TRIP

01820 51 picked up 51 picked up

01825 51 TRIP 51 TRIP

01804 50-2 TimeOut 50-2 Time Out

01814 50-1 TimeOut 50-1 Time Out

01824 51 Time Out 51 Time Out

01852 50-2 BLOCKED 50-2 BLOCKED

01851 50-1 BLOCKED 50-1 BLOCKED

01855 51 BLOCKED 51 BLOCKED

01910 >INSTANT. 50-2 >50-2 instantaneously

01912 >INSTANT. 50-1 >50-1 instantaneously

01914 >INSTANT. 51 >51 instantaneously

01911 50-2 INSTANT. 50-2 instantaneously

01913 50-1 INSTANT. 50-1 instantaneously

Addr. Setting Title Setting Options Default Setting Comments

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01915 51 INSTANT. 51 instantaneously

01714 >BLK 50N/51N >BLOCK 50N/51N

01724 >BLOCK 50N-2 >BLOCK 50N-2

01725 >BLOCK 50N-1 >BLOCK 50N-1

01726 >BLOCK 51N >BLOCK 51N

01756 50N/51N OFF 50N/51N is OFF

01757 50N/51N BLK 50N/51N is BLOCKED

01758 50N/51N ACT 50N/51N is ACTIVE

01765 50N/51NPickedup 50N/51N picked up

01831 50N-2 picked up 50N-2 picked up

01833 50N-2 TRIP 50N-2 TRIP

01834 50N-1 picked up 50N-1 picked up

01836 50N-1 TRIP 50N-1 TRIP

01837 51N picked up 51N picked up

01839 51N TRIP 51N TRIP

01832 50N-2 TimeOut 50N-2 Time Out

01835 50N-1 TimeOut 50N-1 Time Out

01838 51N TimeOut 51N Time Out

01854 50N-2 BLOCKED 50N-2 BLOCKED

01853 50N-1 BLOCKED 50N-1 BLOCKED

01856 51N BLOCKED 51N BLOCKED

01916 >INSTANT. 50N-2 >50N-2 instantaneously

01918 >INSTANT. 50N-1 >50N-1 instantaneously

01983 >INSTANT. 51N >51N instantaneously

01917 50N-2 INSTANT. 50N-2 instantaneously

01919 50N-1 INSTANT. 50N-1 instantaneously

01984 51N INSTANT. 51N instantaneously

07563 >BLOCK InRushPh >BLOCK InRush Phase

01840 PhA InrushBlk Phase A trip blocked by inrush detection

01841 PhB InrushBlk Phase B trip blocked by inrush detection

01842 PhC InrushBlk Phase C trip blocked by inrush detection

01843 INRUSH X-BLK Cross blk: PhX blocked PhY

07551 50-1 InRushPU 50-1 InRush picked up

07552 50N-1 InRushPU 50N-1 InRush picked up

F.No. Alarm Comments

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Overcurrent Protection (50, 50N, 51, 51N)

07553 51 InRushPU 51 InRush picked up

07554 51N InRushPU 51N InRush picked up

07556 InRush OFF InRush OFF

07557 InRushPhBLOCKED InRush Phase BLOCKED

07558 InRush Gnd BLK InRush Ground BLOCKED

07559 67-1 InRushPU 67-1 InRush picked up

07560 67N-1 InRushPU 67N-1 InRush picked up

07561 67-TOC InRushPU 67-TOC InRush picked up

07562 67N-TOCInRushPU 67N-TOC InRush picked up

07565 Ia InRush PU Phase A InRush picked up

07566 Ib InRush PU Phase B InRush picked up

07567 Ic InRush PU Phase C InRush picked up

07564 Gnd InRush PU Ground InRush picked up

F.No. Alarm Comments

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Functions

2.3 Directional Overcurrent Protection (67, 67N)

General The 7SJ62/63/64 features directional overcurrent protection. Therefore, this devicecan be applied to systems where proper protection depends on knowing both the mag-nitude of the fault current and the direction of energy flow to the fault location. Direc-tional overcurrent protection requires that the device be connected to both currenttransformers and voltage transformers. The time-overcurrent protection (non-direc-tional) described in Section 2.2 may operate as overlapping back-up protection or maybe disabled. Additionally, the user may select between directional overcurrent protec-tion and non-directional overcurrent protection on a relay element by relay element ba-sis.

To better understand the benefits of directional overcurrent protection, consider theparallel transformers shown in Figure 2-17. These transformers are designated as Iand II and are supplied from a single source. For a fault internal to Transformer I, someof the fault current will flow from Bus A through Transformer I to the fault while the re-maining fault current flows from Bus A through Transformer II and Bus B to the fault.In order to avoid tripping out Bus B for this fault, the load side relays protecting Trans-former II must coordinate with the load side relays protecting Transformer I. Likewise,for a fault internal to Transformer II, some of the fault current will flow from Bus Athrough Transformer II to the fault while the remaining fault current flows from Bus Athrough Transformer I and Bus B to the fault. In order to avoid tripping out Bus B forthis fault, the load side relays protecting Transformer I must coordinate with the loadside relays protecting Transformer II. If the load side relays on Transformer I andTransformer II are conventional overcurrent elements, it is clearly impossible for theload side relays on Transformer I and Transformer II to coordinate properly with eachother for both faults internal to Transformer I and Transformer II.

By employing directional overcurrent relays as the load side relays protecting Trans-formers I and II, coordination between the relays is no longer necessary since the loadside relays on Transformer I will only detect faults internal to Transformer I and theload side relays on Transformer II will only detect fault internal to Transformer II. It isimportant to note that the directional overcurrent relays must be polarized toward thefaults they are to protect, which does not necessarily correspond to the direction ofnormal power flow.

For the same reasons discussed above, directional overcurrent protection is also usedto protect transmission lines and distribution feeders operated in a loop configurationor supplied from two directions, as shown in Figure 2-18.

Phase and ground directional overcurrent protection may be turned on and off inde-pendently. Directional overcurrent relay elements are available with a wide array of di-rectional curves and characteristic time-current curves.

There are four definite time (Instantaneous elements with optional timers) and two in-verse time directional overcurrent elements in the device. The definite time (Instanta-neous) directional elements include two phase elements and two ground elements.The definite time directional phase elements are designated 67-2 and 67-1 whereasthe definite time directional ground elements are designated 67N-2 and 67N-1. Theinverse time directional elements include a directional phase element designated as67-TOC and a directional ground element designated as 67N-TOC.

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Directional Overcurrent Protection (67, 67N)

Figure 2-17 Overcurrent Protection for Parallel Transformers

Figure 2-18 Transmission Lines with Sources at Each End

Depending on the setting of parameter 0613A 50N/51N/67N w.the ground currentstage can operate either with measured values Ignd or with the values 3I0 calculatedfrom the three phase currents. Devices featuring a sensitive ground current input,however, generally use the calculated quantity 3I0.

All directional overcurrent elements, inverse and definite time, enabled in the devicemay be blocked via an external signal to the binary inputs of the device or via auto-matic reclosure (cyclically). Removal of the external signal to the binary input will re-enable these elements. Also, a feature described as Manual Close Mode can be con-figured to improve fault clearing times associated with Switch-on-to-Fault Conditions.

I

II

A B

t

t

Time-Overcurrent Protection

Directional Overcurrent Protection

Direction ofLoad Flow

t

Time-Overcurrent Protection

Directional Overcurrent Protection

t

G G

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Under this situation, the time delay may be defeated for one of the three directionalovercurrent phase elements and one of the three directional overcurrent ground ele-ments via an impulse from the external control switch, thus resulting in high speed trip-ping. This impulse is prolonged by a period of 300 ms. The directional phase andground elements utilized for high speed tripping in this situation are selected at ad-dresses 1513 and 1613 respectively.

Pickup and delay settings may be quickly adjusted to system requirements via dynam-ic setting swapping (see Section 2.4).

Tripping by the 67-1, 67-TOC, 67N-1, and 67N-TOC elements may be blocked for in-rush conditions by utilizing the inrush restraint feature.

Table 2-6 gives an overview of the interconnection to other functions of 7SJ62/63/64.

2.3.1 Description of Directional Overcurrent Protection

2.3.1.1 Definite Time, Directional Overcurrent Protection

67-2, 67N-2 The 67-2 and 67N-2 directional overcurrent elements, phase and ground currents arecompared separately with the pickup values of the 67-2 and 67N-2 relay elements.Currents in the set direction above the pickup values are detected and recorded withinthe device. After the user-configured time delay has elapsed, a trip signal is issued.

The dropout value of the definite time, directional overcurrent elements is roughlyequal to 95% of the pickup value for currents greater than or equal to 30% of the nom-inal current of the device.

These stages can be blocked by the automatic reclosure feature.

Figure 2-20 shows by way of example the logic diagram for the 67-2 relay element.

Table 2-6 Interconnection to other functions

Directional TimeOvercurrent

Protection Stages

Connection toAutomaticReclosing

ManualCLOSE

Dynamic Cold-Load Pickup

InrushRestraint

67-1 • • • •

67-2 • • •

67-TOC • • • •

67N-1 • • • •

67N-2 • • •

67N-TOC • • • •

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Directional Overcurrent Protection (67, 67N)

Figure 2-19 Logic Diagram for the 67-2 Relay Element

If parameter MANUALCLOSEMODE is set to 50-2 instant. and manual close detec-tion applies, the pick-up is tripped instantaneously, also for blocking of the stage viabinary input. The same applies to 79 AR 67-2 inst. and the binary input for in-stantaneous tripping.

67-1, 67N-1 The 67-1 and 67N-1 directional overcurrent elements, phase and ground currents arecompared separately with the pickup values of the 67-1 and 67N-1 relay elements.Currents in the set direction above the pickup values are detected and recorded withinthe device. After the user-configured time delay has elapsed, a trip signal is issued.

If the inrush restraint feature is enabled, and an inrush condition exist, no trippingtakes place, but a message is recorded and displayed indicating when the overcurrentelement time delay elapses.

Different messages are recorded and displayed appear depending on whether trippingtakes place or the time delay expires without tripping.

The dropout value of the definite time, directional overcurrent elements is roughlyequal to 95% of the pickup value for currents greater than or equal to 30% of the nom-inal current of the device.

These stages can be blocked by the automatic reclosure feature.

1513A MANUALCLOSEMODE

Inactive67-TOC instant.67-1 instant.67-2 instant.

„1“

or

67-2 Ph A PU

&

T 0

or

or

or

AB

C

>BLOCK 67-2

>BLK 67/67-TOC 67 BLOCKED

or67/67-TOC OFF

MeasurementPickup-/Tripping Logic

&

67-2 picked up

67-2 TRIP

67-2 Time Out

79 AR 67-2 blkor 67-2 BLOCKED

or79 AR 67-2 inst.

>INSTANT. 67-2.

FNo. 02642

„1“

Manual Close&

FNo. 02649

FNo. 02647

FNo. 02655

FNo. 02652

FNo. 02651

FNo. 02604

FNo. 02615

1501 FCT 67/67-TOC

FNo. 14501

OFF

ON

1503 67-2 DELAY

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Figure 2-20 shows by way of example the logic diagram for the 67-1 relay element.

Figure 2-20 Logic Diagram for the 67-1 Relay Element

2.3.1.2 Inverse Time, Directional Overcurrent Protection (67-TOC, 67N-TOC)

Inverse time, directional overcurrent protection, the 67-TOC and 67N-TOC relay ele-ments may contain IEC characteristic curves or ANSI characteristic curves dependingon the model ordered. A user-specified curve may also be applied to the inverse time,directional overcurrent relay elements. The curves and associated formulas are givenin Technical Specifications (Figures 4-1 to 4-6 in Section 4.3). During configuration ofthe 67-TOC and 67N-TOC characteristic curves, the definite time directional relay el-ements (67-2, 67-1, 67N-2, and 67N-1) are enabled (see Subsection 2.3.1.1).

1513A MANUALCLOSEMODE

Inactive67-TOC instant.67-1 instant.67-2 instant.

or

Aφ67-1 PU

&

T 0

or

or

≥1

AB

C

67-1 TRIP

67-1 picked up

67-1 Time Out

„1“

>BLOCK 67-1

>BLK 67/67-TOC 67 BLOCKED

or

Measurement/Logic

67/67-TOC OFF

or79 AR 67-1 blk.

67-1 BLOCKED

67-1 InRushPU&

&

&

Inrush Recognition 67-1 (see Figure 2-12)

&

„1“

Manual Close&

or79 AR 67-1 inst.

>INSTANT. 67-1

1501 FCT 67N/67N-

1505 67-1 DELAY

FNo. 02660

FNo. 02665

FNo. 02664

FNo. 02621

FNo. 02604

FNo. 02637

FNo. 02652

FNo. 02651

FNo. 14503

FNo. 07559

Forward

„1“Reverse

Phase A forward

Phase A reverse

Direction Determination

Undefined

FNo. 02628

FNo. 02632

OFF

ON

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Directional Overcurrent Protection (67, 67N)

Pickup and Trip-ping

Each phase and ground current is separately compared with the pickup values of the67-TOC and 67N-TOC relay elements. When the currents in the 67-TOC and 67N-TOC relay elements exceed the corresponding pickup value by a factor of 1.1, the el-ement picks up and a message is reported, if the current is in the set direction. If theinrush restraint feature is being utilized, then the message reported is dependent onwhether or not an inrush condition exists. Pickup of a 67-TOC or 67N-TOC relay ele-ment is based on the rms value of the fundamental harmonic. When the 67-TOC and67N-TOC elements pickup, the time delay of the trip signal is calculated using an in-tegrated measurement process. The calculated time delay is dependent on the actualfault current flowing and the selected time-current characteristic curve. Once the timedelay elapses, a trip signal is issued.

If the inrush restraint feature is enabled, and an inrush condition exist, no trippingtakes place, but a message is recorded and displayed indicating when the overcurrentelement time delay elapses. The r.m.s. values of the fundamental waves are used forthe pickup.

The characteristic curves of the 67-TOC and 67N-TOC relay elements may be select-ed independently of each other. In addition, pickup, time multipliers, and time dials forthe 67-TOC and 67N-TOC elements may be individually set.

Dropout For IEC orANSI Curves

Dropout of an element using an IEC or ANSI curve occurs when the current decreasesto about 95 % of the pickup value if instantaneous reset is selected, or 90 % of thepickup value if disk emulation is selected. When instantaneous reset is selected, resetof the element occurs without delay. When disk emulation is selected, reset occursjust as it would for an electromechanical relay utilizing an induction disk.

For disk emulation, the reset process begins after fault current is interrupted. Resetcorresponds to the unwinding of an induction disk. A subsequent pickup of the relayelement prior to full reset will result in a reduced tripping time delay. The reduced trip-ping time delay will be based on the degree to which the relay had reset when the sub-sequent pickup occurred. When the current in the relay element is between 90 % and95 % of the pickup value following dropout, neither disk movement in the tripping orreset direction is simulated.

Disk emulation offers advantages when the inverse time, directional overcurrent relayelements must be coordinated with conventional electromechanical overcurrent relayslocated toward the source.

User SpecifiedCurves

When user specified curves are utilized, the time-current characteristic curve may bedefined point by point. Up to 20 pairs of values (current, time) may be entered. Therelay element then approximates the curve using linear interpolation.

When utilizing user specified time-current curves, the reset curve may be user speci-fied as well. This is advantageous when the inverse time, directional overcurrent pro-tection must be coordinated with conventional electromechanical overcurrent relayslocated toward the source. If user specified reset curves are not utilized, the relay el-ement drops out when current decreases to about 95% of the relay element’s pickupvalue, and immediate reset takes place.

Figure 2-21 shows by way of example the logic diagram for the overcurrent stage 67-TOC of the inverse directional time-overcurrent protection of the phase currents.

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Figure 2-21 Logic Diagram for the 67-TOC Relay Element

2.3.1.3 Determination of Direction

Determination of fault direction is performed independently for each phase elementand for the ground element.

Methods ofDeterminingDirection

For the a-phase directional elements, direction is determined by comparing Ia with Vbcat the relay location. For the b-phase and c-phase directional elements, direction is de-termined by comparing Ib with Vca and Ic with Vab at the relay location. For phase-to-ground, phase-to-phase, and double phase-to-ground faults, sufficient voltage magni-tude is available at the relay location to determine direction for all possible fault loca-tions. For three-phase faults, stored voltage values are used to determine direction un-less sufficient voltage magnitudes exists at the relay location. The stored voltage val-ues correspond to the voltage magnitudes and angles during the last two cycles where

1513A MANUALCLOSEMODE

Inactive67-2 instant.67-1 instant.67-TOC instant.

or

Aφ67-TOC PU

&

or

or

or

AB

C

67-TOC TRIP

67-TOC pickedup

67-TOC Time Out

„1“

>BLOCK 67-TOC

>BLK 67/67-TOC 67 BLOCKED

or

Measurement/Logic

67/67-TOC OFF

or79 AR 67-TOC blk

67-TOC BLOCKED

67-TOC InRushPU&

&

&

Inrush Recognition 67-TOC (s. Figure 2-12)

&

„1“

Manual Close &

or79 AR 67-TOC inst.

>INSTANT 67-TOC

1501 FCT 67N/67N-TOC

1508 51 TIME DIAL

FNo. 02670

FNo. 02675

FNo. 02674

FNo. 02622

FNo. 02604

FNo. 02669

FNo. 02652

FNo. 02651

FNo. 14506

FNo. 07561

Forward

„1“Reverse

Phase A forward

Phase A reverse

Direction Determination

Undefined

FNo. 02628

FNo. 02632

OFF

ON

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Directional Overcurrent Protection (67, 67N)

sufficient voltage magnitude was available to determine direction. When sufficient volt-age magnitude is not available to determine direction, direction is locked until sufficientvoltage returns. When closing into a three-phase fault, if voltage magnitude is not suf-ficient to determine direction and no stored voltage values exist in the buffer, the relayelement will trip without regard to fault direction. In all other cases the voltage magni-tude will be sufficient for determining the direction.

For the directional ground fault elements, direction is determined by comparing V0 withI0. The current I0 may be obtained from a current transformer connected in the residualpath or may be calculated by the device from the three phase currents. The voltageV0 may be calculated by the device from the three phase-to-ground voltages or thevoltage 3V0 may be obtained by connecting the secondary windings of the voltagetransformers in a broken delta configuration. If the magnitude of V0 or 3V0 is not suf-ficient to determine direction, then the directional ground elements will not initiate a tripsignal. If the current I0 cannot be determined because only two current transformersare utilized or the current transformers are connected in an open delta configuration,then the directional ground elements will not be able to function.

Phase-to-ground faults are detected by the directional ground element, and may bedetected by the directional phase element associated with the faulted phase if themagnitude of the fault current is sufficient. Phase-to-phase faults are detected by thetwo directional phase elements associated with the faulted phases. Double phase-to-ground faults are detected by the directional ground element, and may be detected bythe directional phase elements associated with the faulted phases if the magnitude ofthe fault current flowing in the phase conductors is sufficient. Three-phase faults, ofcourse, are detected by all directional phase elements, but not by the directionalground elements. As was stated earlier, in order for any ground fault to be detected bya directional ground element, current transformers and voltage transformers must beconnected so as to supply sufficient magnitudes of zero sequence currents and volt-age.

For a phase-to-ground fault, the voltage supplied to the directional phase element pro-tecting the faulted phase is 90° out of phase with the phase-to-ground voltage existingon the faulted phase at the relay location (see Figure 2-22). The device compensatesfor this phase difference by adding 90° when the phase sequence is “abc” and sub-tracting 90° when the phase sequence is “acb.” The resulting voltage is called the po-larizing voltage. For phase-to-phase faults, the angles of the polarizing voltages asso-ciated with the directional phase elements which protect the faulted phases can varybased upon the location of the fault with respect to the device. The relationship be-tween the polarizing voltage angle and the phase current angle for a phase-to-phasefault is identical to the relationship between the polarizing voltage angle and the phasecurrent angle for a phase-to-ground fault only when the fault location and relay loca-tion are identical.

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Figure 2-22 Voltages Used for Direction Determination

Table 2-7 shows the assignment of voltage and current values for the determination of fault di-rection for various types of short-circuit faults.

1) or 3 * V0= |Vag + Vbg + Vcg|, depending on type of connection for the voltages

The direction curve for the directional phase relay element is shown in Figure 2-23 ina complex R-X diagram. The curve illustrates the operating direction of the relay interms of the impedance viewed by the directional phase relay element, that is, the ratio

VA

VC VBUL2–L3

VC VBVBC

VCA

VA

VAB

a) Phase to Ground Fault (a-g) b) Phase to Phase Fault (a-c)

Table 2-7 Voltage and Current Values for the Determination of Fault Direction

A B C GROUND

Pick up Current Voltage Current Voltage Current Voltage Current Voltage

A Ia Vbc

B Ib Vca

C Ic Vab

G I0 V01)

A, G Ia Vbc I0 V01)

B, G Ib Vca I0 V01)

C, G Ic Vab I0 V01)

A, B Ia Vbc Ib Vca

B, C Ib Vca Ic Vab

C, A Ia Vbc Ic Vab

A, B, G Ia Vbc Ib Vca I0 V01)

B, C, G Ib Vca Ic Vab I0 V01)

C, A, G Ia Vbc Ic Vab I0 V01)

A, B, C Ia Vbc Ib Vca Ic Vab

A, B, C, G Ia Vbc Ib Vca Ic Vab I0 V01)

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Directional Overcurrent Protection (67, 67N)

of the directional phase element polarizing voltage to the directional phase elementcurrent. Line ‘a’ represents the directional limit line, and when the protective relayviews an impedance which lies on the same of the directional limit line as the shadedarea, the fault is assumed to be in the forward direction.

For a phase-to-phase fault, the actual directional limit line will deviate from the theo-retical when the fault location is different than the relay location because the polarizingvoltage angle varies with fault location (see Figure 2-22b). For a b-to-c fault, the direc-tional limit for the b-phase directional element rotates clockwise as the location be-tween the relay and fault increases (dotted line ‘b’ in Figure 2-23). Likewise, the direc-tional limit for the c-phase directional element rotates counterclockwise as the locationbetween the relay and fault increases (dotted line c in Figure 2-23). Rotation of the di-rectional limit in this manner is irrelevant in practice, since the impedance viewed bythe relay either lies in the first or third quadrant of the R-X diagram.

Figure 2-23 Torque angle limits

2.3.1.4 Reverse Interlocking for Looped Lines

ApplicationExample

The reverse interlocking principle may be applied to a group of transmission lines anddistribution feeders which operate in a looped configuration or which are supplied fromtwo directions. High speed protection is possible using reverse interlocking by havingthe directional overcurrent elements block high speed non-directional overcurrent el-ements as shown in Figure 2-24. This scheme is feasible when the lengths of the linesare not too great and when pilot wires are available for signal transfer.

For each line, a separate data transfer path is required to facilitate signal transmissionin each direction. These transfer paths carry the blocking signals to the opposite endof the lines. In addition, at each line terminal, two directional overcurrent elementsmust be employed, one polarized to operate for faults in the forward direction (towardthe line) and one polarized to operate for faults in the reverse direction. If a line is en-ergized, but open at one end, an interruption of the transfer path is noted and reportedwith a delay.

jX

R

Line

ab

c

Torqueangle

Reserve

Forwards

Impedance Z

Torque angle limits

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During a line fault, the directional overcurrent element that detects faults in the forward(line) direction will block the high speed operation of the non-directional overcurrentelements in the reverse direction. The non-directional relays that are blocked are gen-erally located at the same substation. In addition, a message is generated regardingthe fault direction and transmitted to the relays located in the reverse direction. Duringa fault in the reverse direction, the directional overcurrent element that detects faultsin the reverse direction will block the high-speed operation of the non-directional over-current element at the opposite end of the line. The relay at the opposite end of theline is generally located at a different substation, thus blocking is accomplished via thepilot wires. In addition, a message is generated regarding the fault direction and trans-mitted to the relay located at the opposite end of the line.

Figure 2-24 Reverse Interlocking Using Directional Elements

Figure 2-25 Logic Diagram for Generation of Fault Direction Signals

The directional overcurrent elements can be coordinated with each other to providetime delayed backup protection for the reverse interlocking scheme.

Figure 2-25 shows the logic diagram for the generation of fault direction signals.

7SJ6*7SJ6*7SJ6*50-1

7SJ6* 7SJ6* 7SJ6*

7SJ6*

7SJ6*

− Blocking

− Non-directional Ele-ment

− Directional Element

52 52 52 52 52 52G G

52

52

50-1 50-1 50-1 50-1 50-1

50-1

50-1

50-1

Pickup of 50-1 A φ Direction deter-mination Phase A

forwards

reverse

Pickup of 50N-1 Direction deter-mination Ground

forwards

reverse

Phase A forward

Phase A reverse

Ground forward

Ground reverse

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Directional Overcurrent Protection (67, 67N)

2.3.2 Programming Directional Overcurrent Settings

In contrast to the main functions of non-directional phase and ground overcurrent pro-tection, all other protective functions are disabled upon device delivery. The accom-panying addresses appear in the overview of setting groups only when the functionsare configured as present (Section 2.1.1). The functions may be enabled by selectinga time characteristic(i.e. Definite, ANSI, or User-Defined) during configuration.

When selecting the directional time-overcurrent protection in DIGSI® 4 a dialog boxappears with several tabs for setting individual parameters. Depending on the func-tional scope specified during configuration of the protective functions in addresses0115 67/67-TOC and 0116 67N/67N-TOC the number of tabs can vary.

2.3.2.1 General

Phase CurrentStages

If address 0115 67/67-TOC was set to Definite Time, then only the settings forthe definite-time elements are available. Selecting TOC IEC or TOC ANSI the inversecharacteristics will be available in addition. The superimposed directional stages 67-2and 67-1 apply in all these cases.

At address 1501 FCT 67/67-TOC, directional phase overcurrent protection may beswitched ON or OFF.

Ground CurrentStage

At address 1601 FCT 67N/67N-TOC, directional ground time-overcurrent protectionmay be switched ON or OFF independent of the directional phase time-overcurrent pro-tection.

Depending on the parameter 0613A 50N/51N/67N w., the device can either oper-ate using measured values Ignd or the quantities 3I0 calculated from the three phasecurrents. Devices featuring a sensitive ground current input, however, generally usethe calculated value 3I0.

Pickup values, time delays, and characteristic curves for ground protection are setseparately from the pickup values, time delays and characteristic curves associatedwith directional phase protection. Because of this, relay coordination for ground faultsis independent of relay coordination for phase faults, and more sensitive settings canoften be applied to directional ground protection.

Manual Close Mode(Phase, Ground)

When a circuit breaker is closed into a faulted line, a high speed trip by the circuitbreaker is often desired. The manual closing feature is designed to remove the delayfrom one of the directional overcurrent elements when a circuit breaker is manuallyclosed into a fault. The time delay may be bypassed via an impulse from the externalcontrol switch, thus resulting in high speed tripping. This impulse is prolonged by a pe-riod of 300 ms. Address 1513A MANUALCLOSEMODE can be set such that the delay isdefeated for the 67-2 element, the 67-1 element, the 67-TOC element, or none of theelements. Accordingly, address 1613A MANUALCLOSEMODE is considered for theground path address. Defeating the delay on just one of the three elements (phaseand ground) allows control over what level of fault current is required to initiate highspeed tripping of a circuit breaker that is closed into a fault.

External ControlSwitch

If the manual closing signal is not from a 7SJ62/63/64, that is, neither via the built-inoperator interface nor via a series interface, but, rather, directly from a control ac-

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knowledgment switch, this signal must be passed to a 7SJ62/63/64 binary input, andconfigured accordingly so that the element selected for high speed tripping will be ef-fective.

Internal controlfunction

The manual closing information must be routed via CFC (interlocking task-level) usingthe CMD_Information block, if the internal control function is used (see Figure 2-26).

Figure 2-26 Example for manual close feature using the internal control function

Direction Limit Lineand DirectionalOrientation

At address 1515A Normal Load, the directional limit line may be set asInductive(135×), Resistive (90×), or Capacitive(45×) (see Figure 2-27).As a rule, the option Inductive(135×) is used since power system elements areinductive by nature.

The directional orientation may be established at address 1516 67N Direction. Di-rectional overcurrent protection normally operates in the direction of the facility to beprotected (line, transformer, etc.). If the device is properly connected in accordancewith one of the circuit diagrams in Appendix A3, this is the Forward direction.

Figure 2-27 Definition of the Directional Limit Line (addresses 1515A and 1516)

If the voltage used to determine fault direction drops below the minimum value, record-ed voltage values are available from a buffer based on the last two cycles of sufficientvoltage. If recorded voltage is not available due to closing in on a fault, tripping will takeplace without directional determination.

Direction Line Limitand Direction Ori-entation (Ground)

At address 1615A Normal Load, the directional limit line may be set asInductive(135×), Resistive (90×), or Capacitive(45×) (see Figure 2-27).As a rule, the option Inductive(135×) is used since power system elements areinductive by nature.

The directional orientation may be established at address 1616 67N Direction. Di-rectional overcurrent protection normally operates in the direction of the facility to beprotected (line, transformer, etc.). If the device is properly connected in accordancewith one of the circuit diagrams in Appendix A.3, this is the Forward direction.

“IN: Control Device52 Breaker CF_D12”

“OUT: P. System Data 2>Manual Close SP”

R

jX

INDUCTIVE (135°)

R

jX

RESISTIVE (90°)

R

jX

CAPACITIVE (45°)

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Directional Overcurrent Protection (67, 67N)

Figure 2-28 Definition of the Directional Limit Line (addresses 1615A and 1616)

If the voltage used to determine fault direction drops below the minimum value, record-ed voltage values are available from a buffer based on the last two cycles of sufficientvoltage. If recorded voltage is not available due to closing in on a fault, a tripping willnot occur.

Inrush Restraint When applying the protection device to transformers where high inrush currents areto be expected, 7SJ62/63/64 can make use of an inrush restraint function for the di-rectional overcurrent stages 50-1 PICKUP, 51 PICKUP, 50N-1 PICKUP and 51N PICKUP together with the non-directional overcurrent stages. The inrush restraint op-tion is enabled or disabled at 2201 INRUSH REST. (at the parameters for the non-directional time overcurrent protection) Subsection 2.2.2.6 shows the characteristicvalues of the inrush restraint feature.

2.3.2.2 Definite-Time, Directional Overcurrent Protection (67-2, 67-1)

67-2 Relay Element The pickup and delay of the 67-2 relay element are set at addresses 1502 67-2 PICKUP and 1503 67-2 DELAY respectively. In setting the pickup and delay of the67-2 element, the same considerations apply as did for the determining the pickup anddelay of the 50-2 element in Subsection 2.2.2.1.

The delay set at address 1503 is in addition to the 67-2 pickup time. The delay of the67-2 element may be set to ∞. The 67-2 element will then pickup and generate a mes-sage, but will never trip. If the 67-2 element is not required at all, then the pickup valueshould be set to ∞ thus preventing pickup, trip, and the generation of a message.

67-1 Relay Element The pickup value of the 67-1 relay element (set at address 1504 67-1 PICKUP)should be set above the maximum anticipated load current. Pickup due to overloadshould never occur since the 50-1 relay element is designed only for fault protection.For this reason, a setting equal to 120 % of the expected peak load is recommendedfor line protection, and a setting equal to 140 % of the expected peak load is recom-mended for transformers and motors.

If the 7SJ62/63/64 relay is used to protect transformers or motors with large inrush cur-rents, the inrush restraint feature may be used to prevent a false trip of the 67-1 relayelement. The configuration data for the inrush restraint feature is programmed at ad-dress block 22 (see Subsection 2.9.2).

The delay of the 67-1 element is set at address 1505 67-1 DELAY and should bebased on system coordination requirements. The delay for directional elements is usu-ally set shorter than the delay for non-directional elements since the non-directionalelements overlap the directional elements as backup protection.

R

jX

INDUCTIVE (135°)

R

jX

RESISTIVE (90°)

R

jX

CAPACITIVE (45°)

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For parallel transformers supplied from a single source (see Figure 2-17), the delay ofthe directional elements located on the load side of the transformers may be set tozero if desired.

The delay set at address 1505 is in addition to the 67-1 pickup time. The delay of the67-1 element may be set to ∞. The 67-1 element will then pickup and generate a mes-sage, but will never trip. If the 67-1 element is not required at all, then the pickup valueshould be set to ∞ thus preventing pickup, trip, and the generation of a message.

Interaction withAutomaticReclosingEquipment

When reclosing occurs, it is desirable to have high speed protection against temporaryfaults. If the fault still exists after the first reclose, the 67-2 elements can be blockedand the 67-1 elements will provide time delay tripping. At address 1514A 67 active,it can be specified whether or not the 67-2 elements should be supervised by the sta-tus of an internal or external automatic reclosing device. If address 1514A is set toWith 79 Active, the 67-2 elements will not operate unless automatic reclosing isnot blocked. If address 1514A is set to Always, the 67-2 elements will always oper-ate.

Die integrierte Wiedereinschaltautomatik im 7SJ62/63/64 bietet außerdem die Mög-lichkeit, für jede der gerichteten Überstromzeitschutzstufen getrennt festzulegen, obunverzögert, unbeeinflusst von der AWE mit der eingestellten Zeit ausgelöst oder blo-ckiert werden soll (siehe Abschnitt 2.13.1.3).

2.3.2.3 Inverse-Time Directional Overcurrent Protection (67-TOC)

67-TOC RelayElement With IEC orANSI Curves

Having set TOC IEC or TOC ANSI in address 0115 67/67-TOC when configuringthe protective functions (Subsection 2.1.1), the parameters for the inverse character-istics will also be available.

Pickup of the 67-TOC relay element will occur for currents greater than or equal to110% of the 67-TOC element’s pickup value, and may or may not occur for currentsbetween 100% and 110% of the 67-TOC element’s pickup value. Dropout of the 67-TOC relay element occurs when the current decreases to 95 % of the 67-TOC ele-ment’s pickup value.

The pickup of the 67-TOC element is set at address 1507 67/67-TOC. As is the casefor the 67-1 relay element, the pickup value of the 67-TOC relay element should beset above the maximum anticipated load current. Pickup due to overload should neveroccur since the 67-TOC relay element is designed only for fault protection. For thisreason, a setting equal to 120 % of the expected peak load is recommended for lineprotection, and a setting equal to 140 % of the expected peak load is recommendedfor transformers and motors.

The 67-TOC element time multiplication factor for an IEC curve is set at address 1508 67 TIME DIAL and in address 1509 51c TIME DIAL for an ANSI curve and shouldbe based on system coordination requirements.

The time multiplication factor may be set to ∞. The 67-TOC element will then pickupand generate a message, but will never trip. If the 67-TOC element is not required atall, address 0115 should be set to Definite Time during protective function con-figuration (see Section 2.1.1).

If Disk Emulation is selected at address 1510 67-TOC Drop-out, then resetoccurs according to the reset curve as described in Subsection 2.2.1.2.

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Directional Overcurrent Protection (67, 67N)

If address 0115 67/67-TOC was set to TOC IEC, you can specify the desired IECcurve (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse)in address 1511 51N IEC CURVE. Having selected TOC ANSI in address 0115 67/67-TOC, you can specify the desired ANSI curve (Very Inverse, Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. oder Definite Inv.) in address 1512 51N ANSI CURVE.

User SpecifiedCurves

If address 0115 67/67-TOC was set to User Defined PU or User def. Resetduring configuration of the user-specified curve option, a maximum of 20 value pairs(current and time) may be entered at address 1530 67 to represent the time-currentcharacteristic curve associated with the 67-TOC element. This option allows point-by-point entry of any desired curve.

If address 0115 was set to User def. Reset during configuration of the user-spec-ified curve option, additional value pairs (current and reset time) may be entered at ad-dress 1531 MofPU Res T/Tp to represent the reset curve associated with the 67-TOC element.

Current and time values are entered as multiples of the address 1507 and 1508 set-tings. Therefore, it is recommended that addresses 1507 and 1508 be initially set to1.00 to simplify the calculation of these ratios. Once the curve is entered, the settingsat addresses 1507 and 1508 may be modified if necessary.

Upon delivery of the device, all time values are set at ∞, preventing pickup of the de-vice from initiating a trip signal.

When entering a user-specified curve, the following must be observed:

− The value pairs should be entered in increasing sequence. As few as 10 pairs ofnumbers may be entered at the user’s option. Each unused pair must then bemarked as unused by entering “∞“for the time and current values. It is important toview the curve to ensure that it is clear and constant.

− The current values entered should be those from Table 2-8, along with the matchingtimes. Other values for MofPU are changed to the nearest adjacent value althoughthis is not indicated.

− Current flows which are less than the smallest current value entered will not lead toa reduction of the reset time below the time associated with the smallest current val-

Table 2-8 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 1.94 MofPU = 2 to 4.75 MofPU = 5 to 7.75 MofPU = 8 to 20

1.00 1.50 2.00 3.50 5.00 6.50 8.00 15.00

1.06 1.56 2.25 3.75 5.25 6.75 9.00 16.00

1.13 1.63 2.50 4.00 5.50 7.00 10.00 17.00

1.19 1.69 2.75 4.25 5.75 7.25 11.00 18.00

1.25 1.75 3.00 4.50 6.00 7.50 12.00 19.00

1.31 1.81 3.25 4.75 6.25 7.75 13.00 20.00

1.38 1.88 14.00

1.44 1.94

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ue entered. The reset curve (see Figure 2-29 right) represents constant reset timefor currents smaller than the smallest current value entered.

− Current flows which are greater than the largest current value entered will not leadto an extension of the reset time beyond the time associated with the largest currentvalue entered. The reset curve (see Figure 2-29 right) represents constant resettime for currents larger than the largest current value entered.

The time and current value pairs are entered at address 1531 to recreate the drop-down curve. The following must be observed:

Figure 2-29 Use of a User-Specified Curve

The current values entered should be those from Table 2-9, along with the matchingtimes. Other values for MofPU are changed to the nearest adjacent value although thisis not indicated.

− Current flows which are greater than the largest current value entered will not leadto an extension of the reset time beyond the time associated with the largest currentvalue entered. The reset curve (see Figure 2-29) represents constant reset time forcurrents larger than the largest current value entered.

t

I

Reset Curve Characteristic Curve

Largest Current Point

Smallest Current Point

Smallest Current Point

Largest Current Point

0.05 0.9 1 1.1 20

Table 2-9 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 0.86 MofPU = 0.84 to 0.67 MofPU = 0.66 to 0.38 MofPU = 0.34 to 0.00

1.00 0.93 0.84 0.75 0.66 0.53 0.34 0.16

0.99 0.92 0.83 0.73 0.64 0.50 0.31 0.13

0.98 0.91 0.81 0.72 0.63 0.47 0.28 0.09

0.97 0.90 0.80 0.70 0.61 0.44 0.25 0.06

0.96 0.89 0.78 0.69 0.59 0.41 0.22 0.03

0.95 0.88 0.77 0.67 0.56 0.38 0.19 0.00

0.94 0.86

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Directional Overcurrent Protection (67, 67N)

− Current flows which are less than the smallest current value entered will not lead toa reduction of the reset time below the time associated with the smallest current val-ue entered. The reset curve (see Figure 2-29) represents constant reset time forcurrents smaller than the smallest current value entered.

2.3.2.4 Programming Settings for Directional Overcurrent Ground Protection

General The functions associated with time-overcurrent protection were established duringconfiguration of protective functions (Section 2.1.1) at address 0116 67N/67N-TOC.If address 0116 was set to Definite Time, then only the settings for the definite-time elements are available. Select 67N/67N-TOC = TOC IEC or = TOC ANSI to haveavailable inverse characteristics in addition. The superimposed directional high-setstage 67N-2 is available in all these cases.

At address 1601 FCT 67N/67N-TOC, directional ground time-overcurrent protectionmay be switched ON or OFF independent of the directional phase time-overcurrent pro-tection.

Pickup values, time delays, and characteristic curves for ground protection are setseparately from the pickup values, time delays and characteristic curves associatedwith directional phase protection. Because of this, relay coordination for ground faultsis independent of relay coordination for phase faults, and more sensitive settings canoften be applied to directional ground protection.

67N-2 RelayElement

The pickup and delay of the 67N-2 relay element are set at addresses 1602 67N-2 PICKUP and 1603 67N-2 DELAY respectively. The same considerations apply forthese settings as did for 67-2 settings discussed earlier.

The delay set at address 1603 is in addition to the 67N-2 pickup time. The delay ofthe 67N-2 element may be set to ∞. The 67N-2 element will then pickup and generatea message, but will never trip. If the 67N-2 element is not required at all, then the pick-up value should be set to ∞, thus preventing pickup, trip, and the generation of a mes-sage.

67N-1 RelayElement

The pickup value of the 67N-1 relay element (set at address 1604 67N-1 PICKUP)should be set below the minimum anticipated ground fault current in the relay zone ofprotection.

If the 7SJ62/63/64 relay is used to protect transformers or motors with large inrush cur-rents, the inrush restraint feature may be used to prevent a false trip of the 67N-1 relayelement. The configuration data for the inrush restraint feature is programmed at ad-dress block 22 (at the parameters for the non-directional time overcurrent protection,see Subsection 2.2.2.6).

The delay of the 67N-1 element is set at address 1605 67N-1 DELAY and should bebased on system coordination requirements.

The delay set at address 1605 is in addition to the 67N-1 pickup time. The delay ofthe 67N-1 element may be set to ∞. The 67N-1 element will then pickup and generatea message, but will never trip. If the 67N-1 element is not required at all, then the pick-up value 67N-1 PICKUP should be set to ∞ thus preventing pickup, trip, and the gen-eration of a message.

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2.3.2.5 Inverse-Time Directional Overcurrent Protection (67N-TOC)

67N-TOC with IECor ANSI Curves

Having set TOC IEC in address 0116 67N/67N-TOC when configuring the protec-tive functions (Section 2.1.1), the parameters for the inverse characteristics will alsobe available. Specify in address 1611 67N-TOC IEC the desired IEC curve (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse). If you have setTOC ANSI at address 0116 67N/67N-TOC, you can specify the desired ANSI curve(Very Inverse, Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. or Definite Inv.) in address 1612 67N-TOC ANSI.

Pickup of the 67N-TOC relay element will occur for currents greater than or equal to110% of the 67N-TOC element’s pickup value, and may or may not occur for currentsbetween 100% and 110% of the 67N-TOC element’s pickup value. Dropout of the 51Nrelay element occurs when the current decreases to 95% of the 67N-TOC element’spickup value. If Disk Emulation is selected at address 1610 67N-TOC RESET,then reset occurs according to the reset curve as described in Subsection 2.3.1.2.

The pickup value of the 67N-TOC element is set at address 1607 67N-TOC PICKUP.The corresponding time dial for an IEC curve is set at address 1608 67N-TOC T-DIAL and for an ANSI curve at address 1609 67 TIME DIAL and should be basedon system coordination requirements. As is the case for the 67N-1 relay element, thepickup value of the 67N-TOC relay element should be set below the minimum antici-pated ground fault current in the relay zone of protection.

The time multiplication factor may also be set to ∞. The 67N-TOC element will thenpickup and generate a message, but will never trip. If the 67N-TOC element is not re-quired at all, address 0116 should be set to Definite Time during protective func-tion configuration (see Section 2.1.1).

User SpecifiedCurves

If address 0116 67N/67N-TOCwas set to User Defined PU or User def. Resetduring configuration of the user-specified curve option, a maximum of 20 value pairs(current and time) may be entered at address 1630 M.of PU TD to represent thetime-current characteristic curve associated with the 67N-TOC element. This optionallows point-by-point entry of any desired curve.

If address 0116 was set to User def. Reset during configuration of the user-spec-ified curve option, additional value pairs (current and reset time) may be entered at ad-dress 1631 I/IEp Rf T/TEp to represent the reset curve associated with the 67N-TOC element.

Current and time values are entered as multiples of the address 1607 and 1608 set-tings. Therefore, it is recommended that addresses 1607 67N-TOC PICKUP and1608 67N-TOC T-DIAL be initially set to 1.00 to simplify the calculation of theseratios. Once the curve is entered, the settings at addresses 1607 and 1608 may bemodified if necessary.

Upon delivery of the device, all time values are set at ∞, preventing pickup of the de-vice from initiating a trip signal.

When entering user specified curve data, the same instructions apply as in Subsection2.3.2.3 for the phase elements.

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Directional Overcurrent Protection (67, 67N)

2.3.3 Settings

In the list below, the setting ranges and default setting values for the pickup currentsare for a device with a nominal current rating IN = 1 A. For a nominal current ratingIN = 5 A, multiply the Setting Options values and Default Setting values by 5. Considerthe current transformer ratios when setting the device with primary values.

Note: Addresses to which the letter “A“ is attached can only be modified via theDIGSI® 4 software at “Additional Settings“.

Addr. Setting Title Setting Options Default Setting Comments

1501 FCT 67/67-TOC OFFON

OFF 67, 67-TOC Phase Time Over-current

1513A MANUALCLOSE-MODE

67-2 instantaneously67-1 instantaneously67-TOC instantaneouslyInactive

67-2 instantane-ously

Manual Close Mode

1515A Normal Load Inductive (135°)Resistive (90°)Capacitive(45°)

Inductive (135°) Normal Load (Torque angle ofdir. fct)

1516 67 Direction ForwardReverse

Forward Phase Direction

1601 FCT 67N/67N-TOC OFFON

OFF 67N, 67N-TOC Ground TimeOvercurrent

1613A MANUALCLOSE-MODE

67N-2 instantaneously67N-1 instantaneously67N-TOC instantaneouslyInactive

67N-2 instantane-ously

Manual Close Mode

1615A Normal Load Inductive (135°)Resistive (90°)Capacitive(45°)

Inductive (135°) Normal Load (Torque angle ofdir. fct)

1616 67N Direction ForwardReverse

Forward Ground Direction

1502 67-2 PICKUP 0.10..35.00 A; ∞ 2.00 A 67-2 Pickup

1503 67-2 DELAY 0.00..60.00 sec; ∞ 0.10 sec 67-2 Time Delay

1504 67-1 PICKUP 0.10..35.00 A; ∞ 1.00 A 67-1 Pickup

1505 67-1 DELAY 0.00..60.00 sec; ∞ 0.50 sec 67-1Time Delay

1514A 67 active with 79 activealways

always 67 active

1507 67-TOC PICKUP 0.10..4.00 A 1.00 A 67-TOC Pickup

1508 67 TIME DIAL 0.05..3.20 sec; ∞ 0.50 sec 67-TOC Time Dial

1509 67 TIME DIAL 0.50..15.00; ∞ 5.00 67-TOC Time Dial

1510 67-TOC Drop-out InstantaneousDisk Emulation

Disk Emulation Drop-Out Characteristic

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2.3.3.1 Information List for Directional Ground Overcurrent Protection

1511 67- IEC CURVE Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1512 67- ANSI CURVE Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1530 67 1.00..20.00 I / Ip; ∞0.01..999.00 Time Dial

67

1531 MofPU Res T/Tp 0.05..0.95 I / Ip; ∞0.01..999.00 Time Dial

Multiple of Pickup <-> T/Tp

1602 67N-2 PICKUP 0.05..35.00 A; ∞ 0.50 A 67N-2 Pickup

1603 67N-2 DELAY 0.00..60.00 sec; ∞ 0.10 sec 67N-2 Time Delay

1604 67N-1 PICKUP 0.05..35.00 A; ∞ 0.20 A 67N-1 Pickup

1605 67N-1 DELAY 0.00..60.00 sec; ∞ 0.50 sec 67N-1 Time Delay

1614A 67N active alwayswith 79 active

always 67N active

1607 67N-TOC PICKUP 0.05..4.00 A 0.20 A 67N-TOC Pickup

1608 67N-TOC T-DIAL 0.05..3.20 sec; ∞ 0.20 sec 67N-TOC Time Dial

1609 67N-TOC T-DIAL 0.50..15.00; ∞ 5.00 67N-TOC Time Dial

1610 67N-TOC RESET InstantaneousDisk Emulation

Disk Emulation Drop-Out Characteristic

1611 67N-TOC IEC Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1612 67N-TOC ANSI Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1630 M.of PU TD 1.00..20.00 I / Ip; ∞0.01..999.00 Time Dial

Multiples of PU Time-Dial

1631 I/IEp Rf T/TEp 0.05..0.95 I / Ip; ∞0.01..999.00 Time Dial

67N TOC

Addr. Setting Title Setting Options Default Setting Comments

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Directional Overcurrent Protection (67, 67N)

F.No. Alarm Comments

02691 67/67N pickedup 67/67N picked up

02696 67/67N TRIP 67/67N TRIP

02604 >BLK 67/67-TOC >BLOCK 67/67-TOC

02615 >BLOCK 67-2 >BLOCK 67-2

02621 >BLOCK 67-1 >BLOCK 67-1

02622 >BLOCK 67-TOC >BLOCK 67-TOC

02651 67/67-TOC OFF 67/67-TOC switched OFF

02652 67 BLOCKED 67/67-TOC is BLOCKED

02653 67 ACTIVE 67/67-TOC is ACTIVE

02642 67-2 picked up 67-2 picked up

02649 67-2 TRIP 67-2 TRIP

02660 67-1 picked up 67-1 picked up

02665 67-1 TRIP 67-1 TRIP

02670 67-TOC pickedup 67-TOC picked up

02675 67-TOC TRIP 67-TOC TRIP

02692 67 A picked up 67/67-TOC Phase A picked up

02693 67 B picked up 67/67-TOC Phase B picked up

02694 67 C picked up 67/67-TOC Phase C picked up

02647 67-2 Time Out 67-2 Time Out

02664 67-1 Time Out 67-1 Time Out

02674 67-TOC Time Out 67-TOC Time Out

02628 Phase A forward Phase A forward

02629 Phase B forward Phase B forward

02630 Phase C forward Phase C forward

02632 Phase A reverse Phase A reverse

02633 Phase B reverse Phase B reverse

02634 Phase C reverse Phase C reverse

02637 67-1 BLOCKED 67-1 is BLOCKED

02655 67-2 BLOCKED 67-2 is BLOCKED

02669 67-TOC BLOCKED 67-TOC is BLOCKED

14501 >INSTANT. 67-2 >67-2 instantaneously

14503 >INSTANT. 67-1 >67-1 instantaneously

14505 >INSTANT 67-TOC >67-TOC instantaneously

14502 67-2 INSTANT. 67-2 instantaneously

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14504 67-1 INSTANT. 67-1 instantaneously

14506 67-TOC INSTANT. 67-TOC instantaneously

02614 >BLK 67N/67NTOC >BLOCK 67N/67N-TOC

02616 >BLOCK 67N-2 >BLOCK 67N-2

02623 >BLOCK 67N-1 >BLOCK 67N-1

02624 >BLOCK 67N-TOC >BLOCK 67N-TOC

02656 67N OFF 67N/67N-TOC switched OFF

02657 67N BLOCKED 67N/67N-TOC is BLOCKED

02658 67N ACTIVE 67N/67N-TOC is ACTIVE

02646 67N-2 picked up 67N-2 picked up

02679 67N-2 TRIP 67-2 TRIP

02681 67N-1 picked up 67N-1 picked up

02683 67N-1 TRIP 67N-1 TRIP

02684 67N-TOCPickedup 67N-TOC picked up

02686 67N-TOC TRIP 67N-TOC TRIP

02695 67N picked up 67N/67N-TOC picked up

02648 67N-2 Time Out 67N-2 Time Out

02682 67N-1 Time Out 67N-1 Time Out

02685 67N-TOC TimeOut 67N-TOC Time Out

02636 Ground reverse Ground reverse

02635 Ground forward Ground forward

02668 67N-2 BLOCKED 67N-2 is BLOCKED

02659 67N-1 BLOCKED 67N-1 is BLOCKED

02677 67N-TOC BLOCKED 67N-TOC is BLOCKED

14507 >INSTANT. 67N-2 >67N-2 instantaneously

14509 >INSTANT. 67N-1 >67N-1 instantaneously

14511 >INST. 67N-TOC >67N-TOC instantaneously

14508 67N-2 INSTANT. 67N-2 instantaneously

14510 67N-1 INSTANT. 67N-1 instantaneously

14512 67N-TOC INSTANT 67N-TOC instantaneously

F.No. Alarm Comments

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Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc)

2.4 Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc)

General With the dynamic cold load pickup feature, it is possible to dynamically increase thepickup values of the directional and non-directional overcurrent relay elements whendynamic cold load pickup conditions are anticipated (i.e. after a long period of zerovoltage). By allowing pickup settings to increase dynamically, it is not necessary to in-corporate dynamic cold load capability in the normal pickup settings, and directionaland non-directional overcurrent protection may be set more sensitive.

As a further option the pickup thresholds can be modified in dependence of an auto-matic reclosure function that is ready or not ready.

It is possible to change pickup thresholds and delay times.

2.4.1 Description of Dynamic Cold Load Pick-Up Function

Effect When using the dynamic cold load pick-up function, there are two primary methodsused by the device to determine if the protected equipment is de-energized:

• Via a binary input, an auxiliary contact in the circuit breaker can be used to deter-mine if the circuit breaker is open or closed. If the circuit breaker is open, the equip-ment will be considered de-energized. If this method is chosen, address 1702 Start Condition should be set to Breaker Contact.

• The current flow monitoring threshold (Subsection ) may be used to determine if theequipment is de-energized. If this method is chosen, address 1702 should be setto No Current.

If the device determines the protected equipment is de-energized via one of the meth-ods above, a time CB Open Time is started and after its expiration the increasedthresholds take effect.

In addition, switching between parameters can be tripped by two further signals:

• By signal “79M Auto Reclosing ready“ of the internal automatic reclosure function(address 1702 Start Condition = 79 ready). Thus the protection thresholdsand the tripping times can be changed if automatic reclosure is ready for tripping(see also Section 2.13).

• Irrespective of the setting of parameter 1702 Start Condition the release forthe cold load pickup can always be granted via the binary input “>ACTIVATE CLP“.

Figure 2-31 shows the logic diagram for dynamic cold load pick-up function.

When the auxiliary contact or current criterion detects that the system is de-energized,i.e. the circuit breaker is open, the CB open time (CB Open Time) starts. As soon asthe time period expired, the greater thresholds become enabled.

When the protected equipment is re-energized (i.e. the device receives input via a bi-nary input that the circuit breaker is closed or the current flowing through the circuit

Note:

Dynamic Cold Load Pickup is in addition to the 4 setting groups (A to D), which areconfigured separately.

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breaker increases above the current flow monitoring threshold set at address 0212 BkrClosed I MIN), a second time delay referred to as the Active Time is initiated.Once the Active Time elapses, the pickup values of the relay elements return totheir normal settings. The Active Time is set at address 1704 and controls how longdynamic cold load pick-up settings remain in place once the equipment is re-ener-gized. Upon re-energizing of the equipment, if the measured current values are belowthe normal pickup settings, an alternative time delay referred to as the Stop Time isalso initiated. As in the case with the Active Time, once the Stop Time elapses,the pickup values of relay elements change from the dynamic cold load pickup valuesto their normal settings. The Stop Time is set at address 1705 and controls how longdynamic cold load pick-up settings remain in place given that measured currents arebelow the normal pickup settings. This Stop Time is typically set very short since theactual measurement of currents indicates dynamic cold load conditions will not inad-vertently pickup the relay elements. To defeat the Stop Time from switching the relayelement pickup settings back to normal, it may be set to ∞ or blocked via a binary input.

If a relay element picks up while the dynamic settings are enabled, elapse of the Ac-tive Time or Stop Time will not restore the normal pickup settings until drop outof the relay element occurs based on the dynamic settings.

When the dynamic setting values have taken effect via the binary input “>ACTIVATE CLP“ or the signal “79M Auto Reclosing ready” and this cause drops out, the “normal”settings are restored immediately, even if a pick up is to follow.

If the dynamic cold load pick-up function is blocked via a binary input, all triggered tim-ers will be immediately reset and all normal settings will be restored. If blocking occursduring an on-going fault with dynamic cold load pick-up functions enabled, the timersof all directional and non-directional overcurrent relay elements will be stopped, andthen restarted based on their normal duration.

During power up of the protective relay with an open circuit breaker, the time delay setat address 1703 CB Open Time is started, and is processed using the normal set-tings. Therefore, when the circuit breaker is closed, the normal settings are effective.

Figure 2-30 shows a timing diagram, Figure 2-31 describes the logic for cold load pick-up function.

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Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc)

Figure 2-30 Cold Load Pickup Timing Sequence

Breaker

Closed

Open

“CB open“ “CB open“

“Active Time“

Possible shorterCLP, due to“Stop Time“

Operating State

“Normal“PickUp Levels

“CLP“ setting active“normal setting active“

“Stop Time“

Pickup

Dropout

Trip, if increasedpower demand ispresent after “Ac-tive Time“ expired

increased power consumptionafter long outage

Active Time

Address 1704

CB Open Time

Address 1703

Stop Time

Address 1705

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Figure 2-31 Logic Diagram for Dynamic Cold Load Pickup Feature

2.4.2 Programming Settings

2.4.2.1 General

Dynamic cold load Pickup feature can only be enabled if address 0117 Coldload Pickup was set to Enabled during configuration of protective functions. If the func-

Aus

In

„1“

>BLOCK CLP

CLP running

CLP BLOCKED

CLP OFF

or

52a Configured

52b Configuredor

&

or

FNo. 01730 FNo. 01995

FNo. 01996

FNo. 01994

1701 COLDLOAD PICKUP

Ia, Ib, Ic

„1“

&

S Q

R

>BLK CLP stpTim

or

>52-a

>52-b

or&

or

&

Ι<Max. of

T 0

&

Dynamic PickupT 0

T 0

Dyn set. ACTIVE

Normal Pickup

79 ready&

or

>ACTIVATE CLPFNo. 01997

FNo. 01732

FNo. 04601

FNo. 04602

FNo. 01731

1702 Start Condition

0212 BkrClosed I MIN

1703 CB Open Time

1704 Active Time

1705 Stop Time

79 readyBreaker Contact

No Current

Measurement/Logic

Circuit-Breaker open

Exceeding one of the dynamic cold pick-up thresholds ofthe directional or non-directional overcurrent elements(Address blocks 18 to 21)

Exceeding one of the „normal“ pick-up thresholds of the di-rectional or non-directional overcurrent elements

Processing of thecold load pick-upsettings in the overcurrentelements

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Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc)

tion is not required, address 0117 should be set to Disabled. In address 1701Coldload Pickup can be set ON or OFF.

Depending on the start conditions for the cold load pickup function address 1702Start Condition is set to either No Current, Breaker Contact or to 79 ready. Naturally, the option Breaker Contact can only be selected if the devicereceives an information on the position of the circuit breaker via at least one binary in-put. The option 79 ready modifies dynamically the pickup thresholds of the direction-al and non-directional time overcurrent protection when the automatic reclosing fea-ture is ready. For controlling the cold load pickup the automatic reclosing function pro-vides the internal signal “79M Auto Reclosing ready”. It is always active when auto re-closure is available, activated, unblocked and ready for a further cycle (see also sidetitle “Controlling Directional/Non-Directional Overcurrent Protection Stages via ColdLoad Pickup“ in Subsection 2.13.2).

Time Delays There are no specific procedures on how to set the time delays at addresses 1703 CB Open Time, 1704 Active Time and 1705 Stop Time. These time delays mustbe based on the specific loading characteristics of the equipment being protected, andshould be selected to allow the brief overloads associated with dynamic cold load con-ditions.

2.4.2.2 Non-Directional Phase Elements

The dynamic pickup values and time delays associated with non-directional overcur-rent phase protection are set at address block 18.

The dynamic pickup and delay settings for the 50-2 element are set at addresses1801 50c-2 PICKUP and 1802 50c-2 DELAY respectively; the dynamic pickup anddelay settings for the 50-1 element are set at addresses 1803 50c-1 PICKUP and1804 50c-1 DELAY respectively; and the pickup, time multiplier (for IEC curves), andtime dial (for ANSI curves) settings for the 51 element are set at addresses 1805 51c PICKUP, 1806, and 1807 respectively (51c TIME DIAL).

2.4.2.3 Non-Directional Ground Elements

The dynamic pickup values and time delays associated with non-directional overcur-rent ground protection are set at address block 19.

The dynamic pickup and delay settings for the 50N-2 element are set at addresses1901 50Nc-2 PICKUP and 1902 50Nc-2 DELAY respectively; the dynamic pickupand delay settings for the 50N-1 element are set at addresses 1903 50Nc-1 PICKUPand 1904 50Nc-1 DELAY respectively; and the pickup, time multiplier (for IECcurves), and time dial (for ANSI curves) settings for the 51N element are set at ad-dresses 1905 51Nc PICKUP, 1906, and 1907 respectively (51c TIME DIAL).

2.4.2.4 Directional Phase Elements

The dynamic pickup values and time delays associated with directional overcurrentphase protection are set at address block 20.

The dynamic pickup and delay settings for the 67-2 element are set at addresses2001 67c-2 PICKUP and 2002 67c-2 DELAY respectively; the dynamic pickup and

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delay settings for the 67-1 element are set at addresses 2003 67c-1 PICKUP and2004 67c-1 DELAY respectively; and the pickup, time multiplier (for IEC curves), andtime dial (for ANSI curves) settings for the 67-TOC element are set at addresses 200567c-TOC PICKUP, 2006, and 2006 respectively (67c-TOC T-DIAL).

2.4.2.5 Directional Ground Element

The dynamic pickup values and time delays associated with directional overcurrentground protection are set at address block 21.

The dynamic pickup and delay settings for the 67N-2 element are set at addresses2101 50Nc-2 PICKUP and 2102 67Nc-2 DELAY respectively; the dynamic pickupand delay settings for the 67N-1 element are set at addresses 2103 67Nc-1 PICKUPand 2104 67Nc-1 DELAY respectively; and the pickup, time multiplier (for IECcurves), and time dial (for ANSI curves) settings for the 67N-TOC element are set ataddresses 2105 67Nc-TOC PICKUP, 2106, and 2107 respectively (67Nc-TOC T-DIAL).

2.4.2.6 Settings for Dynamic Cold Load Adjustments

In the list below, the setting ranges and default setting values for the pickup currentsare for an equipment with a nominal current rating IN = 1 A. For a nominal current rat-ing IN = 5 A, multiply the Setting Options values and Default Setting values by 5. Con-sider the current transformer ratios when setting the equipment with primary values.

Addr. Setting Title Setting Options Default Setting Comments

1701 COLDLOAD PIK-KUP

OFFON

OFF Cold-Load-Pickup Function

1702 Start Condition No CurrentBreaker Contact79M Auto Reclosing ready

No Current Start Condition

1703 CB Open Time 0..21600 sec 3600 sec Circuit Breaker OPEN Time

1704 Active Time 1..21600 sec 3600 sec Active Time

1705 Stop Time 1..600 sec; ∞ 600 sec Stop Time

1801 50c-2 PICKUP 0.10..35.00 A; ∞ 10.00 A 50c-2 Pickup

1802 50c-2 DELAY 0.00..60.00 sec; ∞ 0.00 sec 50c-2 Time Delay

1803 50c-1 PICKUP 0.10..35.00 A; ∞ 2.00 A 50c-1 Pickup

1804 50c-1 DELAY 0.00..60.00 sec; ∞ 0.30 sec 50c-1 Time Delay

1805 51c PICKUP 0.10..4.00 A; ∞ 1.50 A 51c Pickup

1806 51c TIME DIAL 0.05..3.20 sec; ∞ 0.50 sec 51c Time dial

1807 51c TIME DIAL 0.50..15.00; ∞ 5.00 51c Time dial

1901 50Nc-2 PICKUP 0.05..35.00 A; ∞ 7.00 A 50Nc-2 Pickup

1902 50Nc-2 DELAY 0.00..60.00 sec; ∞ 0.00 sec 50Nc-2 Time Delay

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Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc)

2.4.2.7 Information List for Dynamic Cold Load Setting Adjustments

1903 50Nc-1 PICKUP 0.05..35.00 A; ∞ 1.50 A 50Nc-1 Pickup

1904 50Nc-1 DELAY 0.00..60.00 sec; ∞ 0.30 sec 50Nc-1 Time Delay

1905 51Nc PICKUP 0.10..4.00 A; ∞ 1.00 A 51Nc Pickup

1906 51Nc T-DIAL 0.05..3.20 sec; ∞ 0.50 sec 51Nc Time Dial

1907 51Nc T-DIAL 0.50..15.00; ∞ 5.00 51Nc Time Dial

2001 67c-2 PICKUP 0.10..35.00 A; ∞ 10.00 A 67c-2 Pickup

2002 67c-2 DELAY 0.00..60.00 sec; ∞ 0.00 sec 67c-2 Time Delay

2003 67c-1 PICKUP 0.10..35.00 A; ∞ 2.00 A 67c-1 Pickup

2004 67c-1 DELAY 0.00..60.00 sec; ∞ 0.30 sec 67c-1 Time Delay

2005 67c-TOC PICKUP 0.10..4.00 A; ∞ 1.50 A 67c Pickup

2006 67c-TOC T-DIAL 0.05..3.20 sec; ∞ 0.50 sec 67c Time Dial

2007 67c-TOC T-DIAL 0.50..15.00; ∞ 5.00 67c Time Dial

2101 50Nc-2 PICKUP 0.05..35.00 A; ∞ 7.00 A 50Nc-2 Pickup

2102 67Nc-2 DELAY 0.00..60.00 sec; ∞ 0.00 sec 67Nc-2 Time Delay

2103 67Nc-1 PICKUP 0.05..35.00 A; ∞ 1.50 A 67Nc-1 Pickup

2104 67Nc-1 DELAY 0.00..60.00 sec; ∞ 0.30 sec 67Nc-1 Time Delay

2105 67Nc-TOC PICKUP 0.05..4.00 A; ∞ 1.00 A 67Nc-TOC Pickup

2106 67Nc-TOC T-DIAL 0.05..3.20 sec; ∞ 0.50 sec 67Nc-TOC Time Dial

2107 67Nc-TOC T-DIAL 0.50..15.00; ∞ 5.00 67Nc-TOC Time Dial

F.No. Alarm Comments

01730 >BLOCK CLP >BLOCK Cold-Load-Pickup

01731 >BLK CLP stpTim >BLOCK Cold-Load-Pickup stop timer

01732 >ACTIVATE CLP >ACTIVATE Cold-Load-Pickup

01994 CLP OFF Cold-Load-Pickup switched OFF

01995 CLP BLOCKED Cold-Load-Pickup is BLOCKED

01996 CLP running Cold-Load-Pickup is RUNNING

01997 Dyn set. ACTIVE Dynamic settings are ACTIVE

Addr. Setting Title Setting Options Default Setting Comments

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Functions

2.5 Voltage Protection (27, 59)

General Voltage protection has the function to protect electrical equipment against undervolt-age and overvoltage. Both operational states are unfavorable as undervoltage maycause for example stability problems and overvoltage may lead to insulation problems.

2.5.1 Description of Voltage Protection

2.5.1.1 Measurement Principle

VT Connection The voltages supplied to the device may correspond to the three phase–to–groundvoltages, or two phase-to-phase voltages and the displacement voltage, depending onhow the voltage transformers are connected. 7SJ64 provides the option to detectthree phase-ground voltages and the ground voltage in addition. The connectionmode has been specified during the configuration in address 0213 VT Connection.

Overvoltage protection requires the phase–phase voltages and if necessary they arecalculated from the phase-earth voltages. In case of phase-phase connection two volt-ages are measured and the third is calculated.

Undervoltage protection relies on the positive-sequence component of the phase-to-phase voltages.

The option between phase–ground and phase–phase voltage allows voltage asym-metries (e.g. caused by a ground fault) to be taken into account (phase–ground) or leftunconsidered (phase–phase).

CurrentSupervision

The primary voltage transformers are arranged, depending on the system, either onthe supply side or the load side of the associated circuit breaker. These different ar-rangements lead to different behavior of the voltage protection function when a faultoccurs. When a circuit breaker is opened, full voltage remains on the supply side whilethe load side voltage becomes zero. Opening the circuit breaker when voltage trans-formers are located on the load side of the circuit breaker causes the undervoltageprotection to remain picked up. Therefore, the flow of current through the circuit break-er can be used as an additional criteria for pickup of undervoltage protection. Whencurrent supervision is active, for undervoltage pickup to occur, the current through thecircuit breaker must exceed a minimum current level which corresponds to the currentflow monitoring setting at address 0212 BkrClosed I MIN. The circuit breaker istripped, when the current decreases below the current flow monitoring setting, and un-dervoltage protection will drop out.

Note:

If current supervision is turned off under address 5120A CURRENT SUPERV., the un-dervoltage function will pick up without 3 phase voltage applied. The device cannot beprogrammed if in pickup. Apply 3 phase voltage or block the voltage protection to con-tinue with programming! Moreover you have the option of setting a flag via device op-eration for blocking the voltage protection. This initiates the reset of the pickup anddevice parameterization can be resumed.

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Voltage Protection (27, 59)

Preparation of Mea-sured Data

Using a Fourier Analysis, the fundamental harmonic component of the three phase-to-phase voltages are filtered out and passed along for further processing. For undervolt-age protection, the positive sequence components of the phase-to-phase voltages areevaluated, while for overvoltage protection, the largest of the three phase-to-phasevoltages is evaluated.

2.5.1.2 Overvoltage Protection (59)

Application The overvoltage protection has the task of preventing insulation failure by protectingagainst abnormally high voltage levels.

Abnormally high voltages often occur in low loaded, long distance transmission lines,in islanded systems when generator voltage regulation fails, or after full load shutdownof a generator from the system.

Function Overvoltage protection consists of two definite time elements designated 59-2 and 59-1. The pickup and delay settings of each element are individually adjustable. The fun-damental harmonic of the largest phase–to–phase voltages is provided to the over-voltage protection elements. When an adjustable setting is exceeded, the 59 elementpickups, and after an adjustable time delay elapses, initiates a trip signal. The 59 ele-ment is a definite time element in that the time delay is not a function of the voltagemagnitude.

Figure 2-32 shows the logic diagram of the overvoltage protection element.

Figure 2-32 Logic Diagram of the Overvoltage Protection

U>>

T 0& 59-2 TRIP

59-2 picked up

„1“

>BLOCK 59-1

59 OFF

& 59 ACTIVE

or

59 BLOCKED

Measurement/Logic

FNo. 065735006 59-2 PICKUP

5007 59-2 DELAY

5001 FCT 59

FNo. 06571

FNo. 06566

FNo. 06565

FNo. 06567

FNo. 06513

ON

OFF

Alarm Only

U>

T 0& 59-1 TRIP

59-1 picked up

FNo. 065705002 59-1 PICKUP

5004 59-1 DELAY

FNo. 06568

Tagging BLK. 27, 59

or

FNo. 234.21027, 59 blk

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Functions

2.5.1.3 Undervoltage Protection (27)

Application Undervoltage protection detects and reports abnormally low voltage conditions, someof which could be related to system stability problems (voltage collapse, etc.). Under-voltage protection is generally used for load shedding and loss of phase purposes.

Function Undervoltage protection consists of two definite time elements designated 27-2 and27-1. The pickup and delay settings of each element are individually adjustable. Forundervoltage protection, the positive sequence components of the phase-to-phasevoltages are evaluated. The 27 element is a definite time element in that the time delayis not a function of the voltage magnitude.

With the 27-1 element, the ratio of drop out voltage to pickup voltage (27-1 DOUT RATIO) is settable as well.

The undervoltage protection will not be blocked when the permissible frequency rangeof fN = ± 10 % (45 Hz to 55 Hz at fN = 50 Hz) is left. This ensures that the protectivefunction is preserved even when it is applied as motor protection in context with decel-erating motors. However, the r.m.s. value of the positive-sequence component of thevoltages is evaluated too small for strongly deviating frequencies so that the devicetends to exhibit unwanted operation. If application cases are anticipated who leave thefrequency range of fN ± 10 %, the current criterion will not return a correct result. Thecurrent criterion must be deactivated.

Figure 2-33 shows a typical voltage profile during a fault for source side connection ofthe voltage transformers. Because full voltage is present after the circuit breaker isopened, current supervision is unnecessary.

After the voltage has decreased below the pickup setting of the 27-1 element, the 27-1 time delay is initiated, after which, the 27-1 element is used to block reclosing. Aslong as the voltage remains below the drop out setting, reclosing is blocked. When thevoltage increases above the drop out level, the 27-1 element drops out and allows re-closing of the circuit breaker.

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Voltage Protection (27, 59)

Figure 2-33 Typical Fault Profile for Source Side Connection of the Voltage Transformer(without current supervision)

Figure 2-34 shows a fault profile for a load side connection of the voltage transformers.When the circuit breaker is open, the voltage disappears and the 27-1 element picksup and times out. When the current drops below the current flow monitoring setting ataddress 0212 BkrClosed I MIN (i.e. the current criterion is no longer met) the 27-1 element will drop out even though the voltage remains below the pick-up setting ofthe 27-1 element.

Pickup

Drop out

Drop Out Setting

Pickup Setting

ReclosingSignal

TrippingSignal

t

t

27-1Drop Out

27-1Pickup

V(t)

Vn

27-1 DO

27-1 PU

27-1 Delay Tmin com

ReclosingBlocked

Tmin com=Minimum Command Line

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Functions

Figure 2-34 Typical Fault Profile for Load Side Connection of the Voltage Transformers(with current supervision)

The instant after a circuit breaker is closed, the load side voltage begins to increaseand current begins to flow through the circuit breaker. To ensure that the 27-1 elementdoes not pickup, the element remains dropped out for a short period of time (about40ms) until both the current flowing through the circuit breaker and the load side volt-age stabilize. It is important to understand, however, that if a low voltage condition ex-ists on the load after the circuit breaker is closed (i.e. a fault exists on the load side ofthe circuit breaker), pickup of the 27-1 element will be delayed by 40 ms.

Figure 2-35 shows the logic diagram for the undervoltage protection.

Pickup

Drop Out

ClosingSignal

TrippingSignal

t

27-1Drop Out

V<

27-1Pickup

27 Delay TMIN COM

Drop Out Setting

Pickup Setting

t

V(t)

Vn

27-1 DO

27-1 PU

t

I(t)

In

Addr. 0212

Current Flow

t

40 ms

tCurrent Criterion Met

27-1 Pickup

Current Criterion Met

Pickup = 27-1 Pickup and Current Criterion Met

Monitoring Setting

Tmin com = Minimum Command Line

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Voltage Protection (27, 59)

Figure 2-35 Logic Diagram for Undervoltage Protection

I>

T 027-2 TRIP

27-2 PU CS

„1“

U>

U<<

&

or

&

&

27-2 picked up

T 0& 27-1 TRIP

27-1 PU CS

&

&

27-1 picked up

&&

„1“

>FAIL:FEEDER VT

>FAIL: BUS VT

>BLOCK 27

>BLOCK 27-1

>BLOCK 27-2

or

27 BLOCKEDor

27 OFF

& 27 ACTIVE

or

>27 I SUPRVSN

40 ms

FNo. 06539

5120A CURRENT SUPERV.

5112 27-2 DELAY

5106 27-1 DELAY

5101 FCT 27

5110 27-2 PICKUP

5102 27-1 PICKUP

0212 BkrClosed I MIN

FNo. 06534

FNo. 06533

FNo. 06540

FNo. 06538

FNo. 06537

FNo. 06531

FNo. 06530

FNo. 06532

FNo. 06503

FNo. 06510

FNo. 06508

FNo. 06509

FNo. 06506

FNo. 06505

ON

OFF

ON

OFF

Alarm Only

Tagging BLK. 27, 59 27, 59 blkFNo. 234.2100

Measurement/Logic

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Functions

2.5.2 Programming Settings

Voltage protection is only in effect and accessible if address 0150 27/59 is set toEnabled during configuration of protective functions. If the voltage protection functionis not needed, address 0150 should be set to Disabled.

All setting values are based on phase-to-phase voltages. The setting ranges dependon the type of voltage transformer connection utilized (specified at address 0213 VT Connection). For voltage transformers connected in a grounded-wye configuration,higher setting values may be used because the voltage inputs are subjected only tophase-to-ground voltage levels.

2.5.2.1 Voltage Protection – General

Undervoltage protection can be turned ON, OFF, or set to Alarm Only at address5101 FCT 27. When undervoltage protection is turned ON, tripping by the undervolt-age elements is allowed.

Overvoltage protection can be turned ON, OFF, or set to Alarm Only at address 5001FCT 59. When address 5001 is set to ON, tripping by the overvoltage element is al-lowed.

2.5.2.2 Undervoltage Protection

Pickup Values There are not clear cut procedures for setting the pickup values of the undervoltagerelay elements. However, because the undervoltage protection function is primarily in-tended to protect induction machines from voltage dips and to prevent stability prob-lems, the pickup values will usually be between 60% and 85% of the nominal voltage.The time delay settings should be selected to prevent voltage dips from causing un-stable conditions, however, the time delay should be long enough to avoid tripping dueto momentary voltage dips.

Undervoltage protection includes two definite time elements. The pickup value of the27-2 element is set at either address 5110 or 5111 27-2 PICKUP (depending on thevoltage transformer connection) while the time delay is set at address 5112 27-2 DELAY. The pickup of the 27-2 element is typically set low while the time delay is setshort, thus this element is used for fast protection against severe undervoltage condi-tions. The pickup value of the 27-1 element is set at either address 5102 or 5103 27-1 PICKUP (depending on the voltage transformer connection) while the time delay isset at address 5106 27-1 DELAY. The pickup of the 27-1 element is typically set highwhile the time delay is set long, thus this element is used for slower protection againstless severe undervoltage conditions. Setting the 27-2 and 27-1 relay elements in thismatter allows the undervoltage protection function to closely follow the stability behav-ior of the system.

Dropout Setting While the drop out setting on the 27-2 element is set permanently to 105% of the pick-up setting, the drop out setting on the 27-1 element can be set at address 5105A 27-1 DOUT RATIO as a multiple of the pickup setting. However, the following limitationsare to be observed:

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Voltage Protection (27, 59)

(Address 5105A) x (Address 5103) cannot exceed 130 V when address 0213 = Vab, Vbc, VGnd.

(Address 5105A) x (Address 5102) cannot exceed 225 V when address 0213 = Van, Vbn, Vcn.

CurrentSupervision

The 27-2 and 27-1 elements can be supervised by the current flow monitoring setting(BkrClosed I MIN) entered at address 0212. If address 5120A CURRENT SUPERV. isswitched on, then the 27-2 and 27-1 elements will not pickup until the current flowingthrough the circuit breaker exceeds the setting entered at address 0212 (typically setvery sensitive). In other words the sustained pickup of the 27-2 and 27-1 elements isdependent on the circuit breaker being closed, as determined by “BkrClosed I MIN.” A benefit of current supervision is that the feature prevents an immediate gen-eral-pickup of the device that would otherwise be caused by the 27 elements when thedevice is powered-up without voltage being present.

The 50 element “BkrClosed I MIN” is used in other protective functions as well,including breaker failure protection, overload protection, and start inhibit for motors.

2.5.2.3 Overvoltage Protection

Pickup Values The overvoltage protection relies on phase-phase voltages. Accordingly, the pickupvalues, too, must always be considered phase–to–phase voltages. The overvoltageprotection is designed in two stages. Thus, the lower threshold (address 5002 or5003, 59-1 PICKUP can be assigned a long delay time (depending on whetherphase-ground or phase-phase voltages are connected) (address 5004, 59-1 DELAY)and the upper threshold (address 5005 or 5006, 59-2 PICKUP) can be assigned ashort delay time (address 5007, 59-2 DELAY). There are not clear cut procedures onhow to set the pickup value of the overvoltage element. However, because the over-voltage function is primarily intended to prevent insulation damage, the pickup of theovervoltage element 59-1 PICKUP should be set between 110 % and 115 % of nom-inal voltage, and the pickup of the overvoltage element 59-2 PICKUP should be setabout 130 % of nominal voltage. Depending on the type of voltage transformer con-nection utilized, the pickup value may be entered at address 5002 and 5005 (usedwhen voltage transformers are connected in a grounded-wye configuration) or 5003 and 5006 (used when voltage transformers are not connected in a grounded-wyeconfiguration). The time delays of the overvoltage elements are entered at addresses

Note:

If a setting has a value of greater than 130 V or 225 V results for the drop out setting,the drop out setting will be automatically limited. No error message occurs.

Note: When switching off the CURRENT SUPERV. setting under Address 5120A, thedevice immediately picks up if voltage is not present and the undervoltage protectionis switched on. The device cannot be programmed if in pickup. Apply 3 phase voltageto continue with programming or block voltage protection! The blocking can be initiat-ed via device operation in DIGSI® 4 and via communication from the control center bymeans of a tagging command. This causes the reset of the pickup and parameteriza-tion can be resumed.

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Functions

5004 59-1 DELAY and 5007 59-2 DELAY and should be selected to allow the briefvoltage spikes that are generated during switching operations.

2.5.2.4 Settings for Voltage Protection

2.5.2.5 Information List for Voltage Protection

Addr. Setting Title Setting Options Default Setting Comments

5101 FCT 27 OFFONAlarm Only

OFF 27 Undervoltage Protection

5001 FCT 59 OFFONAlarm Only

OFF 59 Overvoltage Protection

5102 27-1 PICKUP 10..210 V 75 V 27-1 Pickup

5103 27-1 PICKUP 10..120 V 75 V 27-1 Pickup

5105A 27-1 DOUT RATIO 1.05..3.00 1.20 27-1 Drop out Ratio

5106 27-1 DELAY 0.00..100.00 sec; ∞ 1.50 sec 27-1 Time Delay

5110 27-2 PICKUP 10..210 V 70 V 27-2 Pickup

5111 27-2 PICKUP 10..120 V 70 V 27-2 Pickup

5112 27-2 DELAY 0.00..100.00 sec; ∞ 0.50 sec 27-2 Time Delay

5120A CURRENTSUPERV.

OFFON

ON Current Supervision

5002 59-1 PICKUP 40..260 V 110 V 59-1 Pickup

5003 59-1 PICKUP 40..130 V 110 V 59-1 Pickup

5004 59-1 DELAY 0.00..100.00 sec; ∞ 0.50 sec 59-1 Time Delay

5006 59-2 PICKUP 40..130 V 120 V 59-2 Pickup

5005 59-2 PICKUP 40..260 V 120 V 59-2 Pickup

5007 59-2 DELAY 0.00..100.00 sec; ∞ 0.50 sec 59-2 Time Delay

F.No. Alarm Comments

06503 >BLOCK 27 >BLOCK 27 undervoltage protection

06505 >27 I SUPRVSN >27-Switch current supervision ON

06506 >BLOCK 27-1 >BLOCK 27-1 Undervoltage protection

06508 >BLOCK 27-2 >BLOCK 27-2 Undervoltage protection

06530 27 OFF 27 Undervoltage protection switched OFF

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Voltage Protection (27, 59)

06531 27 BLOCKED 27 Undervoltage protection is BLOCKED

06532 27 ACTIVE 27 Undervoltage protection is ACTIVE

06533 27-1 picked up 27-1 Undervoltage picked up

06534 27-1 PU CS 27-1 Undervoltage PICKUP w/curr. superv

06537 27-2 picked up 27-2 Undervoltage picked up

06538 27-2 PU CS 27-2 Undervoltage PICKUP w/curr. superv

06539 27-1 TRIP 27-1 Undervoltage TRIP

06540 27-2 TRIP 27-2 Undervoltage TRIP

06513 >BLOCK 59-1 >BLOCK 59-1 overvoltage protection

06565 59 OFF 59-Overvoltage protection switched OFF

06566 59 BLOCKED 59-Overvoltage protection is BLOCKED

06567 59 ACTIVE 59-Overvoltage protection is ACTIVE

06568 59-1 picked up 59 picked up

06570 59-1 TRIP 59 TRIP

06571 59-2 picked up 59-2 Overvoltage V>> picked up

06573 59-2 TRIP 59-2 Overvoltage V>> TRIP

234.2100

27, 59 blk 27, 59 blocked via operation

F.No. Alarm Comments

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Functions

2.6 Negative Sequence Protection (46)

General Negative sequence protection detects unbalanced loads on the system. In addition, itmay be used to detect interruptions, faults, and polarity problems with current trans-formers. It is particularly useful in detecting phase-to-ground, phase-to-phase, anddouble phase-to-ground faults with magnitudes lower than the maximum load current.

Use with Motors The application of negative sequence protection to motors has a special significance.The negative sequence currents associated with unbalanced loads create counter-ro-tating fields in three-phase induction motors, which act on the rotor at double frequen-cy. Eddy currents are induced at the rotor surface, and local overheating of the rotorbegins to take place. In addition, the threat of thermal overload exists when the motoris supplied by unbalanced system voltages. Because the motor represents a small im-pedance to negative sequence voltages, small voltage imbalances can lead to largenegative sequence currents.

2.6.1 Description of Negative Sequence Protection

2.6.1.1 Determination of Unbalanced Load

The negative sequence protection feature of the 7SJ62/63/64 relay uses filtering todissect the phase currents into their symmetrical components. The negative-phasesequence system is evaluated by these components, i.e. the inverse current I2. If thelargest of the three phase currents is at least 10% of the nominal device current, andall phase currents are less than four (4) times the nominal device current, then thenegative sequence current is fed into three time-overcurrent relay elements, two ofwhich are definite time (see Figure 2-36) and one of which contains an inverse timecharacteristic (see Figure 2-37).

Refer to phase rotation via binary input section 2.1.3 and 2.18.

2.6.1.2 Definite Time Elements (46-1, 46-2)

The two definite time elements are designated 46-2 and 46-1. Each of the two definitetime elements will generate a message and initiate a time delay when picked up. Onceeither time delay elapses, a trip signal is initiated. Figure 2-36 illustrates the definitetime characteristic when the 46-1 element is set with a more sensitive pickup valuewhile the 46-2 element is set with a shorter tripping delay.

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Negative Sequence Protection (46)

Figure 2-36 Definite Time Characteristic for Negative Sequence Protection

2.6.1.3 Inverse Time Element (46-TOC)

The inverse time element is designated 46-TOC and can operate with IEC or ANSIcharacteristic tripping curves depending on the model ordered. The curves and asso-ciated formulas are given in the Technical Specifications (Figures 4-7 to 4-9 in Section4.8). When programming the inverse time curve, the definite time elements are avail-able (see Subsection 2.6.1.2).

Pickup andTripping

When the negative sequence current exceeds the pickup setting of the 46-TOC ele-ment by 110%, the element picks up, generates a message, and initiates time delayedtripping based on the selected characteristic curve. Once the corresponding time in-terval on the curve elapses, a tripping signal is initiated. The characteristic curve is il-lustrated in Figure 2-37.

Drop Out for IECCurves

When IEC curves are used, the 46-TOC element drops out when the negative se-quence current decreases to 95 % of the pickup setting. The time delay resets imme-diately in anticipation of another pickup.

Drop Out for ANSICurves

When ANSI curves are used, the 46-TOC element may drop out immediately whenthe negative sequence current decreases to 95 % of the pickup setting, or disk emu-lation may be used to simulate the unwinding of an electromechanical induction disc.

If disk emulation is selected, the drop out begins when the current decreases to 90 %of the pickup value, and reset proceeds in accordance with the selected reset curve.When the negative sequence current is between 90 % and 95 % of the pickup setting,neither forward nor reverse movement of the disk is simulated. When the negative se-quence current falls below 5 % of the pickup value, disk emulation is terminated andimmediate reset takes place. Figure 2-37 illustrates the overall tripping characteristic.

t

I246-1 46-2

Tripping Area

46-1

46-2

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Functions

Figure 2-37 Inverse Time Characteristic for Negative Sequence Protection

Figure 2-38 Logic Diagram for Negative Sequence Protection

t

I246-1 46-2

Tripping area

46-1

46-2

1.1 x I2P

Negative SequenceWarning Level

ThermalProtection

Severe ImbalanceProtection

OFF

I2I2p

T 0

>BLOCK 46

„1“46 OFF

or

46 BLOCKED

46 ACTIVE

I2>

I2>> T 0

or 46 TRIP

46-2 picked up

46-TOC pickedup

46-1 picked up

or

Measurement/Logic

FNo. 05166

0140 464006 46 IEC CURVE

4010 46-TOC TIMEDIAL4008 46-TOC PICKUP

4002 46-1 PICKUP

4010 46-2 PICKUP

4003 46-1 DELAY

4005 46-2 DELAY

4001 FCT 46

FNo. 05165

FNo. 05170

FNo. 05159

FNo. 05152

FNo. 05153

FNo. 05151

FNo. 05143

ON

TOC IEC

Definite Time

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Negative Sequence Protection (46)

Disk emulation offers advantages when the negative sequence protection must be co-ordinated with conventional source side relays.

Logic Figure 2-38 shows the logic diagram for negative sequence protection. The protectionmay be blocked via a binary input. This resets pick-ups and time steps and clearsmeasured values.

When the negative sequence protection criteria are no longer satisfied (i.e. all phasecurrents drop below 10 % of the nominal relay current or at least one phase current isgreater than four (4) times the nominal device current, the tripping time delay is imme-diately reset.

2.6.2 Programming Settings

2.6.2.1 General

Negative sequence protection is configured at address 0140 46. If only the definitetime elements are desired, address 0140 should be set to Definite Time. If bothdefinite time and inverse time elements are to be used, address 0140 should be setto TOC IEC or TOC ANSI, and if negative sequence protection is not needed, address0140 should be set to Disabled.

Negative sequence protection is switched ON or OFF at address 4001 FCT 46.

The default pickup settings and delay settings of the negative sequence time-overcur-rent relay elements are generally sufficient for most applications. If the device is usedto protect a motor, and data is available from the manufacturer regarding the allowablelong-term load imbalance and the allowable load imbalance per unit of time, this datashould be used as the basis for selecting the pickup and delay settings. In this situa-tion, it is important to ensure that the values given by the manufacturer represent theprimary values for the motor. For example, if the long-term allowable thermal inversecurrent (with respect to the nominal motor current) is given, this value is used to cal-culate the settings for the negative sequence time-overcurrent element. For this situ-ation:

2.6.2.2 Definite Time Elements

The pickup and delay settings associated with the 46-1 element are set at addresses4002 46-1 PICKUP and 4003 46-1 DELAY respectively while the pickup and delaysettings for the 46-2 element are set at address 4004 46-2 PICKUP and 4005 46-2 DELAY respectively. Typically the 46-1 element is set with a lower pickup value and

where I2 perm prim Permissible Thermal Inverse Current of the Motor

IN Motor Nominal Motor CurrentICT sec Secondary Nominal Current of the Current TransformerICT prim Primary Nominal Current of the Current Transformer

I2I2perm prim

INMotor---------------------------- INMotor

ICT sec

ICT prim-------------------⋅ ⋅=Pickup Setting

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Functions

higher time delay than the 46-2 element. This allows the 46-1 element to act as analarm while the 46-2 element will initiate fast tripping for severe imbalances.

If the 46-2 element is used for fast tripping against severe imbalances, the pickup val-ue should be set at 60 % of the nominal phase current. This will ensure pickup for thecomplete loss of one phase. On the other hand, because the loss of a phase could beinterpreted as a phase-to-phase fault, the time delay of this element should be coor-dinated with fault protection relays. The magnitude of the negative sequence currentwith respect to the phase current when one phase is out of service is given as follows:

Examples:

This ensures

When protecting a feeder, negative sequence protection may serve to identify lowmagnitude unsymmetrical faults below the pickup values of the directional and non-directional overcurrent elements. To detect load magnitude faults, the pickup value ofthe negative sequence time-overcurrent elements must be set below the following:

− a phase-to-phase fault (I) results in the following negative sequence current:

− a phase-to-ground fault (I) corresponds to the following negative sequence current:

To prevent false operations for fault in other zones of protection, the time delay shouldbe coordinated with other fault protection relays in the system.

For a transformer, negative sequence protection may be used as sensitive protectionfor low magnitude phase-to-ground and phase-to-phase faults. In particular, this ap-plication is well suited for delta-wye transformers where low side phase-to-groundfaults do not generate high side zero sequence currents.

The relationship between negative sequence currents and total fault current for phase-to-phase faults and phase-to-ground faults are valid for the transformer as long as theturns ratio is taken into consideration.

Motor: IN Motor = 545A

I2 long-term prim / IN Motor = 0.11 long-term

I2 short-term prim /IN Motor = 0.55 for Tmax = 1s

CurrentTransformers

CT = 600A/1A

Set Value 46-1 Address 4002 = 0.11 · 545A · (1/600A) = 0.10ASet Value 46-2 Address 4004 = 0.55 · 545A · (1/600A) = 0.50A

I21

3------- I⋅ 0.58 I⋅= =

I21

3------- I⋅ 0.58 I⋅= =

I213--- I⋅ 0.33 I⋅= =

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Negative Sequence Protection (46)

Consider a transformer with the following data:

The following faults may be detected at the lower-voltage side:

If the pickup setting (PU) of the device on the high side is set to 0.1 A, then a phase-to-ground fault current of

I = (1/0.33) * CTR * PU * VHS / VLS =

3 * 100 * 0.1 A * 110 kV / 20 kV = 165 A

and a phase-to-phase fault current of

I = (1/0.58) * CTR * PU * VHS / VLS =

1.732 * 100 * 0.1 A * 110 kV / 20 kV = 95 A

can be detected at the low side. These faults correspond to 36 % and 20 % of the basetransformer rating respectively. It is important to note that load current is not taken intoaccount in this simplified example.

As it cannot be recognized reliably on which side the thus detected fault is located, thedelay time must be coordinated with other relays in the system to prevent false oper-ation for faults in other zones of protection.

2.6.2.3 Inverse Time Element 46-TOC

IEC Curves If the 46-TOC element is employed, a characteristic tripping curve should be selectedto coordinate with the thermal overload curve representing the protected equipment(e.g. induction motor, etc.). The curve should be selected at address 4006 46 IEC CURVE. The characteristic tripping curves, and the formulas on which they are based,are given in the Technical Specifications, Section 4.8.

The 46-TOC element picks up when the negative sequence input current exceeds110% of the pickup settings and drops out when he negative sequence current de-creases to 95 % of the pickup setting. The pickup settings is entered at address 400846-TOC PICKUP.

The associated time multiplier is entered at address 4010 46-TOC TIMEDIAL.

The time multiplier may also be set to ∞ thus allowing the element to pickup and gen-erate a message, but never to trip. If the inverse time element is not required at all,address 0140 should be set to Definite Time during configuration of protectivefunctions (Section Configuration of Functions, 2.1.1).

ANSI Curves If the 46-TOC element is employed, a characteristic tripping curve should be selectedto coordinate with the thermal overload curve representing the protected equipment(e.g. induction motor, etc.). The curve should be selected at address 4007 46 ANSI CURVE. The characteristic tripping curves, and the formulas on which they are based,are given in the Technical Specifications, Section 4.8.

Transformer Base Rating 16 MVANominal High Side Voltage VHS = 110 kV

Nominal Low Side Voltage VLS = 20 kV

Transformer Connection Delta-Grounded WyeHigh Side CT Ratio CTR = 100 A / 1 A

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The 46-TOC element picks up when the negative sequence input current exceeds110 % of the pickup settings and drops out when the negative sequence current de-creases to 95 % of the pickup setting. The pickup settings is entered at address 4008 46-TOC PICKUP. If Disk Emulation was selected at address 4011 46-TOC RE-SET, reset will occur in accordance with the reset curve as described in Subsection2.6.1.3. The associated time dial is entered at address 4009 46-TOC TIMEDIAL.

The time may also be set to ∞ thus allowing the element to pickup and generate amessage, but never to trip. If the inverse time element is not required at all, address0140 should be set to Definite Time during configuration of protective functions(Section 2.1.1).

2.6.2.4 Settings for Negative Sequence (Phase Balance) Current Protection

In the list below, the setting ranges and default setting values for the pickup currentsare for a device with a nominal current rating IN = 1 A. For a nominal current rating IN= 5 A, multiply the Setting Options values and Default Setting values by 5. Considerthe current transformer ratios when setting the device with primary values.

Addr. Setting Title Setting Options Default Setting Comments

4001 FCT 46 OFFON

OFF 46 Negative Sequence Protec-tion

4002 46-1 PICKUP 0.10..3.00 A 0.10 A 46-1 Pickup

4003 46-1 DELAY 0.00..60.00 sec; ∞ 1.50 sec 46-1 Time Delay

4004 46-2 PICKUP 0.10..3.00 A 0.50 A 46-2 Pickup

4005 46-2 DELAY 0.00..60.00 sec; ∞ 1.50 sec 46-2 Time Delay

4006 46 IEC CURVE Normal InverseVery InverseExtremely Inverse

Extremely Inverse IEC Curve

4007 46 ANSI CURVE Extremely InverseInverseModerately InverseVery Inverse

Extremely Inverse ANSI Curve

4008 46-TOC PICKUP 0.10..2.00 A 0.90 A 46-TOC Pickup

4009 46-TOC TIMEDIAL 0.50..15.00; ∞ 5.00 46-TOC Time Dial

4011 46-TOC RESET InstantaneousDisk Emulation

Instantaneous 46-TOC Drop Out

4010 46-TOC TIMEDIAL 0.05..3.20 sec; ∞ 0.50 sec 46-TOC Time Dial

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2.6.2.5 Information List for Negative Sequence Current Protection

F.No. Alarm Comments

05143 >BLOCK 46 >BLOCK 46

05151 46 OFF 46 switched OFF

05152 46 BLOCKED 46 is BLOCKED

05153 46 ACTIVE 46 is ACTIVE

05159 46-2 picked up 46-2 picked up

05165 46-1 picked up 46-1 picked up

05166 46-TOC pickedup 46-TOC picked up

05170 46 TRIP 46 TRIP

05171 46 Dsk pickedup 46 Disk emulation picked up

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2.7 Motor Protection (Motor Starting Protection, 48 and Start Inhibit forMotors, 66/68)

2.7.1 Description of Motor Starting Protection

General When the 7SJ62/63/64 relay is used to protect a motor, the starting time monitoringfeature supplements the overload protection described in Section 2.9 by protecting themotor against the potential damage that might result from frequent starting or extend-ed starting durations. In particular, rotor-critical high-voltage motors can quickly beheated above their thermal limits when multiple starting attempts occur in a short pe-riod of time. If the durations of these starting attempts are lengthened by excessivevoltage surges during motor starting, by excessive load moments, or by blocked rotorconditions, a tripping signal will be initiated by the device.

Motor starting protection consists of two time-overcurrent tripping characteristics initi-ated by the motor starting recognition setting entered at address 1107 I MOTOR START. One characteristic is definite time while the other one is inverse time. Whenthe motor phase currents exceed the setting entered at address 1107, time delayedtripping will be initiated. To gain a better understanding of how to set the motor startingrecognition setting at address 1107, refer to side title “Recognition of Running Condi-tion” in Subsections 2.1.6 and 2.9.2.2.

Inverse Time-Over-current Character-istic

The inverse time-overcurrent characteristic is designed to operate only when the rotoris not blocked. When the phase currents exceed the motor starting recognition settingentered at address 1107, time delayed tripping via the inverse time characteristic isinitiated. The inverse time characteristic allows motor starting protection to adjust forthose situations where high starting voltages result in decreased starting currents. Thetripping time is calculated based on the following formula:

tTRIP

IA

I-----

2tAmax⋅= where I> IMOT START

where tTRIP – Actual tripping time for flowing current I

tA max – Tripping time for nominal start-up current IA (set at address 4103)

I – Current actually flowing (measurement value)

IA – Nominal starting current of the motor (set at address 4102)

IMOT START – Pickup value for recognition of motor starting (set at address 1107)

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Figure 2-39 Inverse Time Characteristic Tripping Curve for Motor Starting Current

Therefore, if the starting current I actually measured is smaller (or larger) than thenominal starting current IA entered at address 4102 STARTUP CURRENT, the actualtripping time ttrip is lengthened (or shortened) accordingly. See Figure 2-39.

Definite TimeOvercurrent Trip-ping Characteristic(Blocked RotorTime)

During motor starting, the definite time characteristic is designed to initiate a trip if themotor starting time exceeds the maximum allowable blocked rotor time. The devicecan detect a blocked rotor condition via a binary input („>Rotor locked“) from anexternal rpm-counter. If the current in any of the phases exceeds the motor startingrecognition setting entered at address 1107, and if a blocked rotor conditions is de-tected via a binary input, a motor starting condition is assumed, and time delayed trip-ping via the definite time characteristic will be initiated (based on the maximum allow-able blocked rotor time).

It is important to note that message generation does not occur unless a trip is initiated.Furthermore, when a blocked rotor condition is detected via a binary input, and thedefinite time characteristic times out, immediate tripping will take place regardless ofwhether the blocked rotor condition was detected before or after the definite time char-acteristic timed out.

Logic Motor starting protection may be switched on or off at address 4101 48. In addition,motor starting protection may be blocked via a binary input, at which time pickup mes-sages and time delays will be reset. Figure 2-40 illustrates the logic for motor startingprotection. A pick up does not create a fault record. Fault recording is not started untila trip command has been issued. When the function drops out the starting time, theblocked rotor time and the annunciations are reset and the fault recording is terminat-ed.

tTRIP

IIMOT START IA

tA max

[s]

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Figure 2-40 Logic Diagram for Motor Starting Protection

2.7.2 Description of Start Inhibit for Motor

General The rotor temperature of a motor generally remains well below its maximum allowabletemperature during normal operation and even during severe loading conditions. How-ever, during motor starting, the rotor can heat up quickly. If multiple starting attemptsare made in a short duration of time, the rotor could suffer thermal damage. Therefore,the 7SJ62/63/64 motor start blocking feature is available. A motor start blocking signalis initiated when the relay projects rotor temperature will exceed the maximum allow-able rotor temperature, and blocking continues until the calculated rotor temperaturedecreases below the reset level. To block starting, the blocking signal must be con-nected to a binary output whose contact is inserted in the motor starting circuit.

DeterminingExcessive RotorTemperature

Because the rotor current cannot be measured directly, the stator current must beused to generate a thermal profile of the rotor. The excessive rotor temperature is cal-culated using the highest of the three phase currents. The thermal limit values for therotor winding are based on manufacturer’s data regarding the nominal starting current,maximum permissible starting time, and the number of starts permitted from cold andwarm conditions. From this data, the device performs the necessary calculations toestablish the thermal rotor profile and issues a blocking signal until the thermal rotorprofile decreases below the restarting limit.

4102 STARTUP CURRENT

Fault Cond.

&T 0

>BLK START-SUP

„1“

START-SUP pu

START-SUP OFF

or

>Rotor locked

START-SUP BLK

Pickup Aφ

or

or

or S Q

R

or

START-SUP TRIP

Rotor locked

4101 FCT 48/66

4103 STARTUP TIME

4104 LOCK ROTOR TIME

FNo. 06821

FNo. 06822

FNo. 06812

FNo. 06811

FNo. 06805

FNo. 06801

ONOFF

FNo. 06823

or

or START-SUP ACTFNo. 06813

Measurement/Logic

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Figure 2-41 Temperature Curve at the Rotor and the Thermal Profile during Repeated Start-ing Attempt

Although the heat distribution at the rotor brushes can range widely during motor start-ing, the different maximum temperatures in the rotor do not necessarily affect motorstart blocking (see Figure 2-41). It is much more important to establish a thermal pro-file, after a complete motor start, that is appropriate for the protection of the motor’sthermal condition. Figure 2-41 shows, as an example, the heating processes duringrepeated motor starts (three starts from cold operating condition), as well as the ther-mal reproduction by the protective relay.

Restarting Limit If the rotor temperature has exceeded the restarting limit, the motor cannot be restart-ed. When the rotor temperature goes below the restarting limit, that is, when exactlyone start becomes possible without exceeding the excessive rotor temperature limit,the blocking signal is terminated.

Therefore the restarting temperature related to trip temperature is expressed as:

The restarting limit ΘRestart/ΘTrip is displayed as operational measured value in the“thermal measured values”. The value changes only if the number of admissible coldrestarts ncold alters and is indicated in % and without decimal positions.

ΘL

ThermalProfile

Motor Started Motor Started Motor Started

t

Cool-down with τ·kτ–RUNNING

1stStart

2ndStart

3rdStart

t

Current

LS I >

Cool-down withτ·kτ–STOP

Maximum Allowable Rotor Temperature

Temperature Curve @:Rotor Cage Bar Upper Side LimitRotor Cage Bar Lower Side Limit Restarting

Equilibri-um Time

Equilibri-um Time

Equilibri-um Time

ncold 2 3 4

ΘRestart/ΘTrip 50 % 66,7 % 75 %ΘRestart

ΘTrip--------------------

ncold 1–

ncold---------------------=

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Restarting Times When giving the maximum allowable cold and warm starting attempts, the motor man-ufacturer assumes the motor is not restarted immediately after motor shutdown. Thisassumption is made because the distribution of heat in the rotor, is very different im-mediately after motor shutdown. Only after a certain heat equilibrium time has passedcan a new starting attempt be made.

Equilibrium Time The device can allow for the equilibrium time via a programmable time interval enteredat address 4304 T Equal. Each time the motor is shutdown, the timer starts, and thecalculated thermal profile of the rotor does not change until this timer elapses. Oncethe time interval entered at address 4304 elapses, the device assumes equilibriumhas taken place in the rotor, and the thermal profile begins to update. A time of zerocan be entered at address 4304 at the option of the user. Then the thermal model withthe corresponding time constant (rotor time constant ∗ extension factor) cools down.During the equilibrium time the motor cannot be restarted. As soon as the temperaturesinks below the restarting threshold, the next restarting attempt can be made.

Minimum InhibitTime

Regardless of thermal profiles, some motor manufacturers require a minimum inhibittime after the maximum number of permissible starting attempts has been exceeded.

The total duration of the inhibit signal depends on which of the times T MIN INIHBIT orTRESTART is longer.

Total Time Trecloseuntil release of re-close blocking

The entire time that must elapse before motor starting can resume is equal to the equi-librium time entered at address 4304 and the amount of time, calculated via the ther-mal model, that it takes for the rotor temperature to decrease to the reset temperaturelevel. If the calculated excessive temperature of the rotor is above the restarting limitwhen the motor is shut down, the minimum inhibit time will be started together with theequilibrium time. Thus the total inhibit time Treclose can become equal to the minimuminhibit time if it is longer than the sum of the two first mentioned times:

The operational measured value Treclose (visible in the “thermal measured values”) isthe remaining time until the next restart is permissible. When the rotor overtempera-ture is below the restarting limit and thus the next restarting attempt is permitted, theoperational measured value for the waiting time Treclose has reached zero.

Extension of TimeConstants

In order to properly account for the reduced heat exchange when a self-ventilated mo-tor is stopped, the cooling time constants can be increased relative to the time con-stants for a running machine with the factor Kt at STOP (address 4308). A stoppedmotor is defined by current below an adjustable current flow monitoring thresholdBkrClosed I MIN, assuming that the motor idle current is greater than this thresh-old. The pickup threshold BkrClosed I MIN also effects the thermal overload pro-tection function (see Section 2.9).

While the motor is running, the heating of the thermal profile is modelled with the timeconstant τL calculated from the motor ratings and the cool-down calculated with the

Treclose TEqual TRestart+= for TMIN INHIBIT < TEqual+ TRESTART

Treclose TMIN INHIBIT= for TMIN INHIBIT ≥ TEqual + TRESTART, if thecalculated excessive temperature > re-starting limit

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time constant τL ⋅ Kt at RUNNING (address 4309). In this way, the protection catersto the requirements in case of a slow cool-down (slow temperature equilibrium).

For the calculation of the restarting time TRESTART the following holds:

Behavior in Case ofPower SupplyFailure

Depending on the setting of parameter 0235A ATEX100 in Power System Data 1 (seeSubsection 2.1.3) the value of the thermal replica will be reset to zero if power supplyvoltage fails (ATEX100 = NO) or if it is buffered cyclically in a “non-transient” bufferstorage (ATEX100 = YES) that is preserved in the event of a supply voltage failure. Inthe latter case, the thermal replica uses the buffered values for its calculation andadapts it to the operational conditions. The first option is set by default. For further in-formation please refer to the “Device Description on the Protection of Explosion-Pro-tected Motors of Protection Type Increased-Safety e” (Order No. C53000-B1174-C157).

Emergency Start If, under emergency conditions, motor starting in excess of the maximum allowable ro-tor temperature must take place, the motor start blocking signal can be terminated viaa binary input (“>66 emer.start“), thus allowing a new starting attempt.The thermalrotor profile continues to function, however, the maximum allowable rotor temperaturewill be exceeded. No motor shutdown will be initiated by motor start blocking, but thecalculated excessive temperature of the rotor can be observed for risk assessment.

Blocking/Logic The restarting limit does not feature a pickup annunciation and neither a fault record-ing is initiated. If the motor start blocking function is blocked via binary input “>BLOCK 66” or switched off, the thermal profile of the excessive rotor temperature and the equi-librium time are reset, and any existing motor start blocking signal is terminated.

Via a binary input (“>66 RM th.repl.”) the thermal replica can be reset indepen-dently. This may be useful for testing and commissioning, and after a power supplyvoltage failure.

Figure 2-42 shows the logic diagram of the start inhibit for motors function.

TRESTART kτat STOP τL lnΘpre ncold⋅

ncold 1–-----------------------------⋅ ⋅=

TRESTART kτat RUNNING τL lnΘpre ncold⋅

ncold 1–-----------------------------⋅ ⋅=

at Stop

at Running

with kτ at STOP – extension factor for the time constant =Kt at STOP, address 4308

kτ at RUNNING – extension factor for the time constant =Kt at RUNNING, address 4309

τL– rotor time constant, calculated internally:

τL = ta ⋅ (ncold – nwarm) ⋅ ΙSTARTUP2 with ta = startup time in s

ΙSTARTUP = startup current in pu

Θpre – thermal replica the instant the motor stops (depends on theoperational status)

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Figure 2-42 Logic Diagram of the Start Inhibit for Motors Function

2.7.3 Programming Settings

2.7.3.1 General

Motor starting protection is only effective and accessible if address 0141 48 was setto Enabled during configuration of protective function. If the motor starting protection

ΘL(t) > ΘRES

66 ACTIVE

>66 emer.start

„1“

or

kτSTOP x τCB closed

IcIb

Ia

>BLOCK 66

or

Imax

ΘL = 0

S Q

R

= Motor is running

T 0

&

&

ΘL(t) Calculator

66 TRIP

66 OFF

66 BLOCKED

or

kτRUNNING x τ

>66 RM th.repl. or

S Q

R

T 0

&

66 RM th.repl.

4309 Kt at RUNNING

4308 Kt at STOP

4304 T Equal0212 CB Cl

4302 STARTUP CURRENT

4303 STARTUP TIME

4306 MAX.WARM STARTS

4307 #COLD-#WARM

4310 T MIN. INHIBIT

4301 FCT 66

FNo. 04823FNo. 04827

FNo. 04829

FNo. 04825

FNo. 04826

FNo. 04824

FNo. 04822

OFF

ON

FNo. 04828

or

Measurement/Logic

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feature is not required, address 0141 should be set to Disabled. The function mayswitched ON or OFF at address 4101 48.

The motor start inhibit function is only in effect and accessible if address 0143 66 #of Starts is set to Enabled during configuration of protective functions. If thefunction is not needed, then Disabled is set. The function can be turned ON or OFFunder address 4301 FCT 66.

2.7.3.2 Motor Starting Protection (48)

Under normal conditions the values of the startup current are entered at address 4102STARTUP CURRENT and those of the startup time at address 4103 STARTUP TIME.At all times this enables timely tripping if the value I2t calculated in the protection de-vice is exceeded.

If the startup time is longer than the permissible blocked rotor time, an external rpm-counter can initiate the definite-time tripping characteristic via binary input(“>Rotor locked“). A locked rotor leads to a loss of ventilation and therefore to areduced thermal load capacity of the machine. For this reason the motor starting timesupervision is to issue a tripping command before reaching the thermal tripping char-acteristic valid for normal operation.

A current above the current threshold is interpreted as motor startup. Consequently,this value must be selected such that under all load and voltage conditions during mo-tor startup the actual startup current safely exceeds the setting, but stays below thesetting in case of permissible, momentary overload.

Example: Motor with the following data:

The setting for Address 4102 STARTUP CURRENT is calculated as follows:

For reduced voltage, the start-up current is also reduced almost linearly. At 80% nom-inal voltage, the start-up current in this example is reduced to

0.8 * I.STARTUP = 2.5 A.

The setting at address 1107 I MOTOR START must lie above the maximum load cur-rent and below the minimum start-up current. If no other influencing factors arepresent (peak loads), the value set at address 1107 may be a median value:

Nominal Voltage V N = 6600 V

Nominal Current IG = 126 A

Start-Up Current ISTARTUP = 624 A

Long-Term Current Rating IMAX = 135 A

Start-Up Duration for ISTARTUP TSTA MAX = 8.5 sec

CT Ratio IN CT prim / IN CT sec 200 A / 1 A

ISTARTUP-sec

ISTARTUP

IN CT prim------------------------ IN CT sec⋅ 624 A

200 A--------------- IA⋅ 3.12 A= = =

135 A200 A--------------- 0.68 IN CT sec⋅=Based on the Long-Term Current Rating:

ISTARTUP-SEC

2.5 IN 0.68 IN+

2---------------------------------------- 1.6 INCT sec⋅≈=

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For ratios deviating from nominal conditions, the motor tripping time changes:,

At 80 % of nominal voltage (which corresponds to 80 % of nominal starting current),the tripping time is:

After the definite time characteristic times out (4104 LOCK ROTOR TIME), the blockedrotor binary input becomes effective and initiates a tripping signal. If the time delay as-sociated with the definite time characteristic is set such that at normal startup the bi-nary input “>Rotor locked” (06805) is blocked during the delay time LOCK ROTOR TIME, a shorter delay time of the tripping command can be realized than for unblockedstartup.

2.7.3.3 Start Inhibit for Motors (66, 86)

Many of the variables needed to calculate the rotor temperature are supplied by themotor manufacturer. Among these variables are the starting current, the nominal mo-tor current, the maximum allowable starting time T START MAX (address 4303), thenumber of allowable starts from cold conditions (ncold), and the number of allowablestarts from warm conditions (nwarm).

The starting current is entered at address 4302 IStart/IMOTnom, expressed as amultiple of nominal motor current. In contrast, the nominal motor current is entered asa secondary value, directly in amperes, at address 4305 I MOTOR NOMINAL. Thenumber of warm starts allowed is entered at address 4306 MAX.WARM STARTS andthe difference between the number of allowable cold and warm starts is entered at ad-dress 4307 #COLD-#WARM.

For motors without separate ventilation, the reduced cooling at motor stop can be ac-counted for by entering the factor Kt at STOP at address 4308. As soon as the cur-rent no longer exceeds the current flow monitoring setting entered at address 0212 BkrClosed I MIN, the time constant is increased by the kτ factor.

If no difference between the time constants is to be used (e.g. externally-ventilatedmotors), then the factor Kt at STOP should be set to 1.

Cool-down with running motor is influenced by the extension factor 4309 Kt at RUN-NING. This factor considers that motor running under load and a stopped motor do notcool down at the same speed. It becomes effective as soon as the current exceedsthe value set at address 0212 BkrClosed I MIN. With Kt at RUNNING = 1 theheating and the cooling time constant are the same at operating conditions(I > BkrClosed I MIN).

TTRIP

ISTARTUP

I------------------------

2TSTARTUP⋅=

TTRIP624 A

0.8 624 A⋅----------------------------

28.5 s⋅ 13.3 s= =

Note:

Overload protection characteristic curves are effective during motor starting condi-tions, however, thermal dissipation during motor starting is constant. The setting ataddress 1107 (I MOTOR START) limits the working range of the overload protectionto larger current values.

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Example: Motor with the following data:

Nominal Voltage VN = 6600 V

Nominal Current IN = 126 A

Starting Current IStart= 624 A

Starting Duration @ IStart TANL max = 8.5 s

Allowable Starts with Cold Motor ncold= 3

Allowable Starts with Warm Motor nwarm= 2

Current Transformer Ratio 200 A/1 A

The following settings are derived from these data:

The following settings are made:IStart/IMOTnom = 4.9I MOTOR NOMINAL = 0.6 AT START MAX=8.5 sMAX.WARM STARTS= 2#COLD-#WARM = 1

For the rotor temperature equilibrium time, (address 4304) a setting time of approx. T Equal = 1 min has proven to be a good value. The value for the minimum inhibit time4310 T MIN. INHIBIT depends on the requirements made by the motor manufac-turer, or by the system conditions. It must in any case be higher than 4304 T Equal.In this example, a value has been chosen that reflects the thermal profile (T MIN. INHIBIT = 6.0 min).

The motor manufacturer's, or system requirements determine also the extension fac-tor for the time constant during cool-down, especially with the motor stopped. Whereno other specifications are made, the following settings are recommended:Kt at STOP = 5 und Kt at RUNNING = 2.

For a proper functioning, it is also important that the CT values and the threshold cur-rent for distinction between stopped and running motor (address 0212 BkrClosed I MIN, recommended setting ≈ 0.1 ⋅ I/IN Motor) have been set correctly. An overviewof the parameters and their default settings is given in the tables at the end of this sec-tion and in the Appendix.

TemperatureBehavior duringChangingOperating States

For a better understanding of the above considerations several possible operatingstates in two different operating areas will be discussed in the following paragraph.The examples use the settings indicated above. 3 cold and 2 warm startup attemptshave resulted in a restart limit of 66.7 %:

A. Below the thermal restarting limit

1.A normal startup brings the machine into a temperature range below the thermalrestarting limit and the machine is stopped. The stop launches the equilibriumtime 4304 T Equal and generates the message “66 TRIP“. The equilibriumtime expires and the message “66 TRIP“ is cleared. During the time T Equalthe thermal model remains “frozen“ (see Figure 2-43, to the left).

ISTART IN⁄ 624 A126 A--------------- 4.95= =

IN126 A200 A--------------- 0.62 INCTsec⋅= =

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2.A normal startup brings the machine into a temperature range below the thermalrestarting limit, the machine is stopped and is started by an emergency startupwithout expiration of the equilibrium time. The equilibrium time is shed and thethermal model is released and “66 TRIP“ is reported cleared (see Figure 2-43,to the right).

Figure 2-43 Startups according to examples A.1 and A.2

B. Above the thermal restarting limit:

1.A startup brings the machine from load operation into a temperature range farabove the thermal restarting limit and the machine is stopped. The minimum in-hibit time and the equilibrium time are started and “66 TRIP“ is reported. Thetemperature cool-down below the restarting limit takes longer than 4310 T MIN. INHIBIT and 4304 T Equal, so that the time passing until the temper-ature falls below the temperature limit is the decisive factor for clearing the mes-sage “66 TRIP“. The thermal model remains “frozen” while the minimum inhibittime expires (see Figure 2-44, to the left).

0

0.2

0.4

0.6

0.8

1.0

t

p.u.

Temperature

Restarting

t

Current

66 TRIP

t

BkrClosed

Example A.1 Example A.2

Emergency startup

I MIN

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2.A startup brings the machine from load operation into a temperature range justabove the thermal restarting limit and the machine is stopped. The minimum in-hibit time and the equilibrium time are started and “66 TRIP“ is reported. Al-though the temperature soon falls below the restarting limit, the blocking “66TRIP“ is preserved until the equilibrium time and the minimum inhibit time haveexpired (see Figure 2-44, to the right).

Figure 2-44 Startups according to examples B.1 and B.2

2.7.3.4 Settings

In the list below, the setting range and default setting value for the current-based set-ting are for a device with a nominal current rating IN = 1 A. For a nominal current ratingIN = 5 A, multiply the Setting Options values and Default Setting value by 5. Considerthe current transformer ratios when setting the device with primary values.

0

0.2

0.4

0.6

0.8

1.0

t

p.u.

Temperature

Restarting

t

Current

66 TRIP

t

BkrClosed

Example B.1 Example B.2

T Equal

T MIN. INHIBIT T Equal

T MIN. INHIBIT

I MIN

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Functions

2.7.3.5 Information

Addr. Setting Title Setting Options Default Setting Comments

1107 I MOTOR START 0.60..10.00 A 2.50 A Motor Start Current (Block 49,Start 48)

Addr. Setting Title Setting Options Default Setting Comments

4101 FCT 48/66 OFFON

OFF 48 / 66 Motor (Startup Monitor/Counter)

4301 FCT 66 OFFON

OFF 66 Startup Counter for Motors

4102 STARTUP CUR-RENT

1.00..16.00 A 5.00 A Startup Current

4103 STARTUP TIME 1.0..180.0 sec 10.0 sec Startup Time

4104 LOCK ROTORTIME

0.5..120.0 sec; ∞ 2.0 sec Permissible Locked Rotor Time

4302 IStart/IMOTnom 3.0..10.0 4.9 I Start / I Motor nominal

4303 T START MAX 3..320 sec 10 sec Maximum Permissible StartingTime

4304 T Equal 0.0..320.0 min 1.0 min Temperature Equalizaton Time

4305 I MOTOR NOMINAL 0.20..1.20 A 1.00 A Rated Motor Current

4306 MAX.WARMSTARTS

1..4 2 Maximum Number of WarmStarts

4307 #COLD-#WARM 1..2 1 Number of Cold Starts - WarmStarts

4308 Kτ at STOP 0.2..100.0 5.0 Extension of Time Constant atStop

4309 Kτ at RUNNING 0.2..100.0 2.0 Extension of Time Constant atRunning

4310 T MIN. INHIBIT 0.2..120.0 min 6.0 min Minimum Restart Inhibit Time

F.No. Alarm Comments

06801 >BLK START-SUP >BLOCK Startup Supervision

06805 >Rotor locked >Rotor locked

06811 START-SUP OFF Startup supervision OFF

06812 START-SUP BLK Startup supervision is BLOCKED

06813 START-SUP ACT Startup supervision is ACTIVE

06821 START-SUP TRIP Startup supervision TRIP

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Motor Protection (Motor Starting Protection, 48 and Start Inhibit for Motors, 66/68)

06822 Rotor locked Rotor locked

06823 START-SUP pu Startup supervision Pickup

04822 >BLOCK 66 >BLOCK Motor Startup counter

04823 >66 emer.start >Emergency start

04828 >66 RM th.repl. >66 Reset thermal memory

04824 66 OFF 66 Motor start protection OFF

04825 66 BLOCKED 66 Motor start protection BLOCKED

04826 66 ACTIVE 66 Motor start protection ACTIVE

04827 66 TRIP 66 Motor start protection TRIP

04829 66 RM th.repl. 66 Reset thermal memory

F.No. Alarm Comments

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Functions

2.8 Frequency Protection (81 O/U)

2.8.1 Description of Frequency Protection

General The frequency protection function detects abnormally high and low frequencies in thesystem. If the frequency lies outside the allowable range, appropriate actions are ini-tiated, such as load shedding or separating a generator from the system.

A decrease in system frequency occurs when the system experiences an increase inthe real power demand, or when a malfunction occurs with a generator governor orautomatic generation control (AGC) system.

An increase in system frequency occurs when large blocks of load are removed fromthe system, or again when a malfunction occurs with a generator governor or AGCsystem.

The frequency is detected from the phase–to–phase voltages Va-b applying at the de-vice. If the amplitude of this voltage is too small, one of the other phase–to–phase volt-ages is used instead.

Through the use of filters and repeated measurements, the frequency evaluation isfree from harmonic influences and very accurate.

Underfrequencyand OverfrequencyProtection

Frequency protection consists of four frequency elements. Any given frequency ele-ment can be set to pickup for either overfrequency or underfrequency conditions. Eachelement can be independently set, and utilized to perform different functions within thesystem. The setting decides on the purpose of the individual frequency stage. For thef4 frequency stage, the user can specify independently of the parameterized limit val-ue if this stage shall function as decrease or increase stage. For this reason, it can alsobe used for special applications, if, for example, the user desires a signalization incase of a frequency overrange being below the nominal frequency.

Operating Ranges The frequency can be determined as long as at least one of the phase–to–phase volt-ages is present and of sufficient magnitude. If the measurement voltage drops belowa settable value Vmin, then frequency protection is blocked. For elements used in anunderfrequency protection mode, as soon as the frequency of the measured voltagedecreases below the setting, the element picks up and remain picked up until the sys-tem frequency increases above the setting. For elements used in an overfrequencyprotection mode, as soon as the frequency of the measured voltage increases abovethe setting, the element picks up and remains picked up until the frequency decreasesbelow the setting.

Logic Each frequency element has an associated settable time delay. When a frequency el-ement picks up and the time delay elapses, a trip signal is generated. When a frequen-cy elements drops out, the control signal (tripping or alarm signal) is immediately ter-minated, but not before the minimum command duration 0210A TMin TRIP CMDhas elapsed. Each of the four frequency elements can be blocked individually by bi-nary inputs. Figure 2-45 shows the logic diagram for the frequency protection function.The 81 element is a definite time element in that the time delay is not a function of thefrequency magnitude.

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Frequency Protection (81 O/U)

Figure 2-45 Logic Diagram of the Frequency Protection

2.8.2 Programming Settings

2.8.2.1 General

The frequency protection will only be effective and accessible if address 0154 81 O/U is set to Enabled during configuration of protective functions. If the frequency pro-tection function is not required, then address 0154 should be set to Disabled. Thefunction can be turned ON or OFF at address 5401 FCT 81 O/U.

Minimum Voltage The minimum voltage is set at address 5402 Vmin. If the phase–to–phase voltage isless than this value, the frequency protection is blocked.

2.8.2.2 Frequency Protection Settings

Pickup Values The nominal system frequency is programmed in POWER SYSTEM DATA 1 and thepickup settings for each of the frequency elements should be set higher than nominalfrequency if the element is to be used for overfrequency protection or lower than thenominal frequency if the element is to be used for underfrequency protection.

&

0T

„1“

81 BLOCKED

f

U1V > Vmin

f >

f <

>BLOCK 81-1

81 ACTIVE

81-1 picked up

81-1 TRIP

or or

81 OFF

or 81 Under V Blk

FNo. 052325402 Vmin

5401 FCT 81 O/U

5403 81-1 PICKUP

5405 81-1 DELAY

FNo. 05236

FNo. 05214

FNo. 05211

FNo. 05213

FNo. 05212FNo. 05203

FNo. 05206

ON

OFF

>BLOCK 81O/U

Measurement/Logic

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Functions

If underfrequency protection is used for load shedding purpose, then the frequencysettings relative to other feeder relays are generally based on the priority of the cus-tomers served by the protective relay. The actual settings of the underfrequency ele-ments must be based on network stability requirements.

For 60 Hz systems, the frequency pickup settings for elements one (1) through four(4) are entered at addresses 5404, 5407, 5410, and 5413 respectively.

For 50 Hz systems, the frequency pickup settings for elements one (1) through four(4) are entered at addresses 5403, 5406, 5409, and 5412 respectively.

Delays The time delays (Definite Time) entered at addresses 5405, 5408, 5411, and 5414,allow the device to prioritize or order corrective actions based on the degree to whichthe actual system frequency departs (upward or downward) from the nominal systemfrequency.

2.8.2.3 Settings for Frequency Protection

For 60 Hz systems:

For 50 Hz systems:

Note:

If the element is not required, the frequency setting should be set equal to the nominalfrequency, in which case the element becomes inactive.

Addr. LCD-Text Setting Options Default Setting Comments

5401 FCT 81 O/U OFFON

OFF 81 Over/UnderFrequency Protection

5402 Vmin 10 .. 150 V 65 V Minimum requiredvoltage for operation

5404 81–1 PICKUP 55.50 .. 64.50 Hz 59.50 Hz 81-1 Pickup

5405 81–1 DELAY 0.00 .. 100.00 sec; ∞ 60.00 sec 81-1 Time Delay

5407 81–2 PICKUP 55.50 .. 64.50 Hz 59.00 Hz 81-2 Pickup

5408 81–2 DELAY 0.00 .. 100.00 sec; ∞ 30.00 sec 81-2 Time Delay

5410 81–3 PICKUP 55.50 .. 64.50 Hz 57.50 Hz 81-3 Pickup

5411 81–3 DELAY 0.00 .. 100.00 sec; ∞ 3.00 sec 81-3 Time delay

5413 81–4 PICKUP 55.50 .. 64.50 Hz 61.00 Hz 81-4 Pickup

5414 81–4 DELAY 0.00 .. 100.00 sec; ∞ 30.00 sec 81-4 Time delay

Addr. LCD-Text Setting Options Default Setting Comments

5401 FCT 81 O/U OFFON

OFF 81 Over/UnderFrequency Protection

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Frequency Protection (81 O/U)

2.8.2.4 Information List for Frequency Protectio

5402 Vmin 10 .. 150 V 65 V Minimum requiredvoltage for operation

5403 81–1 PICKUP 45.50 .. 54.50 Hz 49.50 Hz 81-1 Pickup

5405 81–1 DELAY 0.00 .. 100.00 sec; ∞ 60.00 sec 81-1 Time Delay

5406 81–2 PICKUP 45.50 .. 54.50 Hz 49.00 Hz 81-2 Pickup

5408 81–2 DELAY 0.00 .. 100.00 sec; ∞ 30.00 sec 81-2 Time Delay

5409 81–3 PICKUP 45.50 .. 54.50 Hz 47.50 Hz 81-3 Pickup

5411 81–3 DELAY 0.00 .. 100.00 sec; ∞ 3.00 sec 81-3 Time delay

5412 81–4 PICKUP 45.50 .. 54.50 Hz 51.00 Hz 81-4 Pickup

5414 81–4 DELAY 0.00 .. 100.00 sec; ∞ 30.00 sec 81-4 Time delay

Addr. LCD-Text Setting Options Default Setting Comments

F.No. Alarm Comments

05203 >BLOCK 81O/U >BLOCK 81O/U

05206 >BLOCK 81-1 >BLOCK 81-1

05207 >BLOCK 81-2 >BLOCK 81-2

05208 >BLOCK 81-3 >BLOCK 81-3

05209 >BLOCK 81-4 >BLOCK 81-4

05211 81 OFF 81 OFF

05212 81 BLOCKED 81 BLOCKED

05213 81 ACTIVE 81 ACTIVE

05214 81 Under V Blk 81 Under Voltage Block

05232 81-1 picked up 81-1 picked up

05233 81-2 picked up 81-2 picked up

05234 81-3 picked up 81-3 picked up

05235 81-4 picked up 81-4 picked up

05236 81-1 TRIP 81-1 TRIP

05237 81-2 TRIP 81-2 TRIP

05238 81-3 TRIP 81-3 TRIP

05239 81-4 TRIP 81-4 TRIP

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Functions

2.9 Thermal Overload Protection (49)

2.9.1 Description of Thermal Overload Protection

General The thermal overload protection feature of the 7SJ62/63/64 is designed to preventoverloads from damaging the protected equipment.

The device is capable of projecting excessive operating temperatures for the protect-ed equipment in accordance with a single-body thermal model, based on the followingdifferential equation:

If the ambient or coolant temperature is not measured, a constant value of ϑu = 40°Cis assumed so that Θu = 0.

The thermal overload protection feature models a heat image of the equipment beingprotected. Both the previous history of an overload and the heat loss to the environ-ment are taken into account.

Thermal overload protection calculates the operating temperature of the protectedequipment as a percent of the maximum allowable operating temperature. When thecalculated operating temperature reaches a settable percentage (49 Q ALARM) of themaximum allowable operating temperature, a warning message is issued to allow timefor the load reduction measures to take place. When the calculated operating temper-ature reaches 100 % of the maximum allowable operating temperature, a trip signal isinitiated to de-energize the overloaded equipment. Initiation of a trip signal is based onthe phase with the highest calculated temperature.

The maximum thermally-permissible continuous current Imax is described as a multipleof the nominal current IN:

dΘdt--------

1τ th------- Θ⋅+

1τ th-------

Ik IN⋅------------- 2

Θu+ ⋅=

where Θ – Actual operating temperature expressed as a percent of theoperating temperature corresponding to the maximum permissibleoperating current (k*IN)

τth – Thermal time constant for the heating of the equipment beingprotected

I – Operating current expressed as a percentage of the maximumpermissible operating current (k*IN)

k – k–factor indicating the maximum permissible constant phasecurrent referred to the nominal current of the protected object

IN – Nominal current of the protected object

Θu

ϑ u 40°C–

k2 ϑ N⋅

--------------------------=

where ϑu – Measured ambient or coolant temperature

ϑN – Temperature at nominal current

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Thermal Overload Protection (49)

Imax = k × IN

For thermal overload protection to calculate operating temperature as a percent ofmaximum allowable operating temperature, it is necessary to enter the k factor setting(49 K-FACTOR), the time constant setting τth (TIME CONSTANT) and the warningtemperature level Θ (49 Q ALARM) in percent of the trip temperature ΘTRIP.

Thermal overload protection also features a current warning element (I ALARM) in ad-dition to the temperature warning stage. The current warning element may report anoverload current prematurely, even if the calculated operating temperature has not yetattained the warning or tripping levels.

CoolantTemperature(AmbientTemperature)

The device can account for external temperatures. Depending on the type of applica-tion, this may be a coolant or ambient temperature. The temperature can be measuredvia a temperature detection unit (RTD-box). For this purpose, the required tempera-ture detector is connected to detector input 1 of the first RTD-box. If incorrect temper-ature values are measured or there are disturbances between the RTD-box and thedevice, an alarm will be issued and the standard temperature of ϑu = 40° C is used forcalculation with the ambient temperature detection simply being ignored.

For the detection of coolant temperature, the maximum permissible current Imax is in-fluenced by the difference between the coolant and the standard temperature of40° C. If the ambient or coolant temperature is low, the protected object can becharged higher than it is when the temperature is high.

Extension of TimeConstants

When using the device to protect motors, the varying thermal behaviors associatedwith cycling the motor on and off may be correctly evaluated. Under a cycling condi-tion, a motor without external cooling losses heat more slowly, and a longer thermaltime constant must be used. For a motor that is cycled on and off, the 7SJ62/63/64increases the time constant τth by a programmable factor (kτ factor). The motor is con-sidered off the motor currents drop below a programmable minimum current setting(BkrClosed I MIN, refer to “Current Flow Monitoring” in Subsection 2.1.3). For ex-ternally-cooled motors, cables, and transformers, the Kt-FACTOR = 1.

Blocking The thermal overload protection feature may be reset via a binary input(“>RES 49 Image”). The current-induced overtermperature value is reset to zero.The same is accomplished via the binary input (“>BLOCK 49 O/L”); in that case theoverload protection is blocked completely, including the current warning stage.

When motors must be started for emergency reasons, operating temperatures abovethe maximum permissible operating temperatures can be allowed by blocking the trip-ping signal via a binary input (“>EmergencyStart”). Since the calculated operatingtemperature may be higher than the maximum allowable operating temperature afterdrop out of the binary input has taken place, the thermal overload protection functionfeatures a programmable run-on time interval (T EMERGENCY) which is started whenthe binary input drops out. Tripping will be defeated until this time interval elapses. Ona final note, the binary input used for emergency starting affects only the tripping sig-nal. There is no effect on the fault condition protocol nor does the thermal image reset.

Behavior in Case ofPower SupplyFailure

Depending on the setting in address 0235A ATEX100 of Power System Data 1 (seeSubsection 2.1.3) the value of the thermal replica is either reset to zero (ATEX100 =NO) if the power supply voltage fails, or cyclically buffered in a non-volatile memory(ATEX100 = YES) until the power supply voltage is back again. In the latter case, the

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Functions

thermal replica uses the stored value for calculation and matches it to the operatingconditions. The first option is the default setting. For further information, please referto “Device Description on the Protection of Explosion-Protected Motors of ProtectionType Increased-Safety e” (Order No. C53000-B1174-C157).

Figure 2-46 shows the logic diagram for thermal overload protection.

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Thermal Overload Protection (49)

Figure 2-46 Logic Diagram for Thermal Overload Protection

4207A Kt-FACTOR

dΘdt--------

1τ th-------- Θ⋅+

1τ th--------

Ik IN⋅--------------

2Θu+

⋅=

49 Winding O/L

„1“

or 49 O/L I Alarm

I >

I >

Θ>

Θ>

49 Th O/L TRIP

49 Ο/Λ Θ ΑλαρµΘmax

CB closed

Ia

&

IbIc

>BLOCK 49 O/L

49 O/L ACTIVE

or

>EmergencyStartT0

I >

Θ=

cons

t.

Θ = 0

49 O/L BLOCK

49 O / L OFF

or

100 %

4205 I ALARM

FNo. 01515

4202 49 K-FACTOR

4203 TIME CONSTANT

0212 BkrClosed I MIN

1107 I MOTOR START

4201 FCT 49

4204 49 Q ALARM

4208A T EMERGENCY

FNo. 01516

FNo. 01521

FNo. 01517

FNo. 01512

FNo. 01513

FNo. 01511

FNo. 01507

FNo. 01503

ONOFF

Alarm Only

Θu

Θu = 0° C

Θu

0142 FCT 49

No ambient tempDisabled

With amb. temp.

(RTD-box)

>RES 49 ImageFNo. 01580

or

49 Image res.FNo. 01581

&

τth

τth = Kτ ⋅ Time Constantτth = Time Constant

Measurement/Logic

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Functions

2.9.2 Programming Settings

2.9.2.1 General

Thermal overload protection is only effective and accessible if address 0142 49 wasset to No ambient temp or With amb. temp. during configuration of protectivefunctions. If the thermal overload protection is not required, address 0142 49 shouldbe set to Disabled.

Transformers and cable are prone to damage by overloads which last for an extendedperiod of time. For this reason, fault protection elements such as the directional andnon-directional overcurrent elements should not be used to protect against overload.The short time delays associated with fault protection elements do not allow sufficienttime for the orderly curtailment of load by operating personnel. In addition, fault pro-tection elements set to trip for overload will not allow short-duration, non-damagingoverloads – a practice which is often required in real operating situations.

The 7SJ62/63/64 protective relay features an thermal overload protective function witha thermal tripping characteristic curve which may be adapted to the overload toleranceof the equipment being protected.

Thermal overload protection may be switched ON or OFF or Alarm Only at address4201 FCT 49. If switched ON, tripping is also possible.

2.9.2.2 Overload Settings

k–Factor The nominal device current is used as a basis for overload detection. The program-mable 49 K-FACTOR (set at address 4202) is calculated as the ratio of the thermally-permissible continuous current Imax to the nominal device current IN:

The thermally-permissible continuous current for the equipment being protected isknown from manufacturer’s specifications. The thermal overload function is normallynot applicable to aerial lines since the actual current capability of aerial lines is depen-dent on factors that are generally unknown (e.g. wind speed, ambient temperature,etc.). For cables, the permissible continuous current is dependent on the cross-sec-tion, insulating material, design, and the cable routing, among other things. It may betaken from pertinent tables, or is specified by the cable manufacturer. If no specifica-tions are available, a value of 1.1 times the nominal current rating is assumed.

When determining the nominal current rating of the protected equipment, it is impor-tant to relate this current to the nominal current rating of the device. For example, themaximum permissible continuous current for a motor and the nominal current rating ofthe motor are given in primary amperes.

For the k factor to be set based on the nominal device current, the following equationmust be used:

kImax

IN-----------=

kImax prim

INMotor---------------------

INMotor

IN CT prim------------------------⋅=Set the 49 K-FACTOR

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Thermal Overload Protection (49)

Example: Motor and current transformer with the following data:

Time Constant τth The thermal overload protection element tracks excessive temperature progression,employing a thermal differential equation whose solution is an exponential function.The TIME CONSTANT τth (set at address 4203) is used in the calculation to determinethe operating temperature. This is expressed as a maximum allowable operating tem-perature.

For cable protection, the heat-gain time constant τth is determined by cable specifica-tions and by the cable environment. If no time-constant specification is available, itmay be determined from the short-term load capability of the cable. The 1-sec current(i.e. the maximum current permissible for a one-second period of time), is often knownor available from tables. Then, the time constant may be calculated from the formula:

If the short-term load capability is given for an interval other than one sec, the corre-sponding short-term current is used in the above formula instead of the 1-sec current,and the result is multiplied times the given duration. For example, if the 0.5-secondcurrent rating is known,

It is important to note, however, that the longer the effective duration, the less accuratethe result.

Example:

Cable and current transformer with the following data:

Continuous permissible current Imax = 500 A @ 40 oC

Maximum current for 1 sec I1s = 45 * Imax = 22.5 kA

Current transformer 600 A / 1 A

The k factor and time constant are calculated as follows:

where Imax prim Maximum permissible continuous motor current in primaryamperes

IN Motor Nominal motor current in primary amperesIN CT prim Current transformer primary nominal current

Permissible Continuous Current: Imax prim= 1.2 · IN

Motor Nominal Current IN Motor = 1100 A

Current Transformer Ratio 1200 A/1 A

1.21100 A1200 A-------------------⋅ 1.1=Set the 49 K-FACTOR =

Set Value τ th (min)160------

I1 sec

Imax Prim----------------------

2×=

et Value τ th (min)0.560--------

I0.5 sec

Imax Prim----------------------

2×=

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Functions

The settings are: 49 K-FACTOR (Address 4202)= 0.83TIME CONSTANT = 33.7 min

Warning Tempera-ture Level

By setting the thermal warning level 49 Q ALARM at address 4204, a warning mes-sage can be issued prior to tripping, thus allowing time for load curtailment proceduresto be implemented. This warning level simultaneously represents the dropout level forthe tripping signal. In other words, the tripping signal is interrupted only when the cal-culated operating temperature falls below the warning level, thus allowing the protect-ed equipment to be placed back into service.

The thermal warning level is given in % of the tripping temperature level (maximumallowable operating temperature).

A current warning level is also available (I ALARM 4205). The setting at address 4205corresponds to secondary amperes, of course, and should be set equal to, or slightlyless than, permissible continuous current (k * INsec). The current warning level may beused in lieu of the thermal warning level by setting the thermal warning level to 100 %.

Extension of TimeConstants

The time constant programmed at address 4203 is valid for a running motor. For cy-cling motors without external cooling, the motor loses heat more slowly. For a cyclingmotor, the 7SJ62/63/64 takes the reduced heat loss into account by increasing thetime constant τth by a programmable factor (Kt-FACTOR, set at address 4207A).Motor stop is detected if the current falls below the threshold value BkrClosed I MIN of the current flow monitoring (see side title “Current Flow Monitoring” in Subsec-tion 2.1.3) assuming that the motor idle current is greater than this threshold. The pick-up threshold BkrClosed I MIN affects also the following protection functions: volt-age protection, breaker failure protection and restart inhibit for motors.

If no distinguishing of the time constants is necessary (e.g. externally-cooled motors,cables, transformers, etc.) the Kt-FACTOR is set at 1 (Default Setting value).

EmergencyStarting

The drop-out time T EMERGENCY to be entered at address 4208A must ensure thatafter an emergency startup and after dropout of the binary input “>EmergencyStart“the trip command is blocked until the thermal replica is below the dropout thresholdagain.

Ambient or CoolantTemperature

The indications specified up to now are sufficient for a temperature rise replica. Theambient or coolant temperature, however, can also be processed. This has to be com-municated to the device as digitalized measured value via the interface. During con-figuration the parameter 0142 49 must be set to With amb. temp.

If the ambient temperature detection is used, the user must be aware that the 49 K-FACTOR to be set refers to an ambient temperature of ϑu = 40 °C, i.e. it correspondsto the maximum permissible current at a temperature of 40 °C.

kImax

IN-----------

500 A600 A--------------- 0.833= = =

τmin160------

I1s

Imax----------- ⋅ 1

60------ 45

2⋅ 33.75 min= = =

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Thermal Overload Protection (49)

All calculations are performed with standardized quantities. The ambient temperaturemust also be standardized. The temperature with nominal current is used as standard-ized quantity. If the nominal current deviates from the nominal CT current, the temper-ature must be adapted according to the following formula. In address 4209 or 421049 TEMP. RISE I the temperature adapted to the nominal transformer current isset. This setting value is used as standardized quantity for the ambient temperatureinput.

mit ϑN sec – Machine temperature with secondary nominal current = setting atthe 7SJ62/63/64 relay (address 4209 or 4210)

ϑNMach – Machine temperature with nominal machine current

INprim CT – Primary rated current of the current transformers

INMach – Rated current of the machine

If the temperature input is used, the trip times change if the coolant temperature devi-ates from the internal reference temperature of 40 °C. The following formula can beused to calculate the trip time:

mit τth – TIME CONSTANT (Adresse 4203)

k – 49 K-FACTOR (Adresse 4202)

IN – Nominal device current

I – Actually flowing secondary current

Ipre – Previous load current

ϑN – Temperature with nominal current IN (Address 4209 49 TEMP. RISE I)

ϑu – Coolant temperature input(scaling with address 4209 or 4210)

Example:

Machine: INMach = 483 A

ImaxMach = 1.15 IN at ΘK = 40 °C

ϑNMach = 93° C Temperature at INMach

τth = 600 s (thermal time constant of the machine)

Current Transformer Ratio: 500 A/1 A

ϑN sec ϑ NMach

INprimCT

INMach-----------------------

2⋅=

t τ th

Ik IN⋅------------ 2 ϑu 40 °C–

k2 ϑ N⋅

---------------------------Ivor

k IN⋅------------

2–+

Ik IN⋅------------ 2 ϑ u 40 °C–

k2 ϑ N⋅

--------------------------- 1–+

-----------------------------------------------------------------------------------ln⋅=

1.15 483 A500 A---------------⋅ 1.11≈

(to be set in address 4202)K-FAKTOR =

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Motor StartingRecognition

To ascertain whether or not a motor is starting, the motor currents are compared withthe setting I MOTOR START at address 1107. If the motor currents exceed the settingat address 1107, a motor starting condition is assumed. Information on how to set ad-dress 1107 is given under “Recognition of Running Condition (only for motors)” inSubsections 2.1.6 and 2.7.3.

2.9.2.3 Settings for Thermal Overload Protection

In the list below, the setting range and default setting value for I ALARM is for a devicewith a nominal current rating IN = 1 A. For a nominal current rating IN = 5 A, multiplythe Setting Options values and Default Setting value by 5. Consider the current trans-former ratios when setting the device with primary values.

ϑNsec 93° C 500483----------

2⋅ 100° C≈=

(to be set in address 4209 or 4210 49 TEMP. RISE I)

Addr. Setting Title Setting Options Default Setting Comments

4201 FCT 49 OFFONAlarm Only

OFF 49 Thermal overload protection

4202 49 K-FACTOR 0.10..4.00 1.10 49 K-Factor

4203 TIME CONSTANT 1.0..999.9 min 100.0 min Time Constant

4204 49 Θ ALARM 50..100 % 90 % 49 Thermal Alarm Stage

4205 I ALARM 0.10..4.00 A 1.00 A Current Overload Alarm Setpoint

4207A Kτ-FACTOR 1.0..10.0 1.0 Kt-FACTOR when motor stops

4208A T EMERGENCY 10..15000 sec 100 sec Emergency time

4209 49 TEMP. RISE I 40..200 °C 100 °C 49 Temperature rise at ratedsec. curr.

4210 49 TEMP. RISE I 104..392 °F 212 °F 49 Temperature rise at ratedsec. curr.

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Thermal Overload Protection (49)

2.9.2.4 Information List for Thermal Overload Protection

F.No. Alarm Comments

01503 >BLOCK 49 O/L >BLOCK 49 Overload Protection

01507 >EmergencyStart >Emergency start of motors

01580 >RES 49 Image >49 Reset of Thermal Overload Image

01511 49 O / L OFF 49 Overload Protection is OFF

01512 49 O/L BLOCK 49 Overload Protection is BLOCKED

01513 49 O/L ACTIVE 49 Overload Protection is ACTIVE

01515 49 O/L I Alarm 49 Overload Current Alarm (I alarm)

01516 49 O/L Θ Alarm 49 Overload Alarm! Near Thermal Trip

01517 49 Winding O/L 49 Winding Overload

01521 49 Th O/L TRIP 49 Thermal Overload TRIP

01581 49 Image res. 49 Thermal Overload Image reset

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Functions

2.10 Monitoring Functions

The device is equipped with extensive monitoring capabilities - both for hardware andsoftware. In addition, the measured values are also constantly monitored for plausibil-ity, therefore, the current transformer and voltage transformer circuits are largely inte-grated into the monitoring. It is also possible to implement trip and closing circuit mon-itoring, using appropriate binary inputs as available.

2.10.1 Description of Measured Values Monitoring

2.10.1.1 Hardware Monitoring

The device is monitored from the measurement inputs to the binary outputs. Monitor-ing checks the hardware for malfunctions and disallowed conditions.

Auxiliary andReference Voltages

The processor voltage of 5 V DC is monitored, and if the voltage decreases below theminimum value, the device is removed from operation. When the normal voltage re-turns, the processor system is restarted.

Removal of or switching off the supply voltage removes the device from operation anda message is immediately generated by a dead contact. Brief voltage interruptions ofless than 50 ms do not disturb the readiness of the device (for nominal auxiliary volt-age ≥ 110 V DC).

The processor monitors the offset and reference voltage of the AD (analog-digital)converter. The protection is suspended if the voltages deviate outside an allowablerange, and lengthy deviations are reported.

Buffer Battery The buffer battery, which ensures the operation of the internal clock and the storageof counters and messages if the auxiliary voltage fails, is periodically checked forcharge status. If it is less than an allowed minimum voltage, then the “Fail Battery”message is issued.

The internal battery of 7SJ64 is switched off automatically by the clock module whenthe device has been disconnected from the auxiliary voltage for a period of 1 to 2 daysmeaning that clock management will be discontinued. The memory containing themessages and fault data is however preserved.

MemoryComponents

The working memory (RAM) is tested when the system is started up. If a malfunctionoccurs then, the starting sequence is interrupted and an LED blinks. During operation,the memory is checked using its checksum.

For the program memory, the cross sum is formed periodically and compared to thestored program cross sum.

For the settings memory, the cross sum is formed periodically and compared to thecross sum that is freshly generated each time the setting process takes place.

If a malfunction occurs, the processor system is restarted.

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Monitoring Functions

Probing Probing and the synchronization between the internal buffer components are con-stantly monitored. If any deviations cannot be removed by renewed synchronization,then the processor system is restarted.

Measurement ValueCollection – Cur-rents

Up to four input currents are measured by the device. Three of the currents corre-spond to phase currents and the fourth current corresponds to the neutral or groundcurrent measured from a separate current transformer. If all four currents inputs areconnected, their digitized sum must be zero.

Faults in the current circuit are recognized if

IF = |ia+ib+ic+(kN⋅ig) | > S I THRESHOLD ⋅ IN + S I FACTOR ⋅ Imax

The factor kN takes into account a possible difference in the neutral current transform-er ratio (e.g. toroidal current transformer see addresses 0217, 0218, 0204 and0205):

S I THRESHOLD and S I FACTOR are programmable settings. The component S I FACTOR ⋅ Imax takes into account the allowable error of the input transformer, whichcan be especially large when high fault current levels are present (Figure 2-47). Thedropout ratio is about 97%.

This malfunction is reported as “Failure S I”.

Figure 2-47 Current Sum Monitoring

2.10.1.2 Software Monitoring

Watchdog For continuous monitoring of the program sequences, a time monitor is provided in thehardware (hardware watchdog) that runs upon failure of the processor or an internalprogram, and causes a complete restart of the processor system.

kNIgnd-CT PRIM Ignd-CT SEC⁄

CT PRIMARY CT SECONDARY⁄----------------------------------------------------------------------------------------=

IFIN

ImaxIN

Σ I THRESHOLD

Increase:Σ I FACTOR

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An additional software watchdog ensures that malfunctions during the processing ofprograms are discovered. This also initiates a restart of the processor system.

To the extent such a malfunction is not cleared by the restart, an additional restart at-tempt is begun. After three unsuccessful restarts within a 30 second window of time,the device automatically removes itself from service and the red “Error” LED lights up.The readiness relay opens and indicates “device malfunction” with its normal contact.

2.10.1.3 Monitoring of External Current Transformer Circuits

Interruptions or short circuits in the secondary circuits of the current transformers orvoltage transformers, as well as faults in the connections (important for start-up!), aredetected and reported by the device. The measured quantities are periodicallychecked in the background for this purpose, as long as no system fault is present.

Current Symmetry During normal system operation (i.e. the absence of a short-circuit fault), symmetryamong the input currents is expected. This symmetry is checked by the device, usinga quantity monitor. The smallest phase current is compared to the largest phase cur-rent, and asymmetry is recognized if:

|Imin|/|Imax| < BAL. FACTOR I, as long as Imax /IN > BALANCE I LIMIT / IN

where Imax is the largest of the three phase currents and Imin is the smallest. The sym-metry factor BAL. FACTOR I represents the allowable asymmetry of the phase cur-rents while the limit value BALANCE I LIMIT is the lower limit of the operating rangeof this monitoring (see Figure 2-48). Both settings are adjustable, and the dropout ratiois about 97 %.

This malfunction is reported as “Fail I balance”.

Figure 2-48 current Symmetry Monitoring

Voltage Symmetry During normal system operation (i.e. the absence of a short-circuit fault), symmetryamong the input voltages is expected. Because the phase-to-phase voltages are in-sensitive to ground connections, the phase-to-phase voltages are used for the sym-metry monitoring. If the device is connected to the phase-to-ground voltages, then thephase-to-phase voltages are calculated accordingly, whereas if the device is connect-ed to phase-to-phase voltages and the displacement voltage, then the third phase-to-phase voltage is calculated accordingly. From the phase-to-phase voltages, the small-

IminIN

BALANCE I LIMIT

Increase:BAL.FACTOR I

ImaxIN

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Monitoring Functions

est and largest phase-to-ground voltages are calculated and compared to check forsymmetry. Asymmetry is recognized if:

|Vmin|/|Vmax| < BAL. FACTOR V, as long as |Vmax| > BALANCE V-LIMIT

where Vmax is the largest of the three phase-to-ground voltages and Vmin is the small-est. The symmetry factor BAL. FACTOR V is the measure for the asymmetry of theconductor voltages; the limit value BALANCE V-LIMIT is the lower limit of the oper-ating range of this monitoring (see Figure 2-49). Both settings are adjustable. Thedropout ratio is about 97 %.

This malfunction is reported as “Fail V balance”.

Figure 2-49 Voltage Symmetry Monitoring

Current and Volt-age Rotation

To detect swapped phase connections in the voltage and current input circuits, thephase sequence of the phase-to-phase measured voltages and the phase currentsare checked by the monitoring.

Direction measurement with normal voltages, path selection for fault location, andnegative sequence detection all assume a phase sequence of “abc”. The phase se-quence of the phase-to-ground voltages is verified by ensuring the following

Va leads Vb leads Vc leads Va

Likewise, the phase sequence of the phase currents is verified by ensuring the follow-ing

Ia leads Ib leads Ic leads Ia

Verification of the voltage rotation occurs when each measured voltage is at least

| Vc |, |Vb |, | Va| > 40V / √3.

Verification of the current rotation occurs when each measured current is at least

|Ia|, |Ib|, |Ic| > 0.5 IN.

For abnormal phase sequences, the messages “Fail Ph. Seq. V” or “Fail Ph. Seq. I” are issued, along with the switching of this message “Fail Ph. Seq.”.

For applications in which an opposite phase sequence is expected, the protective re-lay should be adjusted via a binary input or a programmable setting. If the phase se-quence is changed in the relay, phases ‘b’ and ‘c’ internal to the relay are reversed,and the positive and negative sequence currents are thereby exchanged (see also

vminV

BALANCE VLIMIT

Increase:BAL.FACTOR V

VmaxV

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Section 2.18). The phase- related messages, malfunction values, and measured val-ues are not affected by this.

2.10.1.4 Description of Fuse-Failure-Monitor

Single-Phase Mea-surement VoltageLoss or Fuse Fail-ure Monitoring

In the event of a loss of measured voltage on one phase (typically due to a short circuitor broken conductor in the voltage transformer secondary circuit), the device will false-ly detect zero voltage. False detection of zero voltage can cause problems with thedirectional overcurrent protection and the undervoltage protection.

If fuses are used instead of a secondary miniature circuit breaker with connected aux-iliary contacts, then the fuse failure monitoring can detect problems in the voltagetransformer secondary circuit. If phase-to-phase voltages and the displacement volt-age are supplied to the system, then the fuse failure monitor is masked. Of course,supervision of the miniature circuit breaker and the fuse failure monitor can be usedat the same time.

If zero sequence voltage occurs, without a ground current being measured at thesame time, the device concludes that an unsymmetrical fault has occurred in the volt-age transformer secondary circuit. The processing of the displacement voltage pro-cessing of the sensitive ground fault detection and the undervoltage protection func-tions are blocked.

2.10.2 Programming Settings for Measured Values Monitoring

2.10.2.1 General

Measured value monitoring can be turned ON or OFF at address 8101 MEASURE. SU-PERV.

The fuse–failure monitor can be set ON or OFF at address 5301 FUSE FAIL MON.

2.10.2.2 Measured Values Monitoring

The sensitivity of measured value monitor can be modified. Default values are set atthe factory, which are sufficient in most cases. If especially high operating asymmetryin the currents and/or voltages is to be expected for the application, or if it becomes

Note:

For ungrounded systems or systems which generate small amounts of ground faultcurrent, fuse failure monitoring must not be used!

Note:

For ungrounded systems or systems which generate small amounts of ground faultcurrent, fuse failure monitoring must not be used!

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Monitoring Functions

apparent during operation that certain monitoring functions activate sporadically, thenthe setting should be less sensitive.

Address 8102 BALANCE V-LIMIT determines the limit voltage (Phase-to-Phase),above which the voltage symmetry monitor is effective (see also Figure 2-49). Address8103 BAL. FACTOR V is the associated symmetry factor; that is, the slope of thesymmetry characteristic curve (Figure 2-49).

Address 8104 BALANCE I LIMIT determines the limit current, above which the cur-rent symmetry monitor is effective (see also Figure 2-48). Address 8105 BAL. FAC-TOR I is the associated symmetry factor; that is, the slope of the symmetry charac-teristic curve (Figure 2-48).

Address 8106 S I THRESHOLD determines the limit current, above which the currentsum monitor (see Figure 2-47) is activated (absolute portion, only relative to IN). Therelative portion (relative to the maximum conductor current) for activating the currentsum monitor (Figure 2-47) is set at address 8107 S I FACTOR.

2.10.2.3 Fuse-Failure-Monitor

2.10.2.4 Settings for Measured Values Monitoring

In the list below, the setting ranges and default setting values for current-based set-tings are for a device with a nominal current rating IN = 1 A. For a nominal current rat-ing IN = 5 A, multiply the Setting Options values and Default Setting values by 5. Con-sider the current transformer ratios when setting the device with primary values.

Note:

Current sum monitoring is only in effect if the ground current for the line to be protect-ed is connected.

Note:

The connections of the ground paths and their adaption factors were set when config-uring the general station data. These settings must be correct for the measured valuesmonitoring to function properly.

Note:

The settings for the fuse failure monitor (address 5302 FUSE FAIL 3Vo) are to beselected so that reliable activation occurs if a phase voltage fails, but not such thatfalse activation occurs during ground faults in a grounded network. The value enteredat address 5302 should be based on the settings entered in P.SYSTEM DATA1 re-garding the voltage transformer connections. Address 5303 FUSE FAIL RESIDmust be set below the smallest anticipated ground fault current. Fuse failure monitor-ing can be turned off completely at address 5301 FUSE FAIL MON..

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2.10.2.5 Information List for Measured Values Monitoring

Addr. Setting Title Setting Options Default Setting Comments

8101 MEASURE.SUPERV

OFFON

ON Measurement Supervision

5301 FUSE FAIL MON. ONOFF

OFF Fuse Fail Monitor

8102 BALANCE V-LIMIT 10..100 V 50 V Voltage Threshold for BalanceMonitoring

8103 BAL. FACTOR V 0.58..0.90 0.75 Balance Factor for VoltageMonitor

8104 BALANCE I LIMIT 0.10..1.00 A 0.50 A Current Threshold for BalanceMonitoring

8105 BAL. FACTOR I 0.10..0.90 0.50 Balance Factor for Current Moni-tor

8106 Σ I THRESHOLD 0.05..2.00 A; ∞ 0.10 A Summated Current MonitoringThreshold

8107 Σ I FACTOR 0.00..0.95 0.10 Summated Current MonitoringFactor

5302 FUSE FAIL 3Vo 10..100 V 30 V Zero Sequence Voltage

5303 FUSE FAIL RESID 0.10..1.00 A 0.10 A Residual Current

F.No. Alarm Comments

00162 Failure Σ I Failure: Current Summation

00163 Fail I balance Failure: Current Balance

00167 Fail V balance Failure: Voltage Balance

00161 Fail I Superv. Failure: General Current Supervision

00171 Fail Ph. Seq. Failure: Phase Sequence

00176 Fail Ph. Seq. V Failure: Phase Sequence Voltage

00175 Fail Ph. Seq. I Failure: Phase Sequence Current

00197 MeasSup OFF Measurement Supervision is switched OFF

06509 >FAIL:FEEDER VT >Failure: Feeder VT

06510 >FAIL: BUS VT >Failure: Busbar VT

06575 VT Fuse Failure Voltage Transformer Fuse Failure

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Monitoring Functions

2.10.3 Description of Trip Circuit Monitor (74TC)

The 7SJ62/63/64 are equipped with an integrated trip circuit monitor. Depending onthe number of available binary inputs, monitoring with one or two binary inputs can beselected. If the configuration of the binary inputs needed for this does not match theselected monitoring type, then a message to this effect is sent (“74TC ProgFail”).When using two binary inputs, malfunctions in the trip circuit can be detected under allcircuit breaker conditions. When only one binary input is used, malfunctions in the cir-cuit breaker itself cannot be detected.

Monitoring withTwo Binary Inputs

When using two binary inputs, these are connected according to Figure 2-50, parallelto the associated trip contact on one side, and parallel to the circuit breaker auxiliarycontacts on the other.

A condition for the use of trip circuit monitoring is that the control voltage for the circuitbreaker is greater than the sum of the minimum voltage drops of both binary inputs(VSt > 2 ⋅ VBImin). Since at least 19 V are needed for each binary input, the monitor canonly be used with a system control voltage of over 38 V.

Figure 2-50 Principle of Trip Circuit Monitor with Two Binary Inputs

Monitoring with binary inputs not only detects interruptions in the trip circuit and lossof control voltage, it also monitors the response of the circuit breaker using the positionof the circuit breaker auxiliary contacts.

Depending on the conditions of the trip contact and the circuit breaker, the binary in-puts are activated (logical condition “H” in Table 2-10), or not activated (logical condi-tion “L”).

Even for healthy trip circuits the condition that both binary inputs are not actuated (“L”)is possible during a short transition period (trip contact is closed, but the circuit breakerhas not yet opened.) A continuous state of this condition is only possible when the tripcircuit has been interrupted, a short-circuit exists in the trip circuit, a loss of batteryvoltage occurs, or malfunctions occur with the circuit breaker mechanism.

V–

V+

RTC

52b52a

VBI1

VBI2

VSt 7SJ62/63/64

7SJ62/63/64

52TC

Legend:

RTC — Trip Contact52 — Circuit Breaker52TC — Circuit Breaker Trip Coil52a — Circuit Breaker Auxiliary Contact

(closed when 52 is closed)52b — Circuit Breaker Auxiliary Contact

(closed when 52 is open)

VSt — Control VoltageVBI1 — Input Voltage for 1st Binary InputVBI2 — Input Voltage for 2nd Binary Input

Note: The above diagram refers to a closed circuitbreaker position

52

>74TC trip rel.

>74TC brk rel.

F# 06852

F# 06853

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Functions

1) Trip Circuit is faulty

The conditions of the two binary inputs are checked periodically. A check takes placeabout every 600 ms. If three consecutive conditional checks detect an abnormality (af-ter 1.8 s), an annunciation is reported (see Figure 2-51). This is used to avoid the an-nunciation for brief transition periods. When the fault in the trip circuit has beencleared, the annunciation is automatically reset.

Figure 2-51 Logic Diagram for Trip Circuit Monitoring with Two Binary Inputs

Monitoring withOne Binary Input

The binary input is connected according to figure 2-52 in parallel with the associatedtrip contact. The circuit breaker auxiliary contact 52-b is connected in series with ahigh-ohm resistor R.

The control voltage for the circuit breaker should be about two times the value of theminimum voltage drop at the binary input (VSt > 2 ⋅ VBImin). Since the minimum voltageto activate a binary input is 19 V, a DC voltage supply of 38 V or higher is required.

Table 2-10 Condition Table for Binary Inputs, Depending on RTC and CB Position

No. Relay TripContact

CircuitBreaker

52a Contact 52b Contact BI 1 BI2

1 Open Closed Closed Open H L

2 Open Open Open Closed H H

3 1) Closed Closed Closed Open L L

4 1) Closed Open Open Closed L H

& > n

n . .....Number of Condition Checks (= 3)

FAIL: Trip cir.

(Measurement Repetition Occurs every 600 ms)

>74TC trip rel.

>74TC brk rel.

F# 06852

F# 06853

F# 06865

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Figure 2-52 Principle of Trip Circuit Monitoring with One Binary Input

During normal operation, the binary input is activated (logical condition “H”) when thetrip contact is open and the trip circuit is intact, because the monitoring circuit is closedby either the 52a circuit breaker auxiliary contact (if the circuit breaker is closed) orthrough the replacement resistor R by the 52b circuit breaker auxiliary contact. Onlyas long as the trip contact is closed, the binary input is short circuited and thereby de-activated (logical condition “L”).

If the binary input is continuously de-activated during operation, this leads to the con-clusion, there is an interruption in the trip circuit or loss of control voltage.

The trip circuit monitor does not operate during system faults. A momentary closedtripping contact does not lead to a failure message. If, however, tripping contacts fromother devices operate in parallel with the trip circuit, then the failure annunciation mustbe delayed (see also Figure 2-53). The conditions of the binary input are, therefore,checked 500 times before an annunciation is sent. A condition check takes placeabout every 600 ms, so trip circuit monitoring is only activated during an actual mal-function of the trip circuit (after 300 s). After the malfunction in the trip circuit is cleared,the failure annunciation is reset automatically.

Figure 2-53 Logic Diagram for Trip Circuit Monitoring with One Binary Input

Figure 2-54 shows the logic diagram for the message that can be generated by the tripcircuit monitor, depending on the control settings and binary inputs.

V–

V+

RTC

VBI

VSt 7SJ62/63/64

7SJ62/63/64

Legend:

RTC — Trip Contact52 — Circuit Breaker52TC — Circuit Breaker Trip Coil52a — Circuit Breaker Auxiliary Contact

(closed when 52 is closed)52b — Circuit Breaker Auxiliary Contact

(closed when 52 is open)

VSt — Control VoltageVBI — Input Voltage for Binary Input

Note: The above diagram refers to a closed circuitbreaker position

R

52b52a52TC52

>74TC trip rel.F# 06852

&>74TC trip rel.

52a Contactn

n.. .....Number of Condition Checks (= 500)

>

(Measurement Repetition Occurs every 600 ms)

F# 06852

FAIL: Trip cir.F# 06865

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Figure 2-54 Message Logic for the Trip Circuit Monitor

2.10.4 Programming Settings for Trip Circuit Monitor

Trip circuit monitoring is only in effect and accessible if address 0182 was set to either2 Binary Inputs or to 1 Binary Input, and the appropriate number of binaryinputs have been masked for this purpose (refer Subsection 2.1.1). Trip circuit moni-toring can be turned ON and OFF at address 8201 FCT 74TC. If the masking of therequired binary inputs does not match the selected monitoring type, then a messageto this effect is generated (“74TC ProgFail”). If the trip circuit monitor is not to beused at all, then address 0182 should be set to Disabled. Further settings are notneeded. The message of a trip circuit interruption is delayed by a fixed amount of time.For two binary inputs, the delay is about 2 seconds, and for one binary input, the delayis about 300 s. This ensures that, for the longest possible duration of a trip signal, afalse malfunction message will not be generated.

Monitoring withOne Binary Input

NOTE: When using only one binary input (BI) for the trip circuit monitor, some mal-functions, such as interruption of the trip circuit or loss of battery voltage, can indeedbe detected, but malfunctions with closed trip contacts cannot. Therefore, the mea-surement must take place over a period of time that bridges the longest possible du-ration of a closed trip contact. This is ensured by the fixed number of measurementrepetitions and the time between the condition checks.

When using only one binary input, a resistor R is inserted into the circuit on the systemside, instead of the missing second binary input. Through appropriate sizing of the re-sistor and depending on the system relationship, a lower control voltage can often besufficient. The resistor R is inserted into the circuit of the 52b circuit breaker auxiliarycontact, to facilitate the detection of a malfunction when the 52a circuit breaker auxil-iary contact open and the trip contact has dropped out (see Figure 2-52). This resistormust be sized such that the circuit breaker trip coil is no longer energized when the

74TC ProgFail

74TC OFF

74TC BLOCKED

„1“

„1“ or

>74TC trip rel.

&

&

&

&S Q

R

>BLOCK 74TC

>74TC brk rel.

FAIL: Trip cir.

74TC ACTIVE

Function

Configured

0182 74 Trip Ct Supv

2 Binary Inputs

1 Binary Input

Disabled

8201 FCT 74TC

OFF

ON

F#. 06852

F# 06853

F# 06851

F# 06864

F# 06861

F# 06865

F# 06863

F# 06862

Configured

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circuit breaker is open (which means 52a is open and 52b is closed). The binary inputshould still be picked up when the trip contact is simultaneously opened.

This results in an upper limit for the resistance dimension, Rmax, and a lower limit Rmin,from which the optimal value of the arithmetic mean should be selected:

In order that the minimum voltage for controlling the binary input is ensured, Rmax isderived as:

So the circuit breaker trip coil does not remain energized in the above case, Rmin isderived as:

If the calculation results that Rmax < Rmin, then the calculation must be repeated, withthe next lowest pickup threshold VBI min, and this threshold must be implemented inthe device using plug-in bridges (see Subsection 8.1.3).

For the power consumption of the resistance:

Example:

IBI (HIGH) Constant Current with BI on

VBI min Minimum Control Voltage for BI (=19 V for delivery setting for nominal voltage of 24/48/60 V;=88 V for delivery setting for nominal voltage of 110/125/220/250 V)

VST Control Voltage for Trip Circuit

RCBTC DC Resistance of Circuit Breaker Trip Coil

VCBTC (LOW) Maximum Voltage on the Circuit Breaker Trip Coil that does not lead to Tripping

IBI (HIGH) 1.8 mA (from SIPROTEC® 7SJ62/63/64)

UBI min 19 V for delivery setting for nominal voltage 24/48/60 V (from SIPROTEC®7SJ62/63/64)

88 V or delivery setting for nominal voltage 110/125/220/250 V) (from SIPROTEC® 7SJ62/63/64)

VST 110 V (from system / release circuit)

RCBTC 500 Ω (from system / release circuit)

VCBTC (LOW) 2 V (from system / release circuit)

RRmax Rmin+

2---------------------------------=

Rmax

VSt VBI min–

IBI (High)--------------------------------- RCBTC–=

Rmin RCBTC

VSt VCBTC (LOW)–

VCBTC (LOW)------------------------------------------------- ⋅=

PR I2

R⋅VSt

R RCBTC+----------------------------

2R⋅= =

Rmax110 V 19 V–

1.8 mA---------------------------------- 500 Ω– 50.1 kΩ= =

Rmin 500 Ω 110 V 2 V–2 V

------------------------------ ⋅ 27 kΩ= =

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The closest standard value of 39 kΩ is selected; the power is:

2.10.4.1 Setting for Trip Circuit Monitor

2.10.4.2 Information

2.10.5 Malfunction Responses of the Monitoring Functions

Depending on the type of malfunction discovered, an annunciation is sent, a restart ofthe processor system is initiated, or the device is taken out of service. after three un-successful restart attempts. The live status contact operates to indicate the device ismalfunctioning. Also, the red LED “ERROR” lights up on the front cover, if the internalauxiliary voltage is present, and the green “RUN” LED goes out. If the internal powersupply fails, then all LEDs are dark. Table 2-11 shows a summary of the monitoringfunctions and the malfunction responses of the relay.

RRmax Rmin+

2-------------------------------- 38.6 kΩ= =

PR110 V

39 kΩ 0.5 kΩ+----------------------------------------

239 kΩ⋅=

PR 0.3 W≥

Addr. Setting Title Setting Options Default Setting Comments

8201 FCT 74TC ONOFF

ON 74TC TRIP Circuit Supervision

F.No. Alarm Comments

06851 >BLOCK 74TC >BLOCK 74TC

06853 >74TC brk rel. >74TC Trip circuit superv.: bkr relay

06852 >74TC trip rel. >74TC Trip circuit superv.: trip relay

06861 74TC OFF 74TC Trip circuit supervision OFF

06862 74TC BLOCKED 74TC Trip circuit supervision is BLOCKED

06863 74TC ACTIVE 74TC Trip circuit supervision is ACTIVE

06864 74TC ProgFail 74TC blocked. Bin. input is not set

06865 FAIL: Trip cir. 74TC Failure Trip Circuit

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.

Table 2-11 Summary of the Device Malfunction Responses

Monitoring Possible Cause Malfunction Re-sponse

Message Output

AC/DC SupplyVoltage Loss

External (aux. Voltage)Internal (power supply)

Device shutdown All LEDs dark Live status contactde-energized

Internal SupplyVoltages

Internal (power supply)Ribbon cabledisconnected

Device shutdown LED “ERROR” Live status contact

de-energized2)

Battery Internal batterydischarged

Annunciation “Fail Battery”(FNo. 00177)

HardwareWatchdog

Internal (processorfailure)

Restart attempt 1) LED “ERROR” Live status contact

de-energized2)

SoftwareWatchdog

Internal(program sequence)

Restart attempt 1) LED “ERROR” Live status contact

de-energized2)

ROM Internal (Hardware) Restart attempt 1) LED “ERROR” Live status contact

de-energized2)

RAM Internal (Hardware) Detection duringboot sequence

LED blinksLive status contact

de-energized2)Detection duringoperation:

Restart attempt 1)

LED “ERROR

Settings Internal (Hardware) Restart attempt 1) LED “ERROR” Live status contact

de-energized2)

Analogue dataacquisition

Internal (Hardware) Device shutdown LED “ERROR” Live status contact

de-energized2)

CurrentSummation

CT Error) Message „Failure S I“(FNo. 00162)

as masked

CurrentSymmetry

CT Error Message „Fail I balance“(FNo. 00163)

as masked

VoltageSymmetry

VT Error Message „Fail Ph. Seq. V“(FNo. 00167)

as masked

1) After three unsuccessful restart attempts, the device will go out of service.2) Protection and control function are blocked, HMI might be still accessible.

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2.10.6 Group Alarms

Certain messages of the monitoring functions are already combined to group alarms.Table 2-12 shows an overview of these group alarms an their composition.

Voltage PhaseSequence

External (connections orpower system)

Message „Fail V balance“(FNo. 00176)

as masked

Current PhaseSequence

External (connections orpower system)

Message „Fail Ph. Seq. I“(FNo. 00175)

as masked

Fuse–Failure–Monitor

External (VTs, fuses, orcontrol cable)

Message „VT Fuse Failure“(FNo. 06575)

as masked

Trip CircuitMonitoring

External (open trip coil orblown fuses)

Message „FAIL: Trip cir.“(FNo. 06865)

as masked

Table 2-11 Summary of the Device Malfunction Responses

Monitoring Possible Cause Malfunction Re-sponse

Message Output

1) After three unsuccessful restart attempts, the device will go out of service.2) Protection and control function are blocked, HMI might be still accessible.

Table 2-12 Group alarms

Group alarm Composed ofFNo Designation FNo Designation

161 Fail I Superv. 01620163

Failure S IFail I balance

160 Alarm Sum Event 016201630167017501760171

Failure S IFail I balanceFail V balanceFail Ph. Seq. IFail Ph. Seq. VFail Ph. Seq.

140 Error Sum Alarm 01780183 .. 0189

01440145014601470177

I/O-BG gestörtStörung BG 1 .. 7Error 5VError 0VError -5VError PwrSupplyFail Battery

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2.11 Sensitive Ground Fault Detection (64, 50Ns, 67Ns)

General Sensitive ground fault detection may be used in isolated or compensated systems todetect ground faults. In solidly or low-resistance grounded systems, sensitive groundfault detection is used to detect high impedance ground faults.

For this protection function, the relay’s fourth current input must be equipped with asensitive input transformer (see Ordering Data in Annex A.1). Because of its high sen-sitivity, ground fault detection is not suited for detection of high magnitude groundfaults (over about 1.6 A at the sensitive ground fault detection relay terminals). Thedirectional and non-directional overcurrent protection functions are preferred for thisapplication (Sections 2.2 and ).

2.11.1 Description of Sensitive Ground Fault Detection

2.11.1.1 Voltage Element

The voltage element of sensitive ground fault detection relies on the zero sequence ordisplacement voltage V0 or 3V0. Additionally the faulty phase is determined. The dis-placement voltage V0 can be directly applied to the device, or the summary voltage3V0 can be calculated by the device based on the three phase-to-ground voltages. Inthe latter case, the three voltage inputs must be connected to voltage transformers ina grounded-wye configuration (see Subsection 2.1.3, address 0213 VT Connec-tion). If the device is only with phase-to-phase voltages, it is not possible to calculatea displacement voltage from them. In this case the direction cannot be determined.

If the displacement voltage is directly applied to the device, then V0 is the voltage atthe device terminals. It is not affected by the voltage adjustment factor set at address0206A Vph / Vdelta.

If the displacement voltage is calculated, then:

3V0 = Va + Vb + Vc

The displacement voltage is used both to detect a ground fault and to determine direc-tion, in accordance with Subsection 2.11.1.3. When the voltage element pickups, apreset time delay must elapse before detection of the displacement voltage is report-ed. This time delay is preset at the factory to 1 second and may be modified at address3111 T-DELAY Pickup. After the time delay set at address 3111 has elapsed, a sec-ond time interval may be started, after which the voltage element may initiate a trip sig-nal. This second time interval is set at address 3112 64-1 DELAY. It is important toreiterate that the total tripping time consists of the displacement voltage measurementtime (about 60 ms) plus the Pickup Time delay (set at address 3111) plus the trippingdelay (set at address 3112).

Determination ofthe GroundedPhase

After the voltage element pickups due to detection of a displacement voltage, thegrounded phase is identified, if possible. To do this, the individual phase-to-groundvoltages are measured. Of course, this is only possible if three phase-to-ground volt-ages are obtained from voltage transformers connected in a grounded-wye configura-tion. If the voltage magnitude for any given phase is below the setting value entered

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at address 3106 VPH MIN, that phase is detected as the grounded phase as long asthe voltage magnitudes of the other two phases are simultaneously above the settingvalue entered at address 3107 VPH MAX.

Figure 2-55 shows the logic for determining the grounded phase.

Figure 2-55 Detection of the grounded phase

2.11.1.2 Current Elements

The current elements associated with sensitive ground fault detection typically operatefor low magnitudes of zero sequence current. They are typically applied in systemswhere ground fault currents are limited by neutral resistors.

There are two current elements used for sensitive ground fault protection. A definitetime element similar to the 50N-2 or 67N-2 elements is used, as well as an elementthat may be operated with either a fixed time delay (similar to the 50N-1 and 67N-1elements) or with a user defined curve (similar to the 51N and 67N-TOC elements).Each of the elements may be directional or non-directional.

2.11.1.3 Determination of Direction

Curves When determining the sensitive ground fault direction it is not the current value that iscrucial but the part of the current which is perpendicular to a settable directional char-acteristic (axis of symmetry). As a prerequisite for determining the direction, the dis-placement voltage V0 must be exceeded as well as a configurable current part influ-encing the direction (active or reactive component).

Figure 2-56 illustrates the directional characteristic of the sensitive ground fault detec-tion function using a complex vector diagram in which the displacement voltage V0 isthe reference magnitude. Address 3125 is set to COS PHI, therefore, the current3I0real is calculated and compared with the value set at address 3123 RELEASE DIRECT.. The directional limit lines are perpendicular to 3I0real.

3106 VPH MIN

V>V<

Va

Vc

V<

V>&

V<

V>

V<

V>

&

&

Sens. Gnd Ph A

Sens. Gnd Ph B

Sens. Gnd Ph C

F# 01272

3107 VPH MAX

F# 01273

F# 01274

Ground fault

FromFigure2-59

Vb

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Figure 2-56 Directional Lines for cos-ϕ Measurement

The directional limit lines may be rotated by a correction angle set at address 3124PHI CORRECTION up to ±45°. Therefore, it is possible to increase sensitivity in theresistive-inductive range with a rotation of –45°, or in the resistive-capacitive rangewith a rotation of +45° (see Figure 2-57). If the sin-ϕ method is used, the directionallimit lines would be rotated by 90°.

If address 3124 PHI CORRECTION is set other than 0°, the angle of the directionallimit line is determined from the sum of the real and reactive components of zero se-quence power.

Figure 2-57 Directional Lines for cos-ϕ Measurement

Method ofDirectionalMeasurement

The calculation algorithm filters the measured values so that it is highly accurate andinsensitive to higher harmonics (particularly the 3rd and 5th harmonics – which are of-ten present in zero sequence currents).

Both the zero sequence or displacement voltage (V0 or 3V0) and the zero sequencecurrent (3I0) are used to determine direction to a fault or grounded connection. Beforethe determination of direction is initiated, the voltage element (and possibly the currentelement) must be picked up and a programmable component of 3I0 must exceed aprogrammable setting (address 3123 RELEASE DIRECT.). The programmable com-

M E S S A R T = C O S P H I

P H I K O R R E K T U R = 0 , 0 °

UE

IE E G E R . I E E

3I0 dir. = Value Set at Address 3123

TYPE OF MEASUREMENT = COS PHI

V0 3I0Real (resistive)

Forward

Reverse

3I0reactive (capacitive)

3I0dir 3I0

PHI CORRECTION = 0.0O

Setting

IEEw UE

IEEb (kapazitiv)

induktiv

MESSART = cos PHI

PHI KORREKTUR=+45,0°

IEE

GERIEE

IEEw UE

IEEb (kapazitiv) induktiv

MESSART = cos PHI

PHI KORREKTUR=-45,0°

IEE

G ERIEE

IEE GER = Einstellwert FREIGABE RICHT.

TYPE OF MEASUREMENT = COS PHI TYPE OF MEASUREMENT = COS PHI

PHI CORRECTION = +45.0° PHI CORRECTION = -45.0°

Forward

Reverse

Forward

Reverse

3I0real 3I0realV0 V0

3I0reactive (capacitive)

3I0reactive (capacitive)InductiveInductive

3I0dir

3I0

3I0dir

3I0

3I0 dir. = Value Set at Address 3123

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ponent of 3I0 compared to address 3123 depends on the setting at address 3125 MEAS. METHOD. Address 3125 establishes the directional measurement method thatwill be used.

If address 3125 is set to COS j, then the component of 3I0 that is in phase with thedisplacement voltage is compared to the setting at address 3123. This current is des-ignated 3I0real, and if larger than the setting at address 3123, directional determinationis initiated. Once directional determination is initiated, the current 3I0real and the dis-placement voltage V0 (or 3V0) are used to calculate the real component of the zerosequence power supplied to the fault. Both in a grounded system and in an unground-ed system, a ground fault actually supplies zero sequence real power to the rest of thesystem. Therefore, if the calculated zero sequence real power supplied to the fault isnegative (P0<0), the fault is considered in the direction of the protected equipment (for-ward direction). If the calculated zero sequence real power supplied to the fault is pos-itive (P0>0), then the fault is considered to be in the opposite direction (reverse direc-tion). This method is typically used to determine the direction of high impedance faultsin a grounded system.

If address 3125 is set to SIN j, then the component of 3I0 that is 90° out of phasewith the displacement voltage is compared to the setting at address 3123. This currentis designated 3I0 reactive, and if larger than the setting at address 3123, directional de-termination is initiated. Once directional determination is initiated, the current3I0reactive and the displacement voltage V0 (or 3V0) are used to calculate the reactivecomponent of the zero sequence power supplied to the fault. Both in a grounded sys-tem and in an ungrounded system, a ground fault actually supplies zero sequence re-active power to the rest of the system. Therefore, if the calculated zero sequence re-active power supplied to the fault is negative (Q0<0), the fault is considered in the di-rection of the protected equipment (forward direction). If the calculated zero sequencereactive power supplied to the fault is positive (Q0>0), then the fault is considered tobe in the opposite direction (reverse direction). This method it typically used to deter-mine the direction of ground connections in an ungrounded system.

ImplementationInstructions

In an ungrounded system, the reactive component of the current should be used todetermine the direction. In a grounded system, the real component of the currentshould be used to determine the direction. Therefore, in an ungrounded system, ad-dress 3125 should be set for SIN j measurement whereas in a grounded system,address 3125 should be set for COS j measurement.

Logic Figure 2-58 illustrates the condition logic for the sensitive ground fault pickup. Groundfault pickup may be switched ON or OFF, or into Alarm Only condition at address3101 Sens. Gnd Fault. When ground fault protection is ON, tripping is possible. Inmode Alarm Only ground faults are recorded in a separate log file for ground faults.The pickup of the displacement voltage V0 starts the ground fault recording. As thepickup of the V0 stage drops out, fault recording is terminated.

The entire function may be blocked via a binary input. Switching off or blocking meansthe measurement logic (shown in Figure 2-59) is deactivated, therefore, time delaysand messages are reset.

All stages can be blocked individually via binary inputs. In this case pickups as well asdirection and grounded phase will still be reported, however, tripping does not takeplace since the time stages are blocked.

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Figure 2-58 Activation of Sensitive Ground Fault Detection

Generation of a tripping message, for both current elements, is dependent on the di-rection selection for each element. If the element is set to non-directional and pa-rameter PU CRITERIA = Vgnd OR INs, a pickup message is generated as soon asthe current threshold is exceeded, irrespective of the status of the V0 stage. If, howev-er, the setting of parameter PU CRITERIA is Vgnd AND INs, the V0 stage must havepicked up also for non-directional mode.

But, if a direction is programmed, the current element must be picked up and the di-rection determination results must be present to generate a message. Once again, acondition for valid direction determination is that the voltage element be picked up aswell.

Based on the setting at address 3130 PU CRITERIA, the generation of a fault condi-tion message can be dependent on either the pickup of both the voltage and currentelements (AND function), or a pickup of at least one of those two elements (OR func-tion). The former may be advantageous if the pickup setting of the voltage elementwas chosen to be very low.

or

„1“

50Ns/67Ns OFF

>BLK 50Ns/67Ns Sens. Gnd block

& 50Ns/67Ns ACT

Reset Measurement Logic

Alarm Onlyto Figure2-59

F# 01230

3101 Sens. Gnd Fault

F# 01207

F# 01211

F# 01212

Alarm OnlyONOFF

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Figure 2-59 Logic Diagram for Sensitive Ground Fault Detection

2.11.1.4 Location of Ground Connections

ApplicationExample

Directional determination may often be used to locate a grounded connection. In radialsystems, locating the ground connection is relatively simple. Since all feeders from a

0131 Sens. Gnd Fault

SensGnd Forward

SensGnd Reverse

>BLOCK 64

„1“

T 0V0 64 Pickup&

&T 0

64 TRIP„1“

INS

DirectionDetermination

T 0

&T 0

50Ns-2 TRIP

&T 0

50Ns-1 TRIP

& 51Ns TRIP

SensGnd undef.

50Ns-2

50Ns-1

or=

=or

or

&

&

&

50Ns-1 Pickup

50Ns-2 Pickup

51Ns Pickup

&

&

&

>BLOCK 50Ns-2

>BLOCK 50Ns-1

>BLOCK 51Ns

Alarm Only

Reset Measuring Device

Measurement Logic

50Ns-1

51Ns

or

50Ns-2

FromFigure2-58

3130 PU CRITERIA

3111 T-DELAY Pickup

3115 67Ns-2 DIRECT.3112 64-1 DELAY

3126 RESET DELAY

3122 67Ns-1 DIRECT.

3114 50Ns-2 DELAY

3118 50Ns-1 DELAY

3120 51Ns TIME DIAL

F# 01215

F# 01217

F# 01276

F# 01277

F# 01278

F# 01221

F# 01223

F# 01224

F# 01226

F# 01227

F# 01229

F# 01201

F# 01202

F# 01203

F# 01204

Vgnd OR INsVgnd AND INs

Non-Directional

Forward/ Reverse

„1“ Non-Directional

Forward/ Reverse

Definite Time

User Defined PU

V0-Element

V0>

Ground faultTo Figure2-55

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common bus (Figure 2-60) deliver a capacitive charging current, practically the sameground connection current is available at the relay location of a faulted feeder in anungrounded system. In a looped system, the relay locations of the faulted line receivethe maximum ground connection current. “Forward” is reported at both ends only forthe faulted line (Figure 2-61), However, the other directional indicators in the systemmay also be of help, if not missing due to insufficient ground current.

Figure 2-60 Location of a Ground Fault in a Radial System

Figure 2-61 Location of Ground Connection based on Direction Indicators in a Looped Sys-tem

2.11.2 Programming Settings

2.11.2.1 General Settings

During configuration of protective functions, address 0131 Sens. Gnd Faultshould be set to Definite Time if the inverse characteristic is not required, User Defined PU if both a definite time and inverse time characteristic are required, andDisabled if the function is not required at all.

Also, during configuration, address 0213 VT Connection determines how the volt-age transformers are connected (phase-to-ground or phase-to-phase), and addresses

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0206A Vph / Vdelta, 0217 and 0218 (primary and secondary rated transformercurrent in the ground path) must be set correctly.

Sensitive ground fault detection may be switched ON, OFF, or to Alarm Only, at ad-dress 3101 Sens. Gnd Fault. If sensitive ground fault protection is switched ON,both tripping and message reporting is possible.

The ground fault is detected and reported only when the displacement voltage has ap-plied for at least the time T-DELAY Pickup (address 3111).

Address 3130 PU CRITERIA specifies whether ground fault detection is enabled onlyfor pickups of V0 and INs (Vgnd AND INs) or as soon as one of the two have pickedup (Vgnd OR INs).

Current Elements,General

The two time-overcurrent elements are set at addresses 3113 through 3120. Each ofthese elements may be directional or non-directional. These elements operate fromthe zero sequence current. They typically operate, therefore, only in grounded sys-tems (solid or low resistance), or for motors connected to an ungrounded bus wherethe entire system capacitance supplies zero sequence current to the motor groundconnection, but the ground current in the ground connection is insignificant becauseof the low motor capacitance.

2.11.2.2 Definite Current Stage (50Ns-2, 50Ns-1)

50Ns–2 Element The 50Ns-2 element pickup and delay settings are entered at addresses 3113 50Ns-2 PICKUP and 3114 50Ns-2 DELAY respectively. Pickup and time out of the 50Ns-2 element can result just in the generation of a message, or in both the generation ofa message and tripping. The latter is only possible if address 3101 is set to ON.

50Ns-1 / 51NsElement

If configured as Definite Time at address 0131, the 50Ns-1 element will be en-abled. The pickup and delay settings for the 50Ns-1 element are at addresses 311750Ns-1 PICKUP and 3118 50Ns-1 DELAY respectively.

2.11.2.3 Inverse Current Stage (51Ns)

51Ns Element The inverse tripping characteristic 51Ns is mainly determined by addresses 3119 and3120 (address 0131 Sens. Gnd Fault = User Defined PU).

User DefinedCurve

If a user defined curve is configured at address 0131, it should be noted that the de-vice will not necessarily pickup until the current exceeds 110 % of the pickup value, asis standard for inverse curves.

Entry of the value pair (current and time) is a multiple of the settings at addresses3119 51Ns PICKUP and 3120 51Ns TIME DIAL. Therefore, it is recommended thataddresses be initially set to 1.00 for simplicity. Once the curve has been entered, thesettings at addresses 3119 and 3120 can be modified if desired.

As delivered, The default settings for all current values is ∞. They are, therefore, notenabled — and no pickup or tripping of these protective functions will occur.

Up to 20 pairs of values (current and time) may be entered at address 3131 M.of PU TD. The device then approximates the curve, using linear interpolation.

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The following must be observed:

− The value pairs should be entered in increasing sequence. If desired, fewer than 20pairs may be entered. In most cases, about 10 pairs is sufficient to define the curveaccurately. Each unused pair must then be marked as unused by entering “∞” asthe limit value. The user must ensure the value pairs produce a clear and constantcurve.

− The current values entered should be those from Table 2-13, along with the match-ing times. Other values for MofPU are changed to the nearest adjacent value al-though this is not indicated.

− Current flows less than the smallest current value entered will not lead to an exten-sion of the tripping time. The pickup curve (see Figure 2-62) continues, from thesmallest current point parallel to the current axis.

− Current flows greater than the highest current value entered will not lead to an ab-breviation of the tripping time. The pickup curve (see Figure 2-62) continues, fromthe largest current point parallel to the current axis.

Figure 2-62 Use of a User Defined Curve

Table 2-13 Preferential Values of Standardized Currents for User Specific Tripping Characteristics

MofPU = 1 to 1.94 MofPU = 2 to 4.75 MofPU = 5 to 7.75 MofPU = 8 to 20

1.00 1.50 2.00 3.50 5.00 6.50 8.00 15.00

1.06 1.56 2.25 3.75 5.25 6.75 9.00 16.00

1.13 1.63 2.50 4.00 5.50 7.00 10.00 17.00

1.19 1.69 2.75 4.25 5.75 7.25 11.00 18.00

1.25 1.75 3.00 4.50 6.00 7.50 12.00 19.00

1.31 1.81 3.25 4.75 6.25 7.75 13.00 20.00

1.38 1.88 14.00

1.44 1.94

Smallest Current Point

Largest Current Point

Pickup CurveT/Tp

I/Ip1 1.1 20

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2.11.2.4 Phase-to-Ground Voltage

Determination ofthe Phase with aGroundConnection

The phase connected to ground may be identified in an ungrounded system, if the de-vice is supplied by three voltage transformers connected in a grounded-wye configu-ration. The phase whose voltage lies below the minimum voltage setting at address3106 VPH MIN is identified as the phase connected to ground as long as the othertwo phase voltages simultaneously exceed the maximum voltage setting at address3107 VPH MAX. The setting at address 3106 must be set less than the minimum al-lowable phase-to-ground voltage. A typical setting for this address would be 40 V. Themaximum voltage setting at address 3107 must be greater than the minimum allow-able phase-to-ground voltage, but less than the minimum phase-to-phase voltage. ForVN = 100 V, approximately 75 V is a typical setting. These settings have no signifi-cance in a grounded system.

Displacement Volt-age V0 or 3V0

The pickup due to displacement voltage is set at address 3109 64-1 VGND if V0 ismeasured or address 3110 64-1 VGND if 3V0 is calculated. Pickup of the voltage el-ement is a condition for initiation of directional determination. Depending on the settingat 0213 VT Connection, only the applicable limit value at address 3109 or 3110 isaccessible. That is, if two phase-to-phase voltages and the displacement voltage V0are supplied to the device, the measured displacement voltage is used directly forground fault recognition. The limit value for V0 is programmed at address 3109, wherea more sensitive setting can be made. If three phase-to-ground voltages are connect-ed to the device, the displacement voltage 3V0 is calculated from the three phase-to-ground voltages, and address 3110 is where the voltage element pickup is set. Theground connection is first detected and reported when the displacement voltage hasexisted for the entire time delay set at address 3111 T-DELAY Pickup.

With regard to an ungrounded system, nearly the entire displacement voltage appearsat the device terminals, therefore the pickup setting is not critical, and typically lies be-tween 30 V and 60 V (address 3109) or 50 V and 100 V (address 3110). Large faultresistances may require higher sensitivity (i.e. a lower pickup setting).With regard to a grounded system, a more sensitive (lower) pickup value may be set,but it must be above the maximum anticipated displacement voltage during normal(unbalanced) system operation.

Trip Time Delay Pickup of just the voltage element may initiate time delayed tripping depending on thesetting at address 3130 PU CRITERIA (address 3101 Sens. Gnd Fault = ON) andmoreover address 3130 PU CRITERIA is configured Vgnd OR INs. The trippingdelay is then set at address 3112 64-1 DELAY. It is important to note that the totaltripping time consists of the displacement voltage measurement time (about 50 ms)plus the pickup time delay (address 3111) plus the tripping time delay (address 3112).

2.11.2.5 Direction

DirectionalCharacteristic

Addresses 3115 to 3126 are for direction determination.

The direction the definite high-set stage 67Ns-2 may be set at address 3115 67Ns-2 DIRECT. as Forward, Reverse or Non-Directional.

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The direction of the definite high-set stage 67Ns-1 or of the inverse characteristic maybe set at address 3122 67Ns-1 DIRECT. as Forward, Reverse or Non-Direc-tional.

The current setting at address 3123 RELEASE DIRECT. supervises the initiation ofdirectional determination, and is based on the current components which are perpen-dicular to the directional limit lines. The position of the directional limit lines themselvesare based on the settings entered at address 3124 PHI CORRECTION and 3125MEAS. METHOD.

When address 3124 PHI CORRECTION is set to 0.0°, the following apply to address3125:

− Address 3125 = COS j: the real component of the zero sequence current with re-spect to the displacement voltage (the component of 3I0 in phase with V0 or 3V0) isevaluated by the setting at address 3123 (see Figure 2-56);

− Address 3125 = SIN j: the reactive (capacitive) component of the zero sequencecurrent with respect to the displacement voltage (the component of 3I0 that leadsV0 or 3V0 by 90°) is evaluated by the setting at address 3123 (see Figure 2-63).

Figure 2-63 Directional Line for sin ϕ Measurement

− The directional line, in this respect, may be rotated within the range ±45° — asshown in Figure 2-57.

UngroundedSystem

In an ungrounded system, no zero sequence fault current exists, therefore, the zerosequence charging current must be used for directional determination. As is the casewith the zero sequence fault current, the zero sequence charging current will also leadthe zero sequence voltage for a fault in the forward direction. A setting equal to abouthalf of this current should be selected at address 3123. The measurement time se-lected at address 3125 should be SIN j.

3I0dir

Inductive

Reverse

3I0

Forward

3I0real V0

3I0reactive

TYPE OF MEASUREMENT = SIN PHI

PHI CORRECTION = 0,0°

3I0dir=Set at Addr.3123

(capacitive)

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Grounded System In a grounded system, address 3123 should be set below the minimum anticipatedground fault current. It is important to note that only the current components that areperpendicular to the directional limit lines defined at addresses 3124 and 3125 will beevaluated. COS j is the type of measurement used, and the correction angle is set to–45°, since the ground fault current is typically resistive-inductive (right portion of Fig-ure 2-57).

Electrical Motors One may set the value COS j for the measurement type and use a correction angleof +45° for electrical motors supplied from a common bus in an ungrounded system,since the ground connection current is often composed of an overlap of the capacitiveground current from the system and the resistive current of the load resistance (Figure2-57, left section).

General The following is valid for determination of direction during ground faults: The minimumcurrent for directional determination entered at address 3123 RELEASE DIRECT. must be set as high as possible so as not to be a false limit of the device during theflow of asymmetrical currents in the system.

If direction determination is used in conjunction with one of the current elements dis-cussed above (50Ns-1 PICKUP or 51Ns PICKUP), a value for address 3123 is onlysignificant if it is less than or equal to the current element pickup value.

A corresponding message (reverse, forward, or undefined) is issued upon directiondetermination. To avoid chatter for this message resulting from sharply-varying groundconnection currents, a dropout delay RESET DELAY, entered at address 3126, is ini-tiated when directional determination drops out, and the message is held for this peri-od of time.

2.11.2.6 Current Transformer

Angular ErrorCompensation

Addresses 3102 through 3105 only apply to compensated systems which utilize Pe-tersen coils. Since the utilization of compensated systems is primarily limited to Euro-pean practices, a detailed explanation of these settings is beyond the scope of thisparticular instruction manual. In the rare event that this protective relay is utilized in acompensated system, the reader should contact Siemens Power T&D for more infor-mation regarding application of the 7SJ62/63/64 relay in a compensated system.

2.11.2.7 Settings for Sensitive Ground Fault Detection

The current-based setting ranges and Default Setting values are independent of thenominal current rating of the device. The sensitive ground fault detection measuresthe current at a special, sensitive input. In general, current-based settings can be en-tered in primary terms with consideration given to the ratio of the applicable currenttransformer. However, problems related to the resolution of the pickup currents canoccur when very small settings and small primary currents are involved. The user istherefore encouraged to enter settings for the sensitive ground fault detection in sec-ondary terms.

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Sensitive Ground Fault Detection (64, 50Ns, 67Ns)

Addr. Setting Title Setting Options Default Setting Comments

3101 Sens. Gnd Fault OFFONAlarm Only

OFF Sensitive Ground Fault

3111 T-DELAY Pickup 0.04..320.00 sec; ∞ 1.00 sec Time-DELAY Pickup

3130 PU CRITERIA Vgnd OR INsVgnd AND INs

Vgnd OR INs Sensitive Ground Fault PICKUPcriteria

3113 50Ns-2 PICKUP 0.001..1.500 A 0.300 A 50Ns-2 Pickup, sensitive

0.05..35.00 A 10.00 A 50Ns-2 Pickup, IEN = 1 A

0.25..175.00 A 50.00 A 50Ns-2 Pickup, IEN = 5 A

3114 50Ns-2 DELAY 0.00..320.00 sec; ∞ 1.00 sec 50Ns-2 Time Delay

3117 50Ns-1 PICKUP 0.001..1.500 A 0.100 A 50Ns-1 Pickup, sensitive

0.05..35.00 A 2.00 A 50Ns-1 Pickup, IEN = 1 A

0.25..175.00 A 10.00 50Ns-1 Pickup, IEN = 5 A

3118 50Ns-1 DELAY 0.00..320.00 sec; ∞ 2.00 sec 50Ns-1 Time delay

3119 51Ns PICKUP 0.001..1.400 A 0.100 A 51Ns Pickup, sensitive

0.05..4.00 A 1.00 A 51Ns Pickup, IEN = 1 A

0.25..20.00 A 5.00 A 51Ns Pickup, IEN = 5 A

3120 51Ns TIME DIAL 0.10..4.00 sec; ∞ 1.00 sec 51Ns Time Dial

3131 M.of PU TD 1.00..20.00 Multiple ofPikkup; ∞0.01..999.00 Time Dial

Multiples of PU Time-Dial

3106 VPH MIN 10..100 V 40 V L-Gnd Voltage of Faulted PhaseVph Min

3107 VPH MAX 10..100 V 75 V L-Gnd Voltage of UnfaultedPhase Vph Max

3109 64-1 VGND 1.8..130.0 V 40.0 V 64-1 Ground Displacement Volt-age

3110 64-1 VGND 10.0..225.0 V 70.0 V 64-1 Ground Displacement Volt-age

3112 64-1 DELAY 0.10..40000.00 sec; ∞ 10.00 sec 64-1 Time Delay

3115 67Ns-2 DIRECT. ForwardReverseNon-Directional

Forward 67Ns-2 Direction

3122 67Ns-1 DIRECT. ForwardReverseNon-Directional

Forward 67Ns-1 Direction

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2.11.2.8 Information List for Sensitive Ground Fault Detection

3123 RELEASE DIRECT. 0.001..1.200 A 0.010 A Release directional element ,sensitive

0.05..30.00 A 0.50 A Release directional element,IEN = 1 A

0.25..150.00 A 2.50 A Release directional element,IEN = 5 A

3124 PHI CORRECTION -45.0..45.0 ° 0.0 ° Correction Angle for Dir. Determi-nation

3125 MEAS. METHOD COS PhiSIN phi

COS Phi Measurement method for Direc-tion

3126 RESET DELAY 0..60 sec 1 sec Reset Delay

3102 CT Err. I1 0.001..1.600 A 0.050 A Current I1 for CT Angle Error,sensitive

0.05..35.00 A 1.00 A Current I1 for CT Angle Error,IEN = 1 A

0.25..175.00 A 5.00 A Current I1 for CT Angle Error,IEN = 5 A

3103 CT Err. F1 0.0..5.0 ° 0.0 ° CT Angle Error at I1

3104 CT Err. I2 0.001..1.600 A 1.000 A Current I2 for CT Angle Error,sensitive

0.05..35.00 A 10.00 A Current I2 for CT Angle Error,IEN = 1 A

0.25..175.00 A 50.00 A Current I2 for CT Angle Error,IEN = 5 A

3105 CT Err. F2 0.0..5.0 ° 0.0 ° CT Angle Error at I2

Addr. Setting Title Setting Options Default Setting Comments

F.No. Alarm Comments

01201 >BLOCK 64 >BLOCK 64

01202 >BLOCK 50Ns-2 >BLOCK 50Ns-2

01203 >BLOCK 50Ns-1 >BLOCK 50Ns-1

01204 >BLOCK 51Ns >BLOCK 51Ns

01207 >BLK 50Ns/67Ns >BLOCK 50Ns/67Ns

01211 50Ns/67Ns OFF 50Ns/67Ns is OFF

01212 50Ns/67Ns ACT 50Ns/67Ns is ACTIVE

01215 64 Pickup 64 displacement voltage pick up

01217 64 TRIP 64 displacement voltage element TRIP

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01221 50Ns-2 Pickup 50Ns-2 Pickup

01223 50Ns-2 TRIP 50Ns-2 TRIP

01224 50Ns-1 Pickup 50Ns-1 Pickup

01226 50Ns-1 TRIP 50Ns-1 TRIP

01227 51Ns Pickup 51Ns picked up

01229 51Ns TRIP 51Ns TRIP

01230 Sens. Gnd block Sensitive ground fault detection BLOCKED

01272 Sens. Gnd Ph A Sensitive Ground fault picked up in Ph A

01273 Sens. Gnd Ph B Sensitive Ground fault picked up in Ph B

01274 Sens. Gnd Ph C Sensitive Ground fault picked up in Ph C

01276 SensGnd Forward Sensitive Gnd fault in forward direction

01277 SensGnd Reverse Sensitive Gnd fault in reverse direction

01278 SensGnd undef. Sensitive Gnd fault direction undefined

F.No. Alarm Comments

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2.12 Intermittent Ground Fault Protection

General Intermittent ground faults can occur in cables due to poor insulation or water ingressin cable joints. Often such faults disappear automatically to strike again after sometime. They can last between a few milliseconds and several seconds. This is why suchfaults are not detected at all or not selectively by the ordinary time overcurrent protec-tion. If pulse durations are extremely short, not all protection devices in a short-circuitpath may pick up; selective tripping is thus not ensured.

Due to the time delay of the overcurrent protection function such faults are too shortto initiate shutdown of the faulted cable. Only when they have become permanent cansuch ground faults be removed selectively by the short-circuit protection.

But such intermittent ground faults already bear the risk of causing thermal damage toequipment. This is why the 7SJ62/63/64 device features a protective function that isable to detect such intermittent ground faults and accumulates their duration. If withina certain time their sum reaches a configurable value, the thermal load capacity hasbeen achieved. If the ground faults are distributed over a long period of time or if theground fault goes off and does not re-ignite after some time, the eqiupment under loadis expected to cool down. Tripping is not necessary in this case.

2.12.1 Functional Description

The intermittent ground fault can either be detected via the ground current input I4 (INor INs) or it is calculated from the sum of the three phase currents (3I0). Unlike theovercurrent protection which uses the fundamental wave, the intermittent ground faultprotection creates the r.m.s. value of this current and compares it to a configurablethreshold Iie>. This method accounts for high harmonic contents (up to 400 Hz) andfor the direct component since both factors contribute to the thermal load. Exceedingthe threshold value Iie> initiates a pickup message (“IIE Fault det“, see Figure2-64). The pickups are also counted; as soon as the counter content has reached thevalue of parameter Nos.det., the message “Intermitt.EF“ is issued. A stabilizedpickup is obtained by prolonging the pickup message “IIE Fault det“ by a settabletime T-det.ext. This stabilization is especially important for coordination with exist-ing static or electromechanical relays.

The duration of the stabilized pickups “IIE stab.Flt“ is summed up in an integratorT-sum det. If the accumulated pickup time reaches a configurable threshold value,a corresponding message is generated (“IEF Tsum exp.“) and tripping takes place,however, only while a ground fault is present (message “IEF Trip“). The trip com-mand is maintaned during the entire minimum tripping time specified for the device,even if the ground fault is of short duration. After completion of the tripping commandall memories are reset and the protection resumes normal condition.

The (much longer) resetting time T-reset (message “IEF Tres run.“) is launchedsimultaneously with T-sum det. when a ground fault occurs. Unlike T-sum det.each new ground fault resets this time to its initial value and it expires anew. If T-re-set expires and no new ground fault is recorded during that time, all memories arereset and the protection resumes normal position. T-reset thus determines the timeduring which the next ground fault must occur to be processed yet as intermittentground fault in connection with the previous fault. A ground fault that occurs later willbe considered a new fault event.

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Intermittent Ground Fault Protection

The message “IIE Fault det“ will be entered in the fault log and reported to thesystem interface only until the message “Intermitt.EF“ is issued. This prevents aburst of messages. If the message is allocated to an LED or a relay, this limitation doesnot apply. This is accomplished by doubling the message (message numbers 06924,06926).

Interaction withAutomaticReclosure

Automatic reclosure is not an effective measure against intermittent ground faults asthe function only trips after repeated detection of a fault or after expiration of the sum-mation monitoring time T-sum det. and besides its basic design is to prevent ther-mal overload. For these reasons the intermittent ground fault protection is not imple-mented as starting feature of the automatic reclosing function.

Interaction withBreaker FailureProtection

A pickup that is present when the time delay TRIP-Timer has expired is interpretedby the breaker failure protection as a criterion for a tripping failure. Since permanentpickup is not ensured after a tripping command of the intermittent ground fault protec-tion, cooperation with the breaker failure protection is not reasonable. Therefore, thisfunction is not activated by the intermittent ground fault protection.

Logic Diagram Figure 2-64 shows the logic diagram of the intermittent ground fault protection.

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Figure 2-64 Logic diagram of the protection for intermittent ground fault – Principle

Fault Logging A fault event and thus fault logging is initated when the Interm. E/F detection stage Iie>first picks up. The message “IIE Fault det“ is issued and entered in the fault log(and reported to the system interface) so often until the number of pickups “IIE Fault det“ has reached the value set for parameter “Nos.det.“. When this hap-pens, the message “Intermitt.EF“ is issued and “IIE Fault det“ is blocked forthe fault log and the system interface. This method accounts for the fact that the In-term. E/F detection stage Iie> may also pick up for a normal short-circuit. In this casethe pickup does not launch the alarm “Intermitt.EF“.

Intermittent ground faults may cause other time overcurrent stages to pick up (e.g. 50-1, 50N-1, 50Ns-1) and produce a burst of messages. To avoid overflow of the fault logsuch messages are not entered anymore in the fault log after detection of an intermit-

>IEF blockFNo. 06903 FNo. 06922

IEF blocked

FNo. 06923IEF enabled

FNo. 06921IEF OFF

3302 Iie>

IEF TRIP

3303 T-det.ext.

&

3306 Nos.det.

&

FNo. 06932Nos.IIE=

FNo. 06926IIE Fault det

FNo. 06927Intermitt.EF

orFNo. 06924IIE Fault det

FNo. 06925IIE stab.Flt

3304 T-sum det.3305 T-reset

Gen.Trip

IEF Trip

&

&

FNo. 06928IEF Tsum exp.

FNo. 06930IEF Trip

IEF Trip

Gen. Trip0210A TMin TRIP CMD

FNo. 06929IEF Tres run.

resS

R

Counterreset

count

res

ab a ≤ b

FNo. 06931Iie/In=

(for log)

(for LED/Relays)

or

Reset Counter

or

Integrator

Reset Counter

OFF„1“

or or

ON

3301 INTERM.EF

Measurement / Logic

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Intermittent Ground Fault Protection

tent ground fault (message ”Intermitt.EF”) unless they cause a tripping command.If an intermittent ground fault has been detected, the following pickup messages of thetime overcurrent protection will still be reported without restraint (see table 2-14):

Table 2-15 shows all messages subject to a restraint mechanism avoiding a messageburst during an intermittent ground fault:

Table 2-14 Unrestricted messages

FNo. Function Description

01800 50-2 picked up 50-2 picked up

02642 67-2 picked up 67-2 picked up

07551 50-1 InRushPU 50-1 InRush picked up

07552 50N-1 InRushPU 50N-1 InRush picked up

07553 51 InRushPU 51 InRush picked up

07554 51N InRushPU 51N InRush picked up

07559 67-1 InRushPU 67-1 InRush picked up

07560 67N-1 InRushPU 67N-1 InRush picked up

07561 67-TOC InRushPU 67-TOC InRush picked up

07562 67N-TOCInRushPU 67N-TOC InRush picked up

07565 Ia InRush PU Phase A InRush picked up

07566 Ib InRush PU Phase B InRush picked up

07567 Ic InRush PU Phase C InRush picked up

07564 Gnd InRush PU Ground InRush picked up

Table 2-15 Buffered messages

FNo. Function Description

01761 50(N)/51(N) PU 50(N)/51(N) O/C PICKUP

01762 50/51 Ph A PU 50/51 Phase A picked up

01763 50/51 Ph B PU 50/51 Phase B picked up

01764 50/51 Ph C PU 50/51 Phase C picked up

01810 50-1 picked up 50-1 picked up

01820 51 picked up 51 picked up

01765 50N/51NPickedup 50N/51N picked up

01831 50N-2 picked up 50N-2 picked up

01834 50N-1 picked up 50N-1 picked up

01837 51N picked up 51N picked up

02691 67/67N pickedup 67/67N picked up

02660 67-1 picked up 67-1 picked up

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Before they are entered in the fault log (event buffer) and transmitted to the systeminterface or CFC, the messages of table 2-15 are buffered (starting with the first pickupmessage received after “Intermitt.EF” was signalled). The buffering does not ap-ply for signalling to relays and LEDs as it is required by time-graded protection sys-tems for reverse interlocking. The intermediate buffer can store a maxium of two sta-tus changes (the most recent ones) for each message.

Buffered messages are signalled to the fault log, CFC and to the system interface withthe original time flag only when a TRIP command is initiated by a protective functionother than the intermittent ground fault protection. This ascertains that a pickup, al-though delayed, is always signalled in association with each TRIP command.

All pickup messages which usually do not occur during an intermittent ground fault arenot affected by this mechanism. Among others this includes the pickup and TRIP com-mands of the following protective functions:

• Breaker failure protection,

• Overload protection,

• Frequency protection and

• Voltage protection.

The pickup signals of these functions will still be logged immediately. A TRIP com-mand of one of these protective functions will cause the buffered messages to becleared since no connection exists between tripping function and buffered message.

A fault event is cleared when the time T-reset has expired or the TRIP command“IEF Trip“ has been terminated.

02670 67-TOC pickedup 67-TOC picked up

02692 67 A picked up 67/67-TOC Phase A picked up

02693 67 B picked up 67/67-TOC Phase B picked up

02694 67 C picked up 67/67-TOC Phase C picked up

02646 67N-2 picked up 67N-2 picked up

02681 67N-1 picked up 67N-1 picked up

02684 67N-TOCPickedup 67N-TOC picked up

02695 67N picked up 67N/67N-TOC picked up

05159 46-2 picked up 46-2 picked up

05165 46-1 picked up 46-1 picked up

05166 46-TOC pickedup 46-TOC picked up

01215 64 Pickup 64 displacement voltage pick up

01221 50Ns-2 Pickup 50Ns-2 Pickup

01224 50Ns-1 Pickup 50Ns-1 Pickup

01227 51Ns Pickup 51Ns picked up

06823 START-SUP pu Startup supervision Pickup

Table 2-15 Buffered messages

FNo. Function Description

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Intermittent Ground Fault Protection

Terminating a fault event for the intermittent ground fault protection thus is a specialcase since it is the time T-reset that keeps the fault event opened and not the pick-up.

2.12.2 Functional Settings

General Protection against intermittent ground faults can only take effect and is only accessibleif the current to be evaluated (with Ignd, with 3I0 or with Ignd,sens.) wasconfigured in address 0133 INTERM.EF. If the function is not needed, it is set to Dis-abled.

In address 3301 INTERM.EF you can switch the function to ON or OFF.

The pickup threshold (r.m.s. value) is set in address 3302 Iie>. A rather sensitivesetting is possible to respond also to short ground faults since the pickup time shortensas the excess current increases. The setting range depends on the selection of thecurrent to be evaluated at address 0133 INTERM.EF.

The pickup time can be prolonged at address 3303 T-det.ext.. This pickup stabi-lization is especially important for the coordination with existing analog or electrome-chanical overcurrent relays. The time T-det.ext. can also be disabled (T-det.ext. = 0).

The stabilized pickup starts the counter Tsum. This counter is stopped but not reset asthe picked up function drops out. Basing on the last counter content the counter re-sumes metering when the stabilized function picks up next. This sum of individualpickup times, which are to initiate tripping, is set at address 3304 T-sum det. Itserves as selectivity criterion for coordinating the relays of one busbar run and is com-parable to the time grading of the time overcurrent protection. The relay in the radialnetwork which is closest to the intermittent fault and picks up, is set to the shortestsummation time T-sum det. (see Figure 2-65).

Figure 2-65 Example of the setting of the time stage T-sum det.

The reset time T-reset, after which the summation is reset in healthy operation andthe protection resumes normal status, is configured at address 3305.

Address 3306 Nos.det. specifies the number of pickups after which a ground faultis considered intermittent.

7SJ511 7SJ511 7SJ511

1.5s 1.0s 0.5s

Pick up Pick up No Pick up

IN

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2.12.2.1 Settings of the Intermittent Ground Fault Protection

2.12.2.2 Information List of the Intermittent Ground Fault Protection

Addr. Setting Title Setting Options Default Setting Comments

3301 INTERM.EF OFFON

OFF Intermittent earth fault protection

3302 Iie> 0.05..35.00 A 1.00 A Pick-up value of interm. E/F stage,IN measured

0.05..35.00 A 1.00 A Pick-up value of interm. E/F stage,3I0 calculated

0.050..1.500 A 1.000 A Pick-up value of interm. E/F stage,INs measured

3303 T-det.ext. 0.00..10.00 sec 0.10 sec Detection extension time

3304 T-sum det. 0.00..100.00 sec 20.00 sec Sum of detection times

3305 T-reset 1..600 sec 300 sec Reset time

3306 Nos.det. 2..10 3 No. of det. for start of int. E/F prot

F.No. Alarm Comments

06903 >IEF block >block interm. E/F prot.

06923 IEF enabled Interm. E/F prot. is active

06921 IEF OFF Interm. E/F prot. is switched off

06922 IEF blocked Interm. E/F prot. is blocked

06924 IIE Fault det Interm. E/F detection stage Iie>

06926 IIE Fault det Interm. E/F detection stage Iie>

06925 IIE stab.Flt Interm. E/F stab detection

06927 Intermitt.EF Interm. E/F detected

06930 IEF Trip Interm. E/F: trip

06928 IEF Tsum exp. Counter of det. times elapsed

06929 IEF Tres run. Interm. E/F: reset time running

06932 Nos.IIE= No. of detections by stage Iie>=

06931 Iie/In= Max RMS current value of fault =

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Automatic Reclosing System (79M)

2.13 Automatic Reclosing System (79M)

2.13.1 Description of Automatic Reclosing System

2.13.1.1 General

From experience, the majority of faults associated with overhead distribution feedersare temporary in nature. Therefore, to maximize service availability, it is desirable toemploy a system that will close the circuit breaker shortly after it is tripped. This is ac-complished in the 7SJ62/63/64 relay via the automatic reclosing system.

When using the automatic reclosing system, if the fault still exists after the circuitbreaker has been reclosed, then the protective elements will re-trip the circuit breaker.Depending on the number of reclosing attempts programmed for the automatic reclos-ing system (up to nine are possible), the circuit breaker will either be reclosed again,or will remain open.

The automatic reclosure system can also operate in interaction with the integratedsynchronizing function or with an external synchrocheck.

Figure 2-66 shows an example of a timing diagram for a successful second reclosure.

Figure 2-66 Timing Diagram for a Second Successful Reclosure

T-Action

T AUS-SVS

Dead Time 1 Dead Time 2

Tmax Close CMD.

Reset Time

Pick up

TripCommand

Breaker

Dead Time

RecloseCommand

Reset Time

79 i. progress

79 1st cycle

79 2nd cycle

Starting cycle Cycle 1 Cycle 2

1st cycle finished

T-Action

Reclosing

Status 52-a

closedopen

Successful

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Figure 2-67 shows an example of a timing diagram for two unsuccessful reclosingshots, with no additional reclosing of the circuit breaker.

Figure 2-67 Timing Diagram showing Two Unsuccessful Reclosing Shots (no additional reclosing of the circuit breaker)

The automatic reclosing function can also be initiated by an external protection relay.For this application, an output contact from the tripping relay must be wired to a binaryinput of the 7SJ62/63/64 relay. It is also possible to allow the 7SJ62/63/64 relay towork in conjunction with an external reclosing device.

The trip commands initated by the automatic reclosure function are counted. A statis-tical counter is available for this purpose for the first and all subsequent reclosing com-mands.

The automatic reclosing function is typically utilized only in situations where the occur-rence of temporary faults is anticipated. Therefore, the automatic reclosing system isnot applied when the 7SJ62/63/64 relay is used to protect generators, motors, trans-formers, and cables.

2.13.1.2 Program Execution

Initiation Initiation of the automatic reclosing function can be caused by internal protective func-tions or externally using a binary input. The automatic reclosing system can be pro-

Trip

Breaker Status

Dead Time

Reclose

Reset Time

Reclosing Successful

Dead Time 1 Dead Time 2

Cancel with a newTrip Command

Cancel with a newTrip Command

Command

Command

Starting cycle Cycle 1 Cycle 2

79 DynBlock

79 Lockout

52-a

closedopen

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Automatic Reclosing System (79M)

grammed such that any of the elements of table 2-16 can initiate (Starts 79), notinitiate (No influence), or block reclosing (Stops 79).:

If an element initiates reclosing, the appropriate reclosing program is executed.

The binary input messages 02715 “>Start 79 Gnd“ and 02716 “>Start 79 Ph“ for starting an automatic reclosure program can also be activated via CFC (fast PLCtask processing). Automatic reclosure can thus be initiated via any messages (e.g.protective pickup) if address 7164 BINARY INPUT is set to Starts 79.

Operating Time The operatng time serves for monitoring the time between a general device pickupand the trip command of a protective function configured as starter. The operating timeis launched when pickup of any function is detected, irrespective of whether this func-tion interacts with the automatic reclosure program or not. If a protective function con-figured as starter initiates a trip command during the operating time, the automatic re-closure program is started. Trip commands of a protective function configured as start-er occurring in the time between expiration of the operating time and dropout of thegeneral device pickup cause the dynamic blocking of the automatic reclosing program.Trip commands of protective functions which are not configured as starter do not affectthe operative time.

If the automatic reclosure program interacts with an external protection device, thegeneral device pickup for start of the operating time is communicated to the automaticreclosing program via binary input 02711 “>79 Start“.

ReclosingPrograms

Depending on the type of fault, two different reclosing programs can be used. The fol-lowing applies:

• The single phase fault (ground fault) reclosing program applies if a phase-to-groundfault is detected. Therefore, the ground fault reclosing program is executed onlywhen the elements associated with a specific phase and/or ground pick up. Thisprogram can also be started via a binary input.

• The multiple phase fault (phase fault program) reclosing program applies to all othercases. That is, when elements associated with two or more phases pickup, with orwithout the pickup of ground elements, the phase reclosing program is executed. Inaddition, when automatic reclosing is initiated by other functions, such as negativesequence elements, the program is started. Like the ground fault reclosing pro-gram, this program can be started via a binary input as well.

The reclosure program evaluates only elements that pick up as elements dropping outmay corrupt the result if they drop out at differen times when opening the circuit break-er. Therefore, the ground fault reclosure program is executed only when the elements

Table 2-16 79 start

Non-directional start Directional start Start other50-1 67-1 sens Ground Flt(50Ns, 51Ns)

50N-1 67N-1 46

50-2 67-2 BINARY INPUT

50N-2 67N-2

51 67 TOC

51N 67N TOC

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associated with one particular phase pick up until the circuit breaker is opened; all oth-ers will initate the phase fault program.

For each of the programs, up to 9 reclosing attempts can be separately programmed.The open breaker times preceding the first four reclosing attempts can be indepen-dently set, however, the open breaker times preceding the fifth through the ninth re-closing attempts will correspond to the open breaker time that precedes the fourth re-closing attempt.

Reclosing BeforeSelectivity

For the automatic reclosure sequence to be successful, faults on any part of the linemust be cleared from the feeding line end(s) within the same – shortest possible –time. Usually, therefore, an instantaneous protection element is set to operate beforean automatic reclosure. In addition, when two or more reclosing attempts are antici-pated, high speed tripping should be allowed. To begin with, high speed tripping min-imizes the impact fault current might have on the system. Second, high speed trippingprevents the operation of load side fuses for temporary faults. Prior to the final reclos-ing attempt, however, high speed tripping should be defeated to prevent a feeder lock-out from occurring due to faults beyond load side protective devices.

Single-ShotReclosing

When a trip signal is programmed to initiate the automatic reclosing system, the ap-propriate automatic reclosing program will be executed. Once the circuit breaker hasopened, the programmable dead time interval is started (see also side title “ReclosingPrograms“). Once the dead time interval has elapsed, a closing signal is issued to re-close the circuit breaker. A blocking time interval TIME RESTRAINT is started at thesame time. If a new fault occurs before the blocking time elapses, the automatic re-closing system is dynamically blocked causing the final tripping of the circuit breaker.

The dead time can be set individually for each of the two reclosing programs.

Criteria for opening the circuit breaker may either be the auxiliary contacts of the circuitbreaker or the dropout of the general device pickup if auxiliary contacts are not con-figured.

If the fault is cleared (successful reclosing attempt), the blocking time expires and au-tomatic reclosing is reset in anticipation of a future fault.

If the fault is not cleared (unsuccessful reclosing attempt), then a final tripping signalis initiated by one or more protective elements.

Multi-ShotReclosing

The 7SJ62/63/64 relay can be programmed to initiate up to nine (9) reclosing at-tempts. The number of reclosing attempts can be set differently for the phase fault re-closing program and the ground fault reclosing program. The first dead time intervalprecedes, in principle, the first reclosing attempt. If the first reclosing attempt is unsuc-cessful, the blocking time interval is reset and the second dead time interval begins.At the end of the second open breaker interval, a second reclosing attempt is initiated.This cycle can be repeated until the allowable number of reclosing attempts pro-grammed have been made.

The dead time intervals preceding the first four (4) reclosing attempts can be set dif-ferently for each of the two reclosing programs. The dead time intervals preceding thefifth (5) through the ninth (9) reclosing attempts will be equal to the dead time intervalthat precedes the fourth (4) reclosing attempt.

If one of the reclosing attempts is successful, the blocking time expires and the auto-matic reclosing system is reset.

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If none of the reclosing attempts is successful, then a final circuit breaker trip will takeplace after the last allowable reclosing attempt has been made.

After the final circuit breaker trip, the automatic reclosing system is dynamicallyblocked (see below).

Blocking Time The function of the blocking time has already been described in the paragraphs at sidetitle “Single-/Multi-Shot Reclosing”. The blocking time can be prolonged when the fol-lowing conditions are fulfilled.

The time TMax CLOSE CMD defines the maximum time during which a close com-mand applies. If a new trip command occurs before this time has run out, the closecommand will be terminated. If the time TMax CLOSE CMD is set higher than the block-ing time TIME RESTRAINT, the blocking time will be extended after expiry to the re-maining close command duration.

Likewise, a pickup from a protective function that is set to initiate the automatic reclos-ing system will lead to an extension of the blocking time!

Static Blocking Static blocking means that the automatic reclosing system is not ready to initiate re-closing, and cannot initiate reclosing as long as the blocking signal is present. Whenstatic blocking takes place, a corresponding message is generated (“79 is NOT ready“). The static blocking signal is also used internally to block the protection ele-ments that are only supposed to work when reclosing is enabled (see also side title“Reclosing Before Selectivity“ further above).

The automatic reclosing system is statically blocked for one or more of the following:

− A blocking signal (FNo. 02703 “>BLOCK 79”) is present at a binary input, if the au-tomatic reclosing system is not initiated (associated message: “>BLOCK 79“).

− A signal (FNo. 02730 “>CB Ready”) indicating the circuit breaker is ready disap-pears from a binary input, if the automatic reclosing system is not initiated (associ-ated message “>CB Ready“).

− The number of allowable reclosing attempts set for both reclosing programs is zero(associated message: “ 79 no cycle“).

− No protective functions (parameters 7150 to 7163) or binary inputs are set to ini-tiate the automatic reclosing system (associated message:” 79 no starter“).

− The circuit breaker position is reported as being “open” and no trip command ap-plies (associated message: “ 79 BLK: CB open“). This presumes that 7SJ62/63/64 be informed on the condition of the trip contact via the auxiliary contacts of thecircuit breaker.

Dynamic blocking/lock out

Dynamic blocking of the automatic reclosure program occurs in those cases where thereclosure program is active and one of the conditions for blocking is fulfilled. The dy-namic blocking is signalled by the message “79 DynBlock“. The dynamic blockingfunction is associated with the configurable lock-out time SAFETY 79 ready. Thislock-out time is usually started by a blocking condition that has been fulfilled. After thelock-out time has elapsed the device checks whether or not the blocking condition canbe reset. If the blocking condition is still present or if a new blocking condition is ful-filled, the lock-out time is restarted. If, however, the blocking condition no longer holdsafter the lock-out time has elapsed, the dynamic blocking will be reset.

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Dynamic blocking/lock out is initiated if:

− The maximum number of reclosure attempts has been achieved. If a trip commandnow occurs within the lock-out time, the automatic reclosure program will beblocked dynamically, (indicated by “ 79 Max. No. Cyc“)

− The protection function has detected a three-phase fault and the device is pro-grammed (3Pol.PICKUP BLK) not to reclose into three-phase faults, (indicated by“79 BLK:3ph p.u. “).

− the operating time has elapsed without a TRIP command being issued, each TRIPcommand that occurs after the operating time has expired and before the picked-up element drops out, will initiate the dynamic blocking (indicated by “79 Tact ex-pired“).

− A protective function trips which is to block the automatic reclosure function (as con-figured). This applies irrespective of the status of the automatic reclosure system(started / not started) if a TRIP command of a blocking element occurs (indicatedby “79 BLK by trip “).

− The circuit breaker failure function is initiated.

− The circuit breaker does not trip within the configured time T-Start MONITOR af-ter a trip command was issued thus leading to the assumption that the circuit break-er has failed. (The breaker failure monitoring is primarily intented for VSI purposes.VSI safety checks are often conducted with the circuit breaker disconnected. Thebreaker failure monitoring prevents unexpected reclosing after the circuit breakerhas been reconnected, indiciated by “79 T-Start Exp“).

− The circuit breaker is not ready after the breaker monitoring time has elapsed, pro-vided that the circuit breaker check has been activated (address 7113 CHECK CB?= Chk each cycle, indicated by “79 T-CBreadyExp“),

− The circuit breaker is not ready after maximum extension of the dead time Max. DEAD EXT.. The monitoring of the circuit breaker status and the synchrocheck maycause undesired extension of the dead time. To prevent the automatic reclosuresystem from assuming an undefined state, the extension of the dead time is moni-tored. The extension time is started when the regular dead time has elapsed. Whenit has elapsed, the automatic reclosure function is blocked dynamically and the lock-out time launched. The automatic reclosure system resumes normal state when thelock-out time has elapsed and new blocking conditions do not apply (indicated by“79 TdeadMax Exp“) .

− Manual closing has been detected (externally) and parameter BLOCK MC Dur. (T≠ 0) was set such that the automatic reclosing system responds to manual closing,

− Via a correspondingly marshalled binary input (FNo. 02703 “>BLOCK 79“). If theblocking takes places while the automatic recloser is in normal state, the latter willbe blocked statically (“79 is NOT ready“). The blocking is terminated immedi-ately when the binary input has been cleared and the automatic reclosure functionresumes normal state. If the automatic reclosure function is already running whenthe blocking arrives, the dynamic blocking takes effect (“79 DynBlock“). In thiscase the activation of the binary input starts the lock-out time SAFETY 79 ready.Upon its expiration the device checks if the binary input is still activated. This thecase, the automatic reclosure program changes from dynamic blocking to staticblocking. If the binary input is no longer active when the time has elapsed and if nonew blocking conditions apply, the automatic reclosure system resumes normalstate.

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Circuit BreakerStatus

The detection of the actual circuit breaker position is necessary for the correct func-tionality of the auto reclose function. The breaker position can be detected via thebreaker contacts and the binary inputs 04602 “>52-b“ and 04601 “>52-a“. Themethod to be used depends on the masking of the binary inputs: “>52-a” (FNo.04601) and “>52-b” (FNo. 04602). The following applies:

• If binary input 04601 „>52-a“ and binary input 04602 „>52-b“ are used, the auto-matic reclosure function can detect whether the circuit breaker is open, closed or inintermediate position.If the circuit breaker is open or in intermediate position without a trip command be-ing present, the automatic reclosure function is blocked dynamically if it is alreadyrunning. If the automatic reclosure system is in normal state, it will be blocked stat-ically. When checking whether a trip command applies, all trip commands of the de-vice are taken into account irrespective of whether the function acts as starting orblocking element on behalf of the automic reclosure program.

• If binary input 04601”>52-a“ alone is allocated, the circuit breaker is consideredopen while the binary input is not active.If the binary input becomes inactive while no trip command of (any) function applies,the automatic reclosure system will be blocked. The blocking will be of static natureif the automatic reclosure system is in normal state at this time. If the automatic re-closing system is already running, the blocking will be a dynamic one.The dead time is started if the binary input becomes inactive following the trip com-mand of a starting element. An intermediate position of the circuit breaker cannotbe detected for this type of allocation.

• If binary input 04602 “>52-b“ alone is allocated, the circuit breaker is consideredopen while the binary input is active.If the binary input becomes active while no trip command of (any) function applies,the automatic reclosure system will be blocked dynamically provided it is alreadyrunning. Otherwise the blocking will be a static one.The dead time is started if the binary input becomes active following the trip com-mand of a starting element. An intermediate position of the circuit breaker cannotbe detected for this type of allocation.

• If neither binary input 04602 “>52-b“ nor 04601 “>52-a“ are allocated, the auto-matic reclosure program cannot detect the position of the circuit breaker. In thiscase, the automatic reclosure system will be controlled exclusively via pickups andtrip commands. Monitoring for “52-b without TRIP” and starting the dead time in de-pendence of the circuit breaker feedback is not possible in this case.

Circuit BreakerMonitoring

The ability of a circuit breaker to reclose and re-trip if necessary can be monitored bythe 7SJ62/63/64 relay.

A precondition for a reclosing attempt, following a trip command initiated by a protec-tive relay element and subsequent initiation of the automatic reclosing function, is thatthe circuit breaker is ready for at least one TRIP-CLOSE-TRIP cycle. The readinessof the circuit breaker is monitored by the device using a binary input (“>CB Ready”).In the case where this signal from the breaker mechanism is not available, the circuitbreaker monitoring feature should be disabled, otherwise reclosing attempts will re-main blocked.

− When multiple reclosing attempts are programmed, it is a good idea to monitor thecircuit breaker condition prior to each reclosing attempt as well, since operation of,for example, pneumatically controlled circuit breakers will result in reduced air pres-sure. A reclosing attempt will be blocked until the binary input, configured with the

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function 02730,indicates that the circuit breaker is ready to complete anotherCLOSE-TRIP cycle.

− The recovery time of the circuit breaker can be monitored by the 7SJ62/63/64 relay.The monitoring time CB TIME OUT expires for as long as the circuit breaker doesnot indicate that it is ready via binary input “>CB Ready“ (FNo. 02730). Meaningthat as the binary input “>CB Ready“ is cleared, the monitoring time CB TIME OUTis started. If the binary input returns before the monitoring time has elapsed, themonitoring time will be cancelled and the reclosure process is continued. If the mon-itoring time runs longer than the dead time, the dead time will be extended accord-ingly. If the monitoring time elapses before the circuit breaker signals its readiness,the automatic reclosure function will be blocked dynamically.

Interaction with the synchronizing function may cause the dead time to extend inad-missibly. To prevent the automatic reclosure function from remaining in an undefinedstate, dead time extension is monitored. The maximum extension of the dead time canbe set at Max. DEAD EXT..

The monitoring time Max. DEAD EXT. is started when the regular dead time haselapsed. If the synchronizing function responds before the time has elapsed, the mon-itoring time will be stopped and the close command generated. If the time expires be-fore the synchronizing function reacts, the automatic reclosure function will be blockeddynamically.

Please make sure that the above mentioned time is not shorter than the monitoringtime CB TIME OUT.

The time 7114 T-Start MONITOR serves for monitoring the response of the auto-matic reclosure function to a breaker failure. It is activated by a trip command arrivingbefore or during a reclosing operation and marks the time that passes between trip-ping and opening of the circuit breaker. If the time elapses, the device assumes abreaker failure and the automatic reclosure function is blocked dynamically. If param-eter T-Start MONITOR is set to ∞, the start monitoring is disabled.

2.13.1.3 Controlling Protective Stages

Depending on the reclosing cycle it is possible to control stages of the directional andnon-directional overcurrent protection by means of the automatic reclosure system.Protective stage control implies that,

1. time overcurrent stages may trip instantaneously depending on the automatic re-closure cycle (T = 0), they may remain unaffected by the auto reclosing functionAR (T = T) or may be blocked (T = ∞).

2. time overcurrent stages can be influenced via the cold load pickup function (seeSection 2.4) regarding thresholds and trip time delays depending on whether theautomatic reclosure system is ready or not.

Control of the overcurrent protection stages takes effect by releasing the cycle markedby the corresponding parameter. The cycle zone release is indicated by the messages“79 1.CycZoneRel“ through “79 4.CycZoneRel“. If the automatic reclosure sys-tem is in normal state, the settings for the starting cycle apply. Consequently, their set-tings always take effect when the automatic reclosure system assumes normal state.

The settings are released for each following cycle by issuing the close command andstarting the blocking time. Following a successfull auto reclosing operation (blockingtime elapsed) or when reset after blocking, the automatic reclosure system assumes

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normal state. Control of the protection is again assumed by the parameters for thestarting cycle.

Figure 2-68 shows an example of protection stages control

Figure 2-68 Control of protection stages for two-fold, successful auto reclosure

Example:

Before the first reclosure faults are to be eliminated quickly applying stages 50-2 or50N-2. Fast fault termination thus has priority over selectivity aspects as the reclosingaction aims at maintaining normal system operation. If the fault prevails, a second trip-ping is to take place instantaneously and a second reclosure.

After the second reclosure, however, stages 50-2 or 50N-2 are to be blocked so thefault can be eliminated applying stages 50-1 or 50N-1 according to the network’s timegrading schedule giving priority to selectivity concerns.

Addresses 7202 bef.1.Cy:50-2, 7214 bef.2.Cy:50-2 and 7203 bef.1.Cy:50N-2 and 7215 bef.2.Cy:50N-2 are set to instant. T=0 sothese stages are active after the first reclosure. To the contrary, addresses 7226

Pick up

TripCommand

Breaker

Dead Time

RecloseCommand

Reset Time

79 1.CycZoneRel

Starting cycle Cycle 1 Cycle 2

79 2.CycZoneRel

79 3.CycZoneRel

79 1stCyc.

79 1stCyc.

T = 0 T = 0

Starting-cycle

Time delay50-2, 50N-2

T = 0T = 0 T = 0T = ∞

Status 52-a

closedopen

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bef.3.Cy:50-2 and 7227 bef.3.Cy:50N-2 are set to blocked T= causingstages 50-2 and 50N-2 to be blocked after the second reclosure. The back-up stagese.g., 50-1 and 50N-1 must obviously not be blocked (addresses 7200, 7201, 7212,7213, 7224 and 7225).

The blocking applies only after reclosure according to the settings address. Hence, itis possible to specify again other conditions for a third reclosure.

The blocking conditions are also valid for the zone sequence coordination, provided itis available and activated (address 7140, see also Subsection 2.13.1.4, “Zone Se-quence Coordination1)“).

2.13.1.4 Zone Sequence Coordination1)

It is the task of the zone sequence coordination to harmonize the automatic reclosurefunction of this device with that of another device that is part of the same power sys-tem. It is a complementary function to the automatic reclosure program and allows forexample to perform group reclosing operations in radial systems. In case of multiplereclosures, groups may also be in nested arrangement and further high-voltage fusescan be overgraded or undergraded.

Zone sequencing works by blocking certain protective functions depending on the re-close cylce. This is implemented by the protective stages control (see Subsection2.13.1.3).

As a special feature, changing from one reclosing cycle to the next is possible withouttrip command only via pickup/dropout of stage 50-1 or 50N-1.

Figure 2-69 shows an example of how zone sequencing and protection of load sidefuses is possible in a radial distribution system. Consider the relays protecting Feeder#3 and the busbar. Assume that the relay protecting Feeder #3 is programmed for onereclosing attempt and that the busbar relay does not utilize reclosing.

For fault F1 at Tap Line #2, the 50-2 elements associated with both the Feeder #3 re-lay and the busbar relay pickup. The time delay of the 50-2 element protecting Feeder#3 is set so that the Feeder #3 circuit breaker will clear the fault before the fuse at TapLine #2 is damaged. After the first reclosing attempt, if the fault was cleared, normalservice is restored to all customers (including the customers served by Tap Line #2).If after the first reclosing attempt, the fault continues to exist, the 50-2 element at Feed-er #3 is blocked, and the fuse operates to clear the fault. If the fuse fails to clear thefault, then the 50-1 element protecting Feeder #3 will initiate a delayed trip signal (0.4seconds), thus serving as backup protection for the fuse.

Assume protection requirement require that the 50-2 element at the busbar relay beset with a delay of 0.4 seconds as well. When the fault first appears at F1, the 50-2element at the bus relay picks up, but drops out when the 50-2 element at Feeder #3trips the circuit breaker. Upon reclosing, if the fault still remains, the 50-2 element as-sociated with the bus relay picks up again, however, the fuse operates to clear thefault, thus resulting in a drop out of the 50-2 element at the busbar relay. Had the faultbeen on Feeder #3, however, the 50-2 element associated with the busbar relay wouldhave initiated a trip (simultaneously with the trip initiated by the Feeder #3 50-1 ele-ment) after reclosing had occurred. All three feeders supplied by the bus would have

1)not applicable for version 7SJ62/63/64**–**A**–

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been cut off from the incoming supply for a fault that should have locked out Feeder#3 only.

To prevent this from happening, zone sequencing is switched on at the bus relay (SeeAR setting dress 7140). With zone sequencing in operation, the bus relay counts thenumber of times a fault is interrupted. For the first fault, the 50-2 element at the bus isallowed to trip. If the fault is at F1 or on Feeder #3, the 50-2 element protecting Feeder#3 will initiate a high speed trip, thus causing the 50-2 element at the bus relay to dropout.

Figure 2-69 Illustration of Zone Sequencing and the Protection of Load Side Fuses

For the second fault, the 50-2 element at the bus relay must be blocked because the50-2 element at Feeder #3 is blocked, and a permanent fault on Feeder #3 could resultin an inadvertent trip by the 50-2 element protecting the bus. Because zone sequenc-ing is switched on at the bus relay, the bus relay counts the number of faults, and afterthe first fault, blocks the 50-2 element from tripping. Therefore, for a permanent faulton Feeder #3, the 50-2 element at the bus would have been blocked after the reclosingattempt, and the 50-1 element at Feeder #3 would have tripped the circuit breaker in0.4 seconds. Had the 50-1 element failed to clear the fault, the 50-1 element at the busrelay, which is set for 0.9 seconds, would serve as backup protection.

For the bus fault F2, the 50-2 element at the bus would have cleared the fault in 0.4seconds. The 50-1 element at the bus serves to backup the 50-2 element. Had zonesequencing not been available, the 50-2 element at the bus relay could not have beenset to clear the bus fault in 0.4 seconds without causing coordination problems be-tween the bus relay and the Feeder #3 relay. On a final note, zone sequencing is onlyeffective at the bus relay when all three feeders utilize high speed tripping prior to thefirst reclosing attempt.

Bus Supply

Feeder 1 Feeder 2 Feeder 3

Tap Line 1

Tap Line 2

7SJ62/63/

7SJ62/63/ 7SJ62/63/ 7SJ62/63/

F1

F250-2 0.4 s50-1 0.9 s

50-2 0.0 s50-1 0.4 s

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2.13.2 Programming Settings

2.13.2.1 General Settings

The internal automatic reclosure system will only be effective and accessible if ad-dress 0171 79 Auto Recl. is set to Enabled during configuration or protectivefunctions. If the automatic reclosing function is not required, then address 0171should be set to Disabled. The function can be turned ON or OFF at address 7101FCT 79.

If no automatic reclosures are performed on the feeder for which the 7SJ62/63/64 re-lay is used (e.g. cables, tranformers, motors, etc.), the automatic reclosure function isdisabled by configuration. The automatic reclosure function will then have absolutelyno effect i.e., 7SJ62/63/64 will not process the automatic reclosure function. No mes-sages exist for this purpose and binary inputs for the automatic reclosure function areignored. All parameters of block 71 are inaccessible and insignificant.

Blocking Durationfor Manual-CLOSEDetection

Parameter 7103 BLOCK MC Dur. defines the reaction of the automatic reclosurefunction when a manual closing signal is detected. The parameter can be set to spec-ify how long the auto reclose function will be blocked dynamically in case of an exter-nal manual close-command being detected via binary input (00356 “>Manual Close“). If the setting is 0, the automatic reclosure system will not respond to a man-ual close-signal.

Blocking Time andDynamic Blocking

The blocking time set at address 7105 TIME RESTRAINT defines the time that mustelapse, after a successful reclosing attempt, before the automatic reclosing function isreset, in preparation of a new fault. If a protective element picks up before the blockingtime elapses, the reclosing cycle is continues. If a protective trip occurred after the lastallowable reclosing attempt was made, then together with the trip command the feederis locked out. If a protective element picks up after the blocking time has elapsed, thena new reclosing cycle is initiated.

In general, address 7105 should be set for only a few seconds. In areas with frequentthunderstorms, a shorter blocking time may be necessary to avoid feeder lockout dueto sequential lightning strikes.

A longer blocking time should be chosen if there is no possibility to monitor the circuitbreaker ready status (see below) during multiple reclosing. In this case, the blockingtime should be longer than the time required for the circuit breaker mechanism to beready.

If a dynamic blocking/lock out of the automatic reclosing system was initiated, then re-closing functions remain blocked until the cause of the blocking has been cleared.Subsection 2.13.1 gives further information on this topic, see side title “DynamicBlocking“. The dynamic blocking is associated to the configurable blocking timeSAFETY 79 ready. It is usually started by a blocking condition that has picked up.

Circuit BreakerMonitoring

Reclosing after a short-circuit tripping presupposes that the circuit breaker is ready forat least one TRIP-CLOSE-TRIP cycle at the time when the reclosing function is initi-ated (i.e. at the beginning of a trip command):

The ready-state of the circuit breaker is signalled to the device via the binary input“>CB Ready“ (FNo. 02730).

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− It is possible to check the status of the circuit breaker before each reclosure or todisable this option (address 7113, CHECK CB?):

− CHECK CB? = No check, deactivates the circuit breaker check,

− CHECK CB? = Chk each cycle, to verify the circuit breaker status before eachreclosing command.

− Checking the status of the circuit breaker is usually recommended. Should thebreaker not provide such a signal, you can disable the circuit breaker check at ad-dress 7113 CHECK CB? to No check, as otherwise auto reclosure would be im-possible.

− The status monitoring time CB TIME OUT can be configured at address 7115 if thecircuit breaker check was enabled at address 7113. This time is set slightly higherthan the maximum recovery time of the circuit breaker following reclosure. If the cir-cuit breaker is not ready after the time has expired, reclosing is omitted and dynam-ic blocking is initiated thus locking the auto reclose function.

Time Max. DEAD EXT. serves for monitoring the dead time extension. The extensioncan be initiated by the circuit breaker monitoring time CB TIME OUT and by the syn-chronizing function.

The monitoring time Max. DEAD EXT. is started after the configured dead time haselapsed.

This time must not be shorter than CB TIME OUT. When using the monitoring time CB TIME OUT, the time Max. DEAD EXT. should be set to a value ≥ CB TIME OUT.

If the auto reclose system is operated with a (internal or external) synchronizing func-tion, Max. DEAD EXT. assures that the auto reclose system does not remain in un-defined state when the synchronizing function fails to check back.

If the synchronization is used as synchrocheck (for synchronous systems), the moni-toring time may be configured rather short e.g., to some seconds. In this case the syn-chronizing function merely checks the synchronism of the power systems. If synchro-nism prevails it switches in instantaneously, otherwise it will not.

If the synchronization is used for synchronous/asynchronous networks, the monitoringtime must grant sufficient time for determining the time for switching in. This dependson the frequency slip of the two subnetworks. A monitoring time of 100s should be suf-ficient to account for most applications for asynchronous networks.

Generally, the monitoring time should be longer than the maximum duration of thesynchronization process (parameter 6x12).

The breaker failure monitoring time 7114 T-Start MONITOR determines the timebetween tripping (closing the trip contact) and opening the circuit breaker (checkbackof the CB auxiliary contacts). This time is started each time a tripping operation takesplace. When it has elapsed, the device assumes breaker failure and blocks the autoreclose system dynamically.

Operating Time The operating time monitors the time between pickup and trip command of a protec-tive function configured as starter while the auto reclose system is ready but not yetrunning. A trip command issued by a protective function configured as starter occuringwithin the operating time will start the automatic reclosing function. If this time differsfrom the setting value of T-ACTION (addresse7117), the automatic reclosing systemwill be blocked dynamically.

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The trip time of inverse tripping characteristics is considerably determined by the faultlocation or fault resistance. The operative time prevents reclosing in case of far remotefaults with long tripping time. Trip commands of a protective function that is not con-figured as starter do not affect the operative time.

Number ofReclosing Attempts

The number of reclosing attempts can be set separately for the programs “Phase“ (ad-dress 7136, # OF RECL. PH) and “Ground“ (address 7135, # OF RECL. GND).The exact definition of the programs is described in Subsection 2.13.1 at side title “Re-closing Programs“.

Close Command:Direct or viaControl

Address 7137 Cmd.via control can be set to either generate directly the closecommand via the automatic reclosing function (setting Cmd.via control = none)or have the closing initated by the control function. The setting list for parameter 7137is created dynamically in dependence of the masked switchgear components. If oneof the switchgear components is selected, usually the circuit breaker 52 Breaker,reclosure is accomplished via control. In this case, the automatic reclosing functiondoes not create a close command but issues a close request. This request is forward-ed to the control which then assumes the switching. Thus, the properties defined forthe switchgear component such as interlocking and command times apply for. Hence,it is possible that the close command will not be carried out due to an applying inter-locking condition.

If this behavior is not desired, the auto reclose function can also generate the closecommand “79 Close“ directly which must be marshalled to contact.

Connection toInternalSynchrocheck(only 7SJ64)

The auto reclose function can interact with the internal synchronizing function of the7SJ64 relay. For this purpose, one of the four synchronization groups must be select-ed at address 7138 Internal SYNC thus specifying the synchronization conditionsfor automatic reclosing. Moreover, the close command must be issued via control.Therefore, address 7137 Cmd.via control must be set to select the appropriateswitchgear component, usually the circuit breaker 52 Breaker. Synchronous reclos-ing via the close command “79 Close“ is not possible.

If interaction with the internal synchronization is not desired, address 7138 must beset to none.

Auto Reclosingwith ExternalSynchrocheck

Parameter 7139 External SYNC can be set to determine that the auto reclose func-tion operates with external synchrocheck. External synchronization is possible if theparameter is set to YES and 7SJ64 is linked to the external synchrocheck via the mes-sage 02865 “79 Sync.Request“ and the binary input “>Sync.release“.

2.13.2.2 Configuration

Initiation andBlocking of Reclos-ing by ProtectiveFunctions

At addresses 7150 to 7164 (see table 2-16), reclosing can be initiated or blocked forvarious types of protective elements. They constitute the interconnection between pro-tective elements and auto reclose function. Each address designates a protectivefunction together with its ANSI synonym e.g., 50-2 for the high-set stage of the non-directional time overcurrent protection (address 7152). The setting options have thefollowing meaning:

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− Starts 79 The protective element initiates the automatic reclosure via itstrip command;

− No influence the protective element does not start the automatic reclosure,it may however be initated by other functions;

− Stops 79 the protective element blocks the automatic reclosure, neithercan it be started by other functions; a dynamic blocking is initi-ated.

2.13.2.3 First Reclosing Attempt

Open BreakerTimes

The dead time preceding the first reclosing attempt is set at address 7127 DEADTIME 1: PH for the multiple phase fault reclosing program and at address 7128 DEADTIME 1: G for the single phase fault reclosing program. The time defined by this parameteris started when the circuit breaker opens (if auxiliary contacts are allocated) or whenthe pickup drops out following the trip command of a starter. The exact definition of theprograms is described in Subsection 2.13.1 at “Reclosing Programs“. The dead timeshould be set long enough to allow a temporary fault to clear (0.9 to 1.5 seconds) un-less stability is a concern, in which case faster times may be required (typically 0.3 to0.6 seconds). In radial networks prolonged idle times are usually permitted.

Cyclic Control ofProtectiveFunctions viaAutomaticReclosure

Addresses 7200 to 7211 allow cyclic control of the various protective functions by theautomatic reclosing function. Thus protective stages can be blocked selectively,switched instantaneously or according to the configured delay times. The following op-tions are available:

− Set value T=T The protective stage is delayed as configured i.e., the auto re-close function does not effect this stage;

− instant. T=0 The protective stage becomes instantaneous if the auto re-close function is ready to perform the mentioned cycle;

− blocked T= The protective stage is blocked if the auto reclose functionreaches the cycle defined in the parameter.

2.13.2.4 Second to Fourth Reclosuring Attempt

Open BreakerTimes

If more than one reclosing cycle was set, you can now configure the individual reclos-ing settings for the 2nd to 4th cycle. The same options are available as for the first cy-cle.

For the 2nd cycle:

Address 7129 DEADTIME 2: PH Dead time for the second (2nd) reclosingattempt (multiple phase recl. program)

Address 7130 DEADTIME 2: G Dead time for the second (2nd) reclosingattempt (single phase recl. program)

Addresses7212 through 7223 Cyclic control of the variousprotective functions before the 2nd

reclosing attempt

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For the 3rd cycle:

Address 7131 DEADTIME 3: PH Dead time for the second (3rd) reclosingattempt (multiple phase recl. program)

Address 7132 DEADTIME 3: G Dead time for the second (3rd) reclosingattempt (single phase recl. program)

Addresses7224 through 7235 Cyclic control of the various protectivefunctions before the third reclosingattempt

For the 4th cycle:

Address 7133 DEADTIME 4: PH Dead time for the second (4th) reclosingattempt (multiple phase recl. program)

Address 7134 DEADTIME 4: G Dead time for the second (4th) reclosingattempt (single phase recl. program)

Addresses7236 through 7247 Cyclic control of the various protectivefunctions before the fourth reclosuringattempt

2.13.2.5 Fifth to Ninth Reclosing Attempt

If more than four cycles are configured, the dead times preceding the fifth (5th) throughthe ninth (9th) reclosing attempts are equal to the open breaker time which precedesthe fourth (4th) reclosing attempt.

2.13.2.6 Blocking

Blocking Three-Phase Faults

Regardless of which reclosing program is executed, automatic reclosing can beblocked for trips following three-phase faults at address 7165 3Pol.PICKUP BLK.The pickup of all three phases for a specific phase element is the criterion required forthree-phase fault blocking.

Blocking of auto re-close via internalcontrol

The auto reclose function can be blocked, if control commands are issued. The controlinformation must be routed via CFC (interlocking task-level) using theCMD_Information block (see Figure 2-70).

Figure 2-70 Blocking of the auto reclose function using the internal control function

“IN: Control Device52 Breaker CF_D12”

“OUT: >BLOCK 79”

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2.13.2.7 Zone Sequencing1)

At address 7140, ZONE SEQ.COORD., the zone sequencing feature can be turned ONor OFF.

If multiple reclosures are performed and the zone sequencing function is deactivated,only those reclosing cycles are counted which the device has conducted after a tripcommand. With the zone sequencing function switched on, an additional sequencecounter also counts such auto reclosures which (in radial systems) are carried out byrelays connected on load side. This presupposes that the pickup of the 50-1/50N-1–stages drops out without a trip command being issued by a protective function initiat-ing the auto reclose function. The parameters at addresses 7200 through 7247 (seeparagraph below at “Initiation and Blocking of Reclosing by Protective Functions“ and“Controlling Directional/Non-Directional Overcurrent Protection Stages via Cold LoadPickup“ can thus be set to determine which protective stages are active or blockedduring what dead time cycles.

In the example shown in Figure 2-69 (Subsection 2.13.1.4), the zone sequencingwould be initated at the bus relay. Moreover, the 50-2 stages would have to be blockedafter the second reclosure i.e., address 7214 bef.2.Cy:50-2 set to blocked T=.The zone sequencing of the feeder relays is switched off but the 50-2 stages must alsobe blocked here after the second reclosing attempt. Moreover, it must be ensured thatthe 50-2 stages start the automatic reclosing function: address 7152 50-2 set toStarts 79.

2.13.2.8 Controlling Directional/Non-Directional Overcurrent Protection Stages via Cold Load Pickup

The cold load pickup function is another possibility to control the protection via the au-tomatic reclosing system (see also Section 2.4). This function provides the address1702 Start Condition. It determines the starting conditions for the increased set-ting values of current and time of the cold load pickup to apply for directional and non-directional overcurrent protection.

If address 1702 Start Condition = 79 ready, the directional and non-directionalovercurrent protection always employ the increased setting values if the automatic re-closing system is ready. The auto reclosing function provides the signal “79 ready”for controlling the cold load pickup. The signal “79 ready“ is always active if the autoreclosing system is available, active, unblocked and ready for another cycle. Controlvia the cold load pickup function is non-cyclic.

Since control via cold load pickup and cyclic control via auto reclosing system can runsimultaneously, the directional and non-directional overcurrent protection must coor-dinate the input values of the two interfaces. In this context the cyclic auto reclosingcontrol has the priority and thus overwrites the release of the cold load pickup function.

If the protective stages are controlled via the automatic reclosing function, changingthe control variables (e.g. by blocking) has no effect on stages that are already run-ning. The stages in question are continued.

1)Not applicable for version 7SJ62/63/64**–**A**–

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2.13.2.9 Settings for Automatic Reclosing

The setting options of address 7137 Cmd.via control are generated dynamicallyaccording to the current configuration.

Address 7138 Internal SYNC is only available for 7SJ64.

Addr. Setting Title Setting Options Default Setting Comments

7101 FCT 79 OFFON

OFF 79 Auto-Reclose Function

7103 BLOCK MC Dur. 0.50..320.00 sec; 0 1.00 sec AR blocking duration aftermanual close

7105 TIME RESTRAINT 0.50..320.00 sec 3.00 sec 79 Auto Reclosing reset time

7108 SAFETY 79 ready 0.01..320.00 sec 0.50 sec Safety Time until 79 is ready

7113 CHECK CB? No checkCheck each cycle

No check Check circuit breaker beforeAR?

7114 T-Start MONITOR 0.01..320.00 sec; ∞ 0.50 sec AR start-signal monitoring time

7115 CB TIME OUT 0.10..320.00 sec 3.00 sec Circuit Breaker (CB) SupervisionTime

7116 Max. DEAD EXT. 0.50..1800.00 sec; ∞ 100.00 sec Maximum dead time extension

7117 T-ACTION 0.01..320.00 sec; ∞ 0.20 sec Action time

7135 # OF RECL. GND 0..9 1 Number of Reclosing CyclesGround

7136 # OF RECL. PH 0..9 1 Number of Reclosing CyclesPhase

7137 Cmd.via control Close command via controldevice

7138 Internal SYNC Internal 25 synchronisation

7139 External SYNC YESNO

NO External 25 synchronisation

7140 ZONESEQ.COORD.

OFFON

OFF ZSC - Zone sequence coordina-tion

7165 3Pol.PICKUP BLK YESNO

NO 3 Pole Pickup blocks 79

7150 50-1 No influenceStarts 79Stops 79

No influence 50-1

7151 50N-1 No influenceStarts 79Stops 79

No influence 50N-1

7152 50-2 No influenceStarts 79Stops 79

No influence 50-2

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Automatic Reclosing System (79M)

7153 50N-2 No influenceStarts 79Stops 79

No influence 50N-2

7154 51 No influenceStarts 79Stops 79

No influence 51

7155 51N No influenceStarts 79Stops 79

No influence 51N

7156 67-1 No influenceStarts 79Stops 79

No influence 67-1

7157 67N-1 No influenceStarts 79Stops 79

No influence 67N-1

7158 67-2 No influenceStarts 79Stops 79

No influence 67-2

7159 67N-2 No influenceStarts 79Stops 79

No influence 67N-2

7160 67 TOC No influenceStarts 79Stops 79

No influence 67 TOC

7161 67N TOC No influenceStarts 79Stops 79

No influence 67N TOC

7162 sens Ground Flt No influenceStarts 79Stops 79

No influence (Sensitive) Ground Fault

7163 46 No influenceStarts 79Stops 79

No influence 46

7164 BINARY INPUT No influenceStarts 79Stops 79

No influence Binary Input

7127 DEADTIME 1: PH 0.01..320.00 sec 0.50 sec Dead Time 1: Phase Fault

7128 DEADTIME 1: G 0.01..320.00 sec 0.50 sec Dead Time 1: Ground Fault

7200 bef.1.Cy:50-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50-1

7201 bef.1.Cy:50N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50N-1

Addr. Setting Title Setting Options Default Setting Comments

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7202 bef.1.Cy:50-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50-2

7203 bef.1.Cy:50N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50N-2

7204 bef.1.Cy:51 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 51

7205 bef.1.Cy:51N Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 51N

7206 bef.1.Cy:67-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67-1

7207 bef.1.Cy:67N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67N-1

7208 bef.1.Cy:67-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67-2

7209 bef.1.Cy:67N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67N-2

7210 bef.1.Cy:67 TOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67 TOC

7211 bef.1.Cy:67NTOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67N TOC

7129 DEADTIME 2: PH 0.01..320.00 sec 0.50 sec Dead Time 2: Phase Fault

7130 DEADTIME 2: G 0.01..320.00 sec 0.50 sec Dead Time 2: Ground Fault

7212 bef.2.Cy:50-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50-1

7213 bef.2.Cy:50N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50N-1

7214 bef.2.Cy:50-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50-2

7215 bef.2.Cy:50N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50N-2

Addr. Setting Title Setting Options Default Setting Comments

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7216 bef.2.Cy:51 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 51

7217 bef.2.Cy:51N Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 51N

7218 bef.2.Cy:67-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67-1

7219 bef.2.Cy:67N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67N-1

7220 bef.2.Cy:67-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67-2

7221 bef.2.Cy:67N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67N-2

7222 bef.2.Cy:67 TOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67 TOC

7223 bef.2.Cy:67NTOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67N TOC

7131 DEADTIME 3: PH 0.01..320.00 sec 0.50 sec Dead Time 3: Phase Fault

7132 DEADTIME 3: G 0.01..320.00 sec 0.50 sec Dead Time 3: Ground Fault

7224 bef.3.Cy:50-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50-1

7225 bef.3.Cy:50N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50N-1

7226 bef.3.Cy:50-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50-2

7227 bef.3.Cy:50N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50N-2

7228 bef.3.Cy:51 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 51

7229 bef.3.Cy:51N Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 51N

Addr. Setting Title Setting Options Default Setting Comments

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7230 bef.3.Cy:67-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67-1

7231 bef.3.Cy:67N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67N-1

7232 bef.3.Cy:67-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67-2

7233 bef.3.Cy:67N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67N-2

7234 bef.3.Cy:67 TOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67 TOC

7235 bef.3.Cy:67NTOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67N TOC

7133 DEADTIME 4: PH 0.01..320.00 sec 0.50 sec Dead Time 4: Phase Fault

7134 DEADTIME 4: G 0.01..320.00 sec 0.50 sec Dead Time 4: Ground Fault

7236 bef.4.Cy:50-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50-1

7237 bef.4.Cy:50N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50N-1

7238 bef.4.Cy:50-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50-2

7239 bef.4.Cy:50N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50N-2

7240 bef.4.Cy:51 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 51

7241 bef.4.Cy:51N Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 51N

7242 bef.4.Cy:67-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67-1

7243 bef.4.Cy:67N-1 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67N-1

Addr. Setting Title Setting Options Default Setting Comments

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Automatic Reclosing System (79M)

2.13.2.10Information List for Automatic Reclosing

7244 bef.4.Cy:67-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67-2

7245 bef.4.Cy:67N-2 Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67N-2

7246 bef.4.Cy:67 TOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67 TOC

7247 bef.4.Cy:67NTOC Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67N TOC

Addr. Setting Title Setting Options Default Setting Comments

F.No. Alarm Comments

02701 >79 ON >79 ON

02702 >79 OFF >79 OFF

02703 >BLOCK 79 >BLOCK 79

02730 >CB Ready >Circuit breaker READY for reclosing

02715 >Start 79 Gnd >Start 79 Ground program

02716 >Start 79 Ph >Start 79 Phase program

02722 >ZSC ON >Switch zone sequence coordination ON

02723 >ZSC OFF >Switch zone sequence coordination OFF

02781 79 OFF 79 Auto recloser is switched OFF

02782 79 ON 79 Auto recloser is switched ON

02784 79 is NOT ready 79 Auto recloser is NOT ready

02785 79 DynBlock 79 - Auto-reclose is dynamically BLOCKED

02801 79 in progress 79 - in progress

02851 79 Close 79 - Close command

02862 79 Successful 79 - cycle successful

02863 79 Lockout 79 - Lockout

02878 79 L-N Sequence 79-A/R single phase reclosing sequence

02879 79 L-L Sequence 79-A/R multi-phase reclosing sequence

02883 ZSC active Zone Sequencing is active

02884 ZSC ON Zone sequence coordination switched ON

02885 ZSC OFF Zone sequence coordination switched OFF

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00127 79 ON/OFF 79 ON/OFF (via system port)

02788 79 T-CBreadyExp 79: CB ready monitoring window expired

02810 79 TdeadMax Exp 79: Maximum dead time expired

02889 79 1.CycZoneRel 79 1st cycle zone extension release

02890 79 2.CycZoneRel 79 2nd cycle zone extension release

02891 79 3.CycZoneRel 79 3rd cycle zone extension release

02892 79 4.CycZoneRel 79 4th cycle zone extension release

02809 79 T-Start Exp 79: Start-signal monitoring time expired

02865 79 Sync.Request 79: Synchro-check request

02844 79 1stCyc. run. 79 1st cycle running

02845 79 2ndCyc. run. 79 2nd cycle running

02846 79 3rdCyc. run. 79 3rd cycle running

02847 79 4thCyc. run. 79 4th or higher cycle running

02731 >Sync.release >AR: Sync. release from ext. sync.-check

02711 >79 Start >79 External start of internal A/R

02808 79 BLK: CB open 79: CB open with no trip

02823 79 no starter 79: no starter configured

02824 79 no cycle 79: no cycle configured

02827 79 BLK by trip 79: blocking due to trip

02828 79 BLK:3ph p.u. 79: blocking due to 3-phase pickup

02829 79 Tact expired 79: action time expired before trip

02830 79 Max. No. Cyc 79: max. no. of cycles exceeded

02899 79 CloseRequest 79: Close request to Control Function

F.No. Alarm Comments

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Fault Location

2.14 Fault Location

Measurement of the distance to a short-circuit fault is an important feature of the7SJ62/63/64 relay allowing faster determination of the fault location. Fault location isonly possible if the device is connected to both current and voltage transformers.

2.14.1 Description of Fault Location

Initiation Fault location is initiated if the directional or non-directional overcurrent relay elementshave initiated a trip signal. Once initiated, the fault locator determines the valid mea-surement loop and measurement window. Sampled pairs of values of short circuit cur-rent and short circuit voltage, are stored in a buffer, and made available for the imped-ance calculations R (Resistance) and X (Reactance). Measurement quantity filteringand the number of impedance calculations automatically adjust to the number of rele-vant measurement value pairs stored in the buffer.

Fault location can also be initiated using a binary input as long as a directional or non-directional overcurrent relay element has picked up. This feature allows fault locationcalculations to proceed even if another protective relay (load side relay, etc.) clearedthe fault, (e.g. the internal time-overcurrent elements did not trip).

MeasurementProcess

The evaluation of the measured quantities takes place after the fault has been hasbeen isolated and cleared. At least three result pairs of R and X are calculated fromthe stored and filtered measured quantities in accordance with the line equations. Iffewer than three pairs of R and X are calculated, then the fault location feature willgenerate no information. Average and standard deviations are calculated from the re-sult pairs. After eliminating “questionable results”, which are recognized via a largevariance from the standard deviation, average values are calculated once again for X.This average is the fault reactance, and is proportional to the fault distance.

Path Selection Using the pickup of the overcurrent time elements (directional or non-directional), thevalid measurement paths for the calculation of fault reactance’s are selected. The faultreactance’s can, of course, only be calculated for phase-to-ground paths if the deviceis connected to three current transformers connected in a grounded-wye configurationand three voltage transformers connected in a grounded-wye configuration.

Table 2-17 shows the assignment of the evaluated paths to the possible pickup sce-narios of the protective elements given that the device is supplied from three voltagetransformers connected in a grounded-wye configuration. If the voltage transformersare connected in an open delta configuration, then Table 2-18 applies. Of course, nophase-to-ground paths can be measured in this case.

In addition, paths are not available for further calculation if one of the two currents ina path are less than 10% of the other current in that path, or if any currents in the pathare less than 10% of the nominal device current.

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Table 2-17 Selection of Paths to be Reported for Wye-Connected Voltage Transformers

Pickup Possible Paths Evaluated Paths Notes

A A–G, A–B, C–A A–G orA–G and least L–L

If only one phase ispicked up, then only theappropriate phase-to-ground path is displayed.If the reactance’s of oneor both φ-φpaths are lessthan the φ-G reactance,then the φ-φpath with theleast reactance is alsodisplayed.

B B–G, A–B, B–C B–G orB–G and least L–L

C C–G, C–A, B–C C–G orC–G and least L–L

G A–G, B–G, C–G least L–G Only the φ-G path withthe least reactance is dis-played.

A, G A–G A–G

The appropriate phase-to-ground path is dis-played

B, G B–G B–G

C, G C–G C–G

A, B A–B, A–G, B–G A–B orA–B and A–G and B–G

The appropriate φ-φ pathis always displayed; if thereactance differential be-tween the φ-G paths islarger than 15% of thelarger φ-G path, then bothφ-G paths are also dis-played.

B, C B–C, B–G, C–G B–C orB–C and B–G and C–G

A, C C–A, A–G, C–G C–A orC–A and A–G and C–G

A, B, G A–B, A–G, B–G A–B orA–B and A–G and B–G

The appropriate φ-φ pathis always displayed; if thereactance differential be-tween the φ-G paths islarger than 15% of thelarger φ-G path, then bothφ-G paths are also dis-played.

B, C, G B–C, B–G, C–G B–C orB–C and B–G and C–G

A, C, G C–A, A–G, C–G C–A orC–A and A–G and C–G

A, B, C A–B, B–C, C–A Least φ-φ pathOnly the least φ-φ path isdisplayed.A, B, C, G A–B, B–C, C–A Least φ-φ path

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Fault Location

Result As results of the fault location, the following results are displayed or obtained usingDIGSI® 4:

− One or more short circuit paths from which the fault reactance was derived.

− One or more reactance’s per phase in Ω secondary.

− The fault distances, proportional to the reactance’s, in km or miles of line, convertedon the basis of the line’s predetermined reactance (entered at address 1105 or1106, see Subsection 2.1.6).

Note: The distance result, in miles or kilometers, can only be accurate for homogenousline sections. If the line is made up of several sections with different reactance’s, thenthe reactance derived by the fault location can be evaluated for a separate calculationof the fault distance. For transformers and motors, only the reactance result, not thedistance result, is significant.

2.14.2 Setting The Functional Parameters

General The calculation of fault distance will only take place if address 0180 Fault Locatoris set to Enabled. If the fault locating function is not needed, then address 0180should be set to Disabled.

Initiation Normally the fault location calculation is started when a protective element initiates atrip signal (8001 START = TRIP). However, address 8001 START is set to Pickup,fault location can be initiated just by the pickup of a protective element. Irrespective ofthis fact, calculation of the fault location can be started externally via binary input(FNo. 01106, “>Start Flt. Loc“).

Table 2-18 Selection of Paths to be Reported for Open-Delta Connected Voltage Transform-ers

Pickup Possible Paths Evaluated Paths Notes

A A–B, C–A Least φ − φ

The least φ-φpath is dis-played.B A–B, B–C Least φ − φ

C C–A, B–C Least φ − φ

A, B A–B A–B

The appropriate φ-φpath isdisplayed.

B, C B–C B–C

A, C C–A C–A

A, B, C A–B, B–C, C–A Least φ-φpath The least φ-φpath is dis-played.

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Functions

Line Constants To calculate the fault distance in miles or kilometers, the device needs the per distancereactance of the line in Ω/mile or Ω/kilometer, expressed as a secondary quantity.These values were entered during setting of the general protection data under ad-dress 1105 or 1106 (see Subsection 2.1.6).

2.14.2.1 Settings for Fault Locator

2.14.2.2 Information List for Fault Location

Addr. Setting Title Setting Options Default Setting Comments

8001 START PickupTRIP

Pickup Start fault locator with

F.No. Alarm Comments

01106 >Start Flt. Loc >Start Fault Locator

01118 Xsec = Flt Locator: secondary REACTANCE

01119 dist = Flt Locator: Distance to fault

01123 FL Loop AG Fault Locator Loop AG

01124 FL Loop BG Fault Locator Loop BG

01125 FL Loop CG Fault Locator Loop CG

01126 FL Loop AB Fault Locator Loop AB

01127 FL Loop BC Fault Locator Loop BC

01128 FL Loop CA Fault Locator Loop CA

01132 Flt.Loc.invalid Fault location invalid

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Breaker Failure Protection (50BF)

2.15 Breaker Failure Protection (50BF)

2.15.1 Description of Breaker Failure Protection

General The breaker failure protection function monitors the reaction of a circuit breaker to atrip signal. To determine if the circuit breaker has properly opened in response to a tripsignal, one of the following methods is used to ascertain the status of the circuit break-er:

• The current flow through the circuit breaker.

• The position of a circuit breaker auxiliary contact.

If after a programmable time delay, the circuit breaker has not opened, a breaker fail-ure trip signal issued, and all adjacent circuit breakers that represent sources to thefault can be tripped (see Figure 2-71, as an example).

Figure 2-71 Functional Principle of the Breaker Failure Protection Function

Initiation The breaker failure protection function can be initiated by two different sources:

• Internal protective function of the 7SJ62/63/64,

• External trip signals via binary inputs („>50BF ext SRC“).

For each of the two sources, a unique pickup message is generated, a unique timedelay is initiated, and a unique tripping signal is generated. The setting values forbreaker failure pickup and delay apply to both sources.

Criteria The criteria used to determine if the circuit breaker has operated is selectable andshould depend on the protective function that initiated the breaker failure function. Ifvoltage protection initiated breaker failure protection, fault current may or may not beflowing through the circuit breaker, therefore, current flow through the circuit breakeris not a reliable indication as to whether the circuit breaker operated properly. In thiscase, the position of the breaker auxiliary contact should be used to determine if thecircuit breaker properly operated. For protective functions that operate in response to

I>IMIN

Schutzfunktion&

BF Ttrip 0

Schalterversagerschutz

TripBF

ProtectiveFunction Trip

Breaker Failure Protection

52 52 52

52

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currents (e.g. directional and non-directional overcurrent protection, etc.), both thecurrent flow through the circuit breaker and the position of the circuit breaker auxiliarycontact can be used to determine if the circuit breaker properly operated. However,operation of a circuit breaker auxiliary contact does not always mean that the circuitbreaker successfully cleared the fault current, therefore, the device can be pro-grammed such that only the current flow criterion is used to determine breaker status.

The current criterion is met if at least one of the three phase currents exceeds the cur-rent flow monitoring setting entered at address 0212 BkrClosed I MIN (see Sub-section 2.1.3.4, “Current Flow Monitoring”). This pickup threshold is also used by otherprotective functions.

Evaluation of the circuit breaker auxiliary contact depends on the type of contact(s),and how they are connected to the binary inputs:

• Both “a” and “b” type auxiliary contacts are connected.

• Only an “a” type auxiliary contact is connected.

• Only a “b” type auxiliary contact is connected.

• No auxiliary contact is connected.

The circuit breaker condition can be detected prior to the initiation of a trip signal, de-pending on the configuration of binary inputs and auxiliary contacts. After a trip com-mand has been issued it is the aim to detect whether the circuit breaker is open or inintermediate postion by means of the checkbacks of its auxiliary contacts. This infor-mation can be used to properly operate the breaker failure function.

Logic If breaker failure is initiated, an alarm message is generated (“50BF int Pickup” or“50BF ext Pickup”), and the breaker failure timer is started. Once the time delayelapses, a breaker failure trip signal is issued (“50BF TRIP”). The trip signal can beconfigured to one of the output relays.

Figure 2-72 shows the logic diagram for the breaker failure protection scheme. It ispossible to turn the entire breaker failure protection function on or off, or it can beblocked dynamically via binary inputs.

If one of the criteria (current value, breaker auxiliary contacts) that led to pickup of thebreaker failure scheme is no longer met during the time delay elapses, then breakerfailure timer drops out and no trip signals are issued.

To protect against nuisance tripping due to excessive contact bounce, a stabilizationof the binary inputs for external trip signals takes place. This external signal must bepresent during the entire period of the delay time, otherwise the timer is reset and notripping signal is issued.

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Figure 2-72 Logic Diagram for the Breaker Failure Protection

50BF int Pickup

&

59 TRIP

Ia, Ib, Ic

S Q

R Q

>50BF ext SRC

>52-b

>52-a

or

„1“

50BF BLOCK

50BF OFF

or

Ι>Max. of

0

>Configured 52-b

„1“

>Configured 52-a or

64 TRIP

27 TRIP or

General TRIP&

&

50BF int TRIP

Ia, Ib, IcΙ>Max. of

&

T 050BF ext TRIP

50BF ext Pickup

&

50BF ACTIVE

Internal Source

External Source

or

or 50BF TRIP

T

7004 Chk BRK CONTACT

0212 BkrCl I MIN

7005 TRIP-Timer

7005 TRIP-Timer

7001 FCT 50BF

FNo. 01456

FNo. 01480

FNo. 01457

FNo. 01481

FNo. 01471

FNo. 01452

FNo. 01453

FNo. 01451

FNo. 01403

FNo. 01431

FNo. 04601

FNo. 04602

ONOFF

ONOFF

Evaluationof Aux. Cont.

No auxiliary contact

Interm. position

CB closed

Release

0212 BkrCl I MIN

>BLOCK 50BF

Measurement/Logic

is configured

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2.15.2 Programming Settings

General The breaker failure protection function is only effective and available if address 0170 50BF is set to Enabled. If the breaker failure function is not required, then address0170 should be set to Disabled. The function can be turned ON or OFF under ad-dress 7001 FCT 50BF.

Criteria Address 7004 Chk BRK CONTACT establishes whether or not a breaker auxiliary con-tact is used, via a binary input, to detect the position of a circuit breaker. If address7004 is set to ON, then both the current flow through the circuit breaker and the posi-tion of the circuit breaker auxiliary contact are used to ascertain the position of the cir-cuit breaker. This is important if the current is smaller than the configured currentthreshold (BkrClosed I MIN, address 0212) despite closed circuit breaker. The lat-ter may apply if protective tripping was caused by a voltage measurement (e.g. 59, 27,64). If these protective functions issue a trip command, the criteria for current and aux-iliary contacts are linked by a logical OR operation. Without the auxiliary contact crite-rion the circuit breaker failure protection would not be able to take effect in this case.If address 7004 is set to OFF, only the current flow through the circuit breaker is usedto indicate the position of the circuit breaker.

The current flow monitoring setting programmed at address 0212 BkrClosed I MINapplies to all three phases, and should be selected such that it is at least 10 % belowthe smallest fault current the circuit breaker would interrupt when responding to tripsignals initiated by protective relays. The setting at address 0212 should not be settoo low, otherwise, the danger exists that equalization processes in the current trans-former secondary circuit could lead to extended drop out times under conditions of ex-tremely high current to be switched off. In addition, it should be noted that other pro-tection functions depend on the current flow monitoring settings as well (e.g. voltageprotection, overload protection, and restarting block for motors).

Time Delay The breaker failure time delay setting is entered at address 7005 TRIP-Timer. Thissetting should be based on the circuit breaker interrupting time plus the dropout timeof the current flow monitoring element plus a safety margin. Figure 2-73 illustrates thetiming of a typical breaker failure scenario.

Figure 2-73 Time Chart for Typical Breaker Failure Operation

Normal Fault Clearing Time

Trip.Time

Fault Occurs

Breaker Interrupting Time

Current FlowMonitoring

Drop Out TimeSafetyTime

Breaker FailurePickup

Breaker Failure Time DelayTRIPTimer (address 7005)

Backup BreakerInterruption Time

(approx.)

Total Fault Clearing Time for Breaker Failure Condition

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2.15.2.1 Settings for Breaker Failure Protection

2.15.2.2 Information List for Breaker Failure Protection

Addr. Setting Title Setting Options Default Setting Comments

7001 FCT 50BF OFFON

OFF 50BF Breaker Failure Protection

7004 Chk BRK CON-TACT

OFFON

OFF Check Breaker contacts

7005 TRIP-Timer 0.06..60.00 sec; ∞ 0.25 sec TRIP-Timer

F.No. Alarm Comments

01403 >BLOCK 50BF >BLOCK 50BF

01431 >50BF ext SRC >50BF initiated externally

01451 50BF OFF 50BF is switched OFF

01452 50BF BLOCK 50BF is BLOCKED

01453 50BF ACTIVE 50BF is ACTIVE

01456 50BF int Pickup 50BF (internal) PICKUP

01457 50BF ext Pickup 50BF (external) PICKUP

01471 50BF TRIP 50BF TRIP

01480 50BF int TRIP 50BF (internal) TRIP

01481 50BF ext TRIP 50BF (external) TRIP

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2.16 Synchronism and Voltage Check (7SJ64 only)

2.16.1 Functional Description

General When connecting two components of a power system, the synchronizing feature ver-ifies that the start does not endanger the stabilty of the power system. Typical appli-cations are for example the synchronization of a feeder and a busbar (see Figure 2-74) or the synchronization of two busbar sections via bus coupler (see Figure 2-75).

The configuration decides whether the synchronism check is carried out only for auto-matic reclosing or only for circuit breaker control or both. It is also possible to specifydifferent release criteria for automatic close or control close. Synchronous connectionis always accomplished via the integrated control.

For comparing the two voltages the synchronizing functions takes the reference volt-age V1 and an additional voltage to be connected U2. The reference voltage U1 is con-nected to the multi-phase system. The voltage to be synchronized U2 is assigned tothe single-phase connection and may be any phase-ground or phase-phase voltage.

Figure 2-74 Infeed

If a transformer is switched between the two VT’s (Figure 2-74), its vector group canbe adapted in the 7SJ64 relay so that external adaptors are not required.

The synchronizing feature of 7SJ64 usually cooperates with the integrated automaticreclosing system and the control function. It is also possible to employ an external au-tomatic reclosing system. In such a case signal exchange between the devices is ac-complished via binary inputs and outputs.

Busbar

7SJ64

V4

VaVbVc

V1

V2

3

1

Infeed

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Figure 2-75 Bus coupler

Operating Modes The synchronizing function can be operated in two modes:

• Synchrocheck

• Synchron/Asynchron

Synchronous power systems exhibit small differences regarding phase angle and volt-age modulus. The operating time of the circuit breaker doesn’t have to be taken intoaccount. The SYNCHROCHECK mode is used which corresponds to the classic synch-rocheck function.

To the contrary, asynchronous systems include bigger differences and the time win-dow for switching on is passed more quickly. It is reasonable to consider the operatingtime of the circuit breaker. The ASYN/SYNCHRON mode is used.

FunctionalSequence

The synchronizing function only opperates if it receives a measurement request. Thisrequest may be issued by the control, the automatic reclosing function or externallyvia binary input e.g., from an external automatic reclosing system.

The measurement request initiates the measurement (message “25x meas.“; withx = 1..4, according to the function group). Depending on the selected operating mode,the configured release conditions are then checked (see side titles “Synchrocheck“ /„Synchronous/ Asynchronous“).

Each condition is indicated explicitely ( messages “25 Vdiff ok“, “25 fdiff ok“,“25 adiff ok“); also those conditions that are not fulfilled if, for example, voltagedifferences (messages “25 V2>V1”, “25 V2<V1”), frequency differences (messages“25 f2>f1”, “25 f2<f1”) or angle differences (messages “25 a2>a1”, “25 a2<a1”) areoutside the threshold values. For these messages to be sent, both voltages must liewithin the operating range of the synchronizing function (see side title “OperatingRange”).

These conditions met, the synchronizing function issues a release signal for closingthe relay (“25 CloseRelease“). This release signal is generally processed by the

7SJ64

V4

VaVbVc

V1

V2

13

Busbar 1

Busbar 2

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control which issues the actual close command for controlling the circuit breaker (seealso side title “Interaction with the Control”).

Measuring the synchronism conditions can be confined to the a maximum monitoringtime T-SYN. DURATION. If the conditions are not fulfilled during T-SYN. DURATION,the release is cancelled (message “25 MonTimeExc“). A new synchronization canonly be performed if a new measurement request is received.

Operating Range The operating range of the synchronizing function is defined by the configured voltagethresholds Vmin and Vmax, and the fixed frequency band fN ± 3 Hz.

If measurement is started and one or both voltages are outside the operating range,or one voltage leaves the permissible range, corresponding messages indicate thisbehavior (“25 f1>>“, “25 f1<<“, “25 V1>>“, “25 V1<<“, etc.).

Synchrocheck Synchrocheck verifies the synchronism before connecting the two system compo-nents and cancels the connecting process if parameters for synchronism lie outsidethe configured thresholds.

Before a release is granted, the following conditions are checked:

− Is the reference voltage V1 above the value Vmin but below the maximum voltageVmax?

− Is the voltage V2 to be synchronized above the setting value Vmin but below themaximum voltage Vmax?

− Is the voltage difference V2 – V1 within the permitted threshold dV ASYN V2>V1?

− Is the voltage difference V1 – V2 within the permitted threshold dV ASYN V2<V1?

− Are the two frequencies f1 and f2 within the permitted operating range fN ± 3 Hz?

− Is the frequency difference f2 – f1 within the permitted threshold df ASYN f2>f1?

− Is the frequency difference f1 – f2 within the permitted threshold df ASYN f2<f1?

− Is the angle difference ϕ2 – ϕ1 within the permitted threshold da SYNC a2> a1?

− Is the angle difference ϕ1 – ϕ2 within the permitted thresholdda SYNC a2< a1?

Synchronous/Asynchronous

The operating mode “Synchronous/Asynchronous“ uses the frequency slip of the twopower systems (parameter F SYNCHRON) to determine whether the to power systemsare asynchronous to each other (“Switching under Asynchronous System Conditions“)or synchronous (“Switching under Synchronous System Conditions“). If they are asyn-chronous, the time window for switching is passed relatively quickly. Therefore, it isreasonable to take into account the operating time of the circuit breaker. Thus the de-vice can issue the On command at a time where asynchronous conditions prevail.When the poles make contact the conditions will be synchronous.

It is thus possible to generally account for the operating time of the circuit breaker i.e.,also with synchronous conditions prevailing.

Switching underSynchronous Sys-tem Conditions

Switching under synchronous conditions means that the On command will be releasedas soon as the characteristic data (voltage difference, angle difference) are within thethresholds specified by configuration.

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Before granting a release for closing under synchronous conditions, the following con-ditions are checked:

− Is the reference voltage V1 above the setting value Vmin but below the maximumvoltage Vmax?

− Is the voltage V2 to be synchronized above the setting value Vmin but below themaximum voltage Vmax?

− Is the voltage difference V2 – V1 within the permitted threshold dV ASYN V2>V1?

− Is the voltage difference V1 – V2 within the permitted threshold dV ASYN V2<V1?

− Are the two frequencies f1 and f2 within the permitted operating range fN ± 3 Hz?

− Is the frequency difference smaller than the configured threshold frequency differ-ence F SYNCHRON which defines the transition from synchronous to asynchronoussystems.

− Is the angle difference ϕ2 – ϕ1 within the permitted threshold da SYNC a2> a1?

− Is the angle difference ϕ1 – ϕ2 within the permitted threshold da SYNC a2< a1?

All synchronism conditions fulfilled, the message “25 Synchron” is issued.

Switching underAsynchronousSystem Conditions

For switching under asynchronous system conditions the device determines the timefor issuing the On command from the angle difference and the frequency differencesuch that the voltages (of busbar and feeder) are identical the instant the poles makecontact. For this purpose the device must be informed on the operating time of the cir-cuit breaker for closing.

Before granting a release for closing, the following conditions are checked:

− Is the reference voltage V1 above the setting value Vmin but below the maximumvoltage Vmax?

− Is the voltage V2 to be synchronized above the setting value Vmin but below themaximum voltage Vmax?

− Is the voltage difference V2 – V1 within the permitted threshold dV ASYN V2>V1?

− Is the voltage difference V1 – V2 within the permitted threshold dV ASYN V2<V1?

− Are the two frequencies f1 and f2 within the permitted operating range fN ± 3 Hz?

− Is the frequeny difference f2 – f1 within the permitted threshold df ASYN f2>f1?

− Is the frequeny difference f1 – f2 within the permitted threshold df ASYN f2<f1?

When the check has been terminated successfully, the device determines the nextsynchronizing time from the angle difference and the frequency difference. The Oncommand is issued at synchronization time minus operating time of the circuit breaker.

De-energizedSwitching

Connecting two components of a power system is also possible if at least one of thecomponents is de-energized. Besides release under synchronous conditions, the fol-lowing additional release conditions can be selected for the check:

− SYNC V1>V2< = Release of the condition that component V1 is energizedand component V2 is de-energized.

− SYNC V1<V2> = Release of the condition stating that component V1 is de-energized and component V2 is energized.

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− SYNC V1<V2< = Release of the condition stating that component V1 andcomponent V2 are de-energized.

Each of these conditions can be enabled or disabled individually; combinations arealso possible (e.g., release if SYNC V1>V2< or SYNC V1<V2> are fulfilled).

The release conditions can be configured individually either for automatic reclosing orfor manual closing. You can for example allow manual closing for synchronism or forde-energized feeder whereas before an automatic reclosing operation, checking onlyde-energized conditions at one feeder terminal and afterwards only synchronism atthe other.

The threshold below which a power system component is considered as de-energizedis defined by parameter V<. If the measured voltage exceeds the threshold V>, it isenergized.

Before granting a release for connecting the energized component V1 and the off-cir-cuit component V2, the following conditions are checked:

− Is the reference voltage V1 above thesetting value Vmin and V> but below the max-imum voltage Vmax?

− Is the voltage to be synchronized V2 below the threshold V<?

− Is the frequeny f1 within the permitted operating range fN ± 3 Hz?

After successful termination of the check the release is granted.

Switching the de-energized component 1 to the energized component 2 or connectingthe de-energized component 1 to the equally de-energized component 2 the condi-tions to be fulfilled are the same.

The associated messages indicating the release via the corresponding condition areas follows: “25 V1< V2>”, “25 V1> V2<” and “25 V1< V2<”.

Via binary input “>25 V1>V2<”, “>25 V1<V2>” and “>25 V1<V2<” release condi-tions can be issued externally provided the synchronization is controlled externally.

Parameter TSUP VOLTAGE (address 6x11A) can be set to configure a monitoring timewhich requires above stated release conditions to be at least fulfilled for de-energizedconnection before switching is allowed.

Direct Command/Blocking

Parameter Direct CO can be set to grant a release without performing any checks.In this case switching is released by activating the allocated binary input “>25direct CO”. It is obviously not reasonable to combine Direct CO with other release condi-tions.

Blocking the entire synchronizing function is possible via the binary input “>BLK 25 CLOSE”. This status is indicated via “25 CLOSE BLK”.

SYNC FunctionGroups

The 7SJ64 relay comprises 4 synchronizing function groups (Function group 1 to 4)which each contain all setting parameters for one synchronizer. This includes theswitchgear component for which the synchronization settings are to be applied. If noswitchgear component is unambiguously identified here, the synchronizing functionmay be used as external synchronizing feature which must be triggered by binary in-put messages. Allocation of switchgear component and function group is accom-plished using one of the binary inputs “>25-1 act” to “>25-4 act”.

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Selecting one SYNC function group several times, causes output of error message(“25 FG-Error”).

Interaction with theControl

Basically, the synchronizing feature interacts with the device control. The switchgearcomponent to be synchronized is selected via a parameter. If an On-command is is-sued, the control accounts for the fact that the switchgear component requires syn-chronization. The control sends a measurement request (“>25 Measu. Only”) to thesynchronizing function which is then started. Having completed the check, the syn-chronizing function issues the release message (“25 CloseRelease“) to which thecontrol responds by terminating the switching operation positively or negatively (seeFigure 2-76).

Figure 2-76 Interaction of control and synchronizing function

Interaction withAutomaticReclosing

IThe automatic reclosing function can also interact with the synchronizing function.They are linked via the device control. The selection is made via parameters of the au-tomatic reclosing function. Thereby you can determine which switch is activated andwhich function group (FG) is used. If no function group is entered, the close commandof the auto reclose function is carried out in unsychronized form. Equally, the com-mand “79 Close” (message 02851) allows only unsynchronized switching.

If the circuit breaker Q0 is configured as switching component, a close command ofthe automatic reclosing function will address this breaker and assign it a close com-mand which will be processed by the control. As this breaker requires synchronization,the control launches the synchronizing function and awaits release. The configuredconditions fulfilled, the release is granted and the control issues the close command(see Figure 2-77).

Close command(Remote / Local) Synchronizing function

SYNC–FG1

SYNC–FG2

SYNC–FG4

Control Meas. request

Release

SwitchgearcomponentQ0

SYNC–FG3

Q0

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Figure 2-77 Connection of the automatic reclosing function to the synchronizing function

Interaction withExternal Control

As another option the synchronizing function can be activated via external measure-ment request. The synchronizing function can be started via binary input using a mea-surement request (“>25 Measu. Only” or “>25 Start” and “>25 Stop”).

After the synchronizing function has completed the check, issues a release message(“25 CloseRelease“, see Figure 2-78).

Figure 2-78 Interaction of synchronizing functionand external control

Measured Values The measured values of the synchronizing function are displayed in separate boxesfor primary and secondary measured values and percentages. The measured values

79 /SYNC FG2 → Q0 Synchronizing function

SYNC–FG1

SYNC–FG4

Control Meas. request

Release

Switchgearcomponent Q0

SYNC–FG2

SYNC–FG3

AWE → Q0

“79 Close”(always asyn-chronized)

Synchronizing function 7SJ64

SYNC–FG1

SYNC–FG2

SYNC–FG4

ext. measurement request

ReleaseSYNC–FG3

Q0

(via:“>25 Measu. Only” or“>25 Start” and“>25 Stop”)

(“25 CloseRelease”)

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are displayed and updated only while a synchronizing function is being called. The fol-lowing values are displayed:

− value of the reference voltage V1

− value of the voltage to be synchronized V2

− Frequency values f1 and f2

− Differences of voltage, frequency and angle.

The models featuring a four-line display have a preset default display which shows theabove mentioned measured values comprised on one display (see Figure A-75 of theAppendix A.4.5).

2.16.2 Functional Settings

General The synchronizing function is only included in the 7SJ64 relay with its 4 voltage inputs.

While setting the power system data (see Subsection 2.1.3) the device was alreadyprovided with data relevant for the measured values and the operating principle of thesynchronizing function. This concerns the following parameters:

0202 Vnom PRIMARY primary nominal voltage of the voltage transformers V1(phase-to-phase) in kV;

0203 Vnom SECONDARY secondary nominal voltage of the voltage transformersV1 (phase-to-phase) in V;

0213 VT Connection determines how voltage transformers are connected;

0214 Rated Frequency the operating range of the synchronizing function refersto the rated frequency of the power system (fN ± 3 Hz);

The synchronizing function can only operate if enabled under at least one of the ad-dresses 0161 25 Function 1 through 0164 25 Function 4 during configura-tion of the functional scope (see Subsection 2.1.1). The operating mode can be pre-selected: ASYN/SYNCHRON means that switching will take place under synchronousand asynchronous conditions. SYNCHROCHECK corresponds to the classic synchro-check function. If not required, this function is set to Disabled. A synchronizing func-tion group thus rendered ineffective is hidden at the menu item Synchronization,all others are shown.

Only the corresponding messages of Function Group 1 are pre-allocated for IEC60870–5–103 (VDEW). If other function groups (2 to 4) are configured and if their mes-sages are to be disposed of via VDEW, the must first be configured to the the systeminterface.

Selecting one of the displayed SYNC function groups in DIGSI® 4 opens a dialog boxwith the tabs “General”, “Power System Data”, “Asynchronous Conditions”, “Synchro-nous Conditions” and “Synchrocheck” in which the individual settings for synchroniza-tion can be made. For SYNC function group x the following holds:

2.16.2.1 General Settings

The general thresholds for the synchronizing function are set at addresses 6x01through 6x12.

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Address 6x01 Synchronizing X can be set to switch the entire synchronous func-tion group x ON or OFF. If switched off, the synchronous check does not verify the syn-chronizing conditions and release is not granted.

Address 6x02 SyncCB is used to select the switchgear component to which the syn-chronizing settings will be applied. Select the option none to use the function as ex-ternal synchronizing feature. It will then be triggered via binary input messages.

Addresses 6x03 Vmin and 6x04 Vmax set the upper and lower limits for the requestband for voltages V1 or V2 and thus determine the operating range for the synchro-nizing function. If the values leave this band, a message will be output.

Address 6x05 V< indicates the voltage threshold below which the feeder or the bus-bar can safely be considered switched off (for checking a de-energized feeder or bus-bar).

Address 6x06 V> indicates the voltage threshold above which the feeder or busbarcan safely be considered energized (for checking an energized feeder or busbar). Itmust be set below the anticipated operational undervoltage.

The setting for the mentioned voltage values is made secondary in volts. When usingthe PC and DIGSI® 4 for configuration, these values can also be entered as primaryvalues. Depending on the connection of the voltages these are phase-ground voltagesor phase-phase voltages.

Addresses 6x07 to 6x10 are set to specify the release conditions for the closingcheck:

6x07 SYNC V1<V2> = Component V1 must be de-energized, componentV2 must be energized (connection to reference withoutvoltage, dead line);

6x08 SYNC V1>V2< = Component V1 must be energized, componentV2 must be de-energized (connection to feeder withoutvoltage, dead bus);

6x09 SYNC V1<V2< = Both V1 and V2 must be without voltage (connectionreference and feeder without voltage, dead bus/deadbus);

6x10A Direct CO = Command is released without checks.

The possible release conditions are independent of each other and can be combined.

Parameter TSUP VOLTAGE (address 6x11A) can be used to set a monitoring timewhich requires above mentioned additional release conditions to be fulfilled at leastbefore release is granted for switching without voltage The preset value of 0.1 s ac-counts for transient responses and can be applied without modification.

Release via synchronous check can be limited to a configurable synchronous moni-toring time T-SYN. DURATION (address 6x12). The configured conditions must befulfilled within this time or release is not granted and the synchronizing function isshed. If this time is set to ∞, the conditions will be checked until they are fulfilled.

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2.16.2.2 Power System Data

The power system data for the synchronizing function are set at addresses 6x20through 6x25.

The circuit breaker closing time T-CB close at address 6x20 is required if the deviceis to close also under asynchronous system conditions, no matter whether for manualclosing, for automatic reclosing after three-pole tripping, or for both. The device willthen calculate the time for the close command such that the voltages are synchronousthe instant the breaker poles make contact. Please note this includes the operatingtime of the breaker and also the pickup time of an auxiliary relay that may be connect-ed on line side.

The parameter Balancing V1/V2 (adress 6x21) can be set to account for differentCT ratios of the two parts of the power system (see example in Figure 2-79).

If a transformer is located between the system parts to be synchronized, its vectorgroup can be accounted for by angle adjustment so that no external adjusting mea-sures are required. Parameter ANGLE ADJUSTM. (address 6x22A) is used to thisend.

• The phase angle from V1 to V2 is evaluated positively.

Example (see also Figure 2-79):Busbar 400 kV primary

100 VsecondaryFeeder 220 kVprimary

110 VsecondaryTransformer 400 kV/220 kV

Vector group Dy(n) 5The transformer vector group is defined from the high side to the low side. In the ex-ample, the reference voltage transformers (V1) are the ones of the transformer highside of i.e., the angle 5 x 30° (according to vector group) that is 150°:Address 6x22A: ANGLE ADJUSTM. = 150°.

The reference voltage transformers supply 100 V secondary for primary operation atnominal value while the feeder transformer supplies 110 V secondary. Therefore, thisdifference must be balanced:Address 6x21: Balancing V1/V2 = 100 V/110 V = 0.91.

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Figure 2-79 Busbar voltage measured via transformer

Connections 7SJ64 provides three voltage inputs for connection of the voltage V1 and one voltageinput for voltage V2 (see Figure 2-80 and Figure 2-79). According to definition, thethree-phase voltage is the reference voltage V1. To compare the three-phase voltageV1 and the voltage V2 correctly with each other, the device must be informed on theconnection type of the voltage V2. Address CONNECTIONof V2 assumes this task(parameter 6x23).

Figure 2-80 Connection of V1 and V2 at device

For the device to perform the internal conversion to primary values, the primary ratedtransformer voltage of the measured quantity V2 must be entered via parameter 6x25 VT Vn2, primary if a transformer is located between the system parts to be syn-chronized.

L1

L2

L3

UL1

UL2

UL3

(any voltage)

U2

Feeder

Busbar

Dy5

400 kV

220 kV

400 kV/220 kV

400 kV/100 V

220 kV

110 V

VT Connection = Van,Vbn,Vcn,VSyCONNECTIONof V2 = A-BANGLE ADJUSTM. = 150°Balancing V1/V2 = 0.91

U1

A B C

R13R14

V4

R15R17

va

R18Vb

R16Vc

Voltage V1

Voltage V2

7SJ64

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2.16.2.3 Asynchronous Conditions

The synchronizing function 7SJ64 can issue a close command also for asynchronouspower systems such that, considering the circuit breaker operating time (address6x20), the power systems are coupled when the phases are equal.

Parameters 6x30 dV ASYN V2>V1 and 6x31 dV ASYN V2<V1 can be set to adjustthe permissible voltage differences asymmetrically.

Parameters 6x32 df ASYN f2>f1 and 6x33 df ASYN f2<f1 limit the operatingrange for asynchronous switching. These two parameters enable an asymmetricalswitching range to be set.

2.16.2.4 Synchronous Conditions

Address 6x40 SYNC PERMIS. activates or deactivate the connection under synchro-nous system conditions (YES) or (NO).

Address 6x41 F SYNCHRON is an automatic threshold between synchronous andasynchronous switching. If the frequency difference is below the specified threshold,the power systems are considered synchronous and the conditions for synchronousswitching apply. If it is above the threshold, the switching is asynchronous and the an-ticipated in-phase time is calculated.

Address 6x42 dV SYNC V2>V1 and 6x43 dV SYNC V2<V1 can be used to set thepermissible voltage differences asymmetrically.

Address 6x44 da SYNC a2> a1 and 6x45 da SYNC a2< a1 confine the operatingrange for synchronous switching. These two parameters allow an asymmetricalswitching range to be configured (see Figure 2-81).

Moreover, the release time delay T SYNC-DELAY (address 6x46) can be set for whichall synchronous conditions must at least be fulfilled for the closing command to be gen-erated after expiration of this time.

Figure 2-81 Switching under synchronous system conditions

Im

Re

6x44

6x45

U1

U2

6x42

6x43

Frequency difference < Parameter 6x41

Switch-on range

dV SYNC V2>V1

dV SYNC V2<V1 da SYNC a2> a1

da SYNC a2< a1

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Figure 2-82 Operating range under synchronous and asynchronous conditions for voltage(V) and frequency (f)

2.16.2.5 Synchrocheck

Address 6x50 dV SYNCHK V2>V1 and 6x51 dV SYNCHK V2<V1 can be used toconfigure the permitted voltage difference also asymmetrically. The availability of twoparameters enables an asymmetrical switch-on range to be set.

Address 6x52 df SYNCHK f2>f1 and 6x53 df SYNCHK f2<f1 determine thepermissible frequency differences. The availability of two parameters enables anasymmetrical switch-on range to be set.

Addresses 6x54 da SYNCHK a2>a1 and 6x55 da SYNCHK a2<a1 confine theoperating range for synchronous switching. The availability of two parameters enablesan asymmetrical switch-on range to be set.

2.16.3 Settings

6x42 U

f

6x30

6x31

6x43

6x33

6x41

6x32

synchronous operating rangeasynchronous operating range

df ASYN f2>f1

dV SYNC V2>V1

dV ASYN V2>V1

F SYNCHRON

df ASYN f2<f1

dV ASYN V2<V1

dV SYNC V2<V1

Addr. Setting Title Setting Options Default Setting Comments

6x01 Synchronizing ONOFF

OFF Synchronizing Function

6x02 SyncCB Synchronizable circuit breaker

6x03 Vmin 20..125 V 90 V Minimum voltage limit: Vmin

6x04 Vmax 20..140 V 110 V Maximum voltage limit: Vmax

6x05 V< 1..60 V 5 V Threshold V1, V2 withoutvoltage

6x06 V> 20..140 V 80 V Threshold V1, V2 with voltage

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6x07 SYNC V1<V2> YESNO

NO ON-Command at V1< and V2>

6x08 SYNC V1>V2< YESNO

NO ON-Command at V1> and V2<

6x09 SYNC V1<V2< YESNO

NO ON-Command at V1< and V2>

6x10A Direct CO YESNO

NO Direct ON-Command

6x11A TSUP VOLTAGE 0.0..60.0 sec 0.1 sec Supervision time of V1>;V2> orV1<;V2<

6x12 T-SYN. DURATION 0.01..1200.00 sec; ∞ 30.00 sec Maximum duration of Synchroni-zation

6x20 T-CB close 0.01..0.60 sec 0.06 sec Closing (operating) time of CB

6x21 Balancing V1/V2 0.50..2.00 1.00 Balancing factor V1/V2

6x22A ANGLE ADJUSTM. 0..360 ° 0 ° Angle adjustment (transformer)

6x23 CONNECTIONof V2 A-GB-GC-GA-BB-CC-A

A-B Connection of V2

6x25 VT Vn2, primary 0.10..800.00 kV 12.00 kV VT nominal voltage V2, primary

6x30 dV ASYN V2>V1 0.5..40.0 V 2.0 V Maximum voltage differenceV2>V1

6x31 dV ASYN V2<V1 0.5..40.0 V 2.0 V Maximum voltage differenceV2<V1

6x32 df ASYN f2>f1 0.01..2.00 Hz 0.10 Hz Maximum frequency differencef2>f1

6x33 df ASYN f2<f1 0.01..2.00 Hz 0.10 Hz Maximum frequency differencef2<f1

6x40 SYNC PERMIS. YESNO

YES Switching at synchronous condi-tions

6x41 F SYNCHRON 0.01..0.04 Hz 0.01 Hz Frequency threshold ASYN <-->SYN

6x42 dV SYNC V2>V1 0.5..40.0 V 5.0 V Maximum voltage differenceV2>V1

6x43 dV SYNC V2<V1 0.5..40.0 V 5.0 V Maximum voltage differenceV2<V1

6x44 dα SYNC α2> α1 2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6x45 dα SYNC α2< α1 2..80 ° 10 ° Maximum angle differencealpha2<alpha1

Addr. Setting Title Setting Options Default Setting Comments

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2.16.4 List of Information

The following table lists the alarms of SYNC function group 1. Alarms of functiongroups 2 to 4 are nearly the same, only their group number is different.

6x46 T SYNC-DELAY 0.00..60.00 sec 0.00 sec Release delay at synchronousconditions

6x50 dV SYNCHK V2>V1 0.5..40.0 V 5.0 V Maximum voltage differenceV2>V1

6x51 dV SYNCHK V2<V1 0.5..40.0 V 5.0 V Maximum voltage differenceV2<V1

6x52 df SYNCHK f2>f1 0.01..2.00 Hz 0.10 Hz Maximum frequency differencef2>f1

6x53 df SYNCHK f2<f1 0.01..2.00 Hz 0.10 Hz Maximum frequency differencef2<f1

6x54 dα SYNCHK α2>α1 2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6x55 dα SYNCHK α2<α1 2..80 ° 10 ° Maximum angle differencealpha2<alpha1

Addr. Setting Title Setting Options Default Setting Comments

F.No. Alarm Comments

170.0001 >25-1 act >25-group 1 activate

170.2008 >BLK 25-1 >BLOCK 25-group 1

170.2102 >BLK 25 CLOSE >BLOCK 25 CLOSE command

170.2009 >25direct CO >25 Direct Command output

170.0043 >25 Measu. Only >25 Sync. Measurement Only

170.2011 >25 Start >25 Start of synchronization

170.2012 >25 Stop >25 Stop of synchronization

170.2013 >25 V1>V2< >25 Switch to V1> and V2<

170.2014 >25 V1<V2> >25 Switch to V1< and V2>

170.2015 >25 V1<V2< >25 Switch to V1< and V2<

170.2007 25 Measu. req. 25 Sync. Measuring request of Control

170.0049 25 CloseRelease 25 Sync. Release of CLOSE Command

170.0050 25 Sync. Error 25 Synchronization Error

170.2022 25-1 meas. 25-group 1: measurement in progress

170.0051 25-1 BLOCK 25-group 1 is BLOCKED

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170.2103 25 CLOSE BLK 25 CLOSE command is BLOCKED

170.2101 25-1 OFF Sync-group 1 is switched OFF

170.2025 25 MonTimeExc 25 Monitoring time exceeded

170.2026 25 Synchron 25 Synchronization conditions okay

170.2027 25 V1< V2> 25 Condition V1<V2> fulfilled

170.2028 25 V1> V2< 25 Condition V1>V2< fulfilled

170.2029 25 V1< V2< 25 Condition V1<V2< fulfilled

170.2030 25 Vdiff ok 25 Voltage difference (Vdiff) okay

170.2031 25 fdiff ok 25 Frequency difference (fdiff) okay

170.2032 25 αdiff ok 25 Angle difference (alphadiff) okay

170.2033 25 f1>> 25 Frequency f1 > fmax permissible

170.2034 25 f1<< 25 Frequency f1 < fmin permissible

170.2035 25 f2>> 25 Frequency f2 > fmax permissible

170.2036 25 f2<< 25 Frequency f2 < fmin permissible

170.2037 25 V1>> 25 Voltage V1 > Umax permissible

170.2038 25 V1<< 25 Voltage V1 < Umin permissible

170.2039 25 V2>> 25 Voltage V2 > Umax permissible

170.2040 25 V2<< 25 Voltage V2 < Umin permissible

170.2090 25 V2>V1 25 Vdiff too large (V2>V1)

170.2091 25 V2<V1 25 Vdiff too large (V2<V1)

170.2092 25 f2>f1 25 fdiff too large (f2>f1)

170.2093 25 f2<f1 25 fdiff too large (f2<f1)

170.2094 25 α2>α1 25 alphadiff too large (a2>a1)

170.2095 25 α2<α1 25 alphadiff too large (a2<a1)

170.2096 25 FG-Error 25 Multiple selection of func-groups

170.2097 25 Set-Error 25 Setting error

170.2050 V1 = V1 =

170.2051 f1 = f1 =

170.2052 V2 = V2 =

170.2053 f2 = f2 =

170.2054 dV = dV =

170.2055 df = df =

170.2056 dα = dalpha =

F.No. Alarm Comments

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2.17 Temperature Detection via RTD-boxes

Up to two temperature detection units (RTD-boxes) with 12 measuring sensors in totalcan be applied for temperature detection and are recognized by the device. In partic-ular they enable the thermal status of motors, generators and transformers to be mon-itored. Rotating machines are additionally monitored for a violation of the bearing tem-perature thresolds. The temperatures are measured in different locations of the pro-tected object by employing temperature sensors (RTD = Resistance Temperature De-tector) and are transmitted to the device via one or two RTD-boxes 7XV566.

Interaction with theOverloadProtection

The ambient temperature or coolant temperature can be transmitted to the overloadprotection of the device via the RTD-box. The temperature detector required for thispurpose must be connected to the detector input 1 of the first RTD-box (correspondsto RTD 1).

2.17.1 Functional Description

RTD-box 7XV56 The RTD-box 7XV566 is an external unit which is mounted on the top-hat rail. It fea-tures 6 temperature detectors and one RS485 interface for communication with theprotection device. The RTD-box detects the coolant temperature of each measuringpoint from the resistance value of the temperature detectors (Pt100, Ni100 or Ni120)connected via a two- or three-wire lines and converts it to a digital value. The digitalvalues are held available at a serial port.

Communicationwith the ProtectionDevice

The protection device can employ up to two RTD-boxes via its service port (port C),7SJ64 also via the additional port (port D).

A maximum of 12 temperature detectors is thus available. For greater distances to theprotection device the communication via fibre optic cables is recommend. Possiblecommunication structures are shown in Appendix A.3.4.

ProcessingTemperatures

The transmitted non-linearized temperature values are converted to a temperature indegree Celsius or Fahrenheit. The conversion depends on the temperature sensorused.

For each temperature detector two thresholds decision can be performed which areavailable for further processing. The user can make the corresponding allocations inthe configuration matrix.

An alarm is issued for each temperature sensor in the event of a short-circuit or inter-ruption in the sensor circuit.

Figure 2-83 shows the logic diagram of the temperature processing.

The manual supplied with the RTD-box contains a connections diagram and dimen-sioned drawing.

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Figure 2-83 Logic diagram of the temperature processing for the RTD-box 1

2.17.2 Configuration Notes

General Temperature detection is only effective and accessible if this function was allocated toan interface during configuration of the protective functions (Subsection 2.1.1). At ad-dress 0190 RTD-BOX INPUT the RTD-box(es) is allocated to the interface at whichit will be operated (e.g. port C). The number of sensor inputs and the communicationmode were set at address 0191 RTD CONNECTION. The temperature unit (°C or °F)was set in the Power System Data 1 at address 0276 TEMP. UNIT.

Device Settings The settings are the same for each input and are here shown at the example of mea-suring input 1.

Set the type of temperature detector for RTD1 (temperature sensor for measuringpoint 1) at address 9011A RTD 1 TYPE. You can choose between Pt 100 W, Ni 120 W and Ni 100 W. If no temperature detector is available for RTD1, set RTD 1 TYPE = Not connected. This setting is only possible via DIGSI® 4 at “AdditionalSettings“.

9011A RTD 1 TYPE

FNo. 14112

Non-linear- Temperaturecalculation

9013 RTD 1 STAGE 1

RTD 1 St.1 p.up

9015 RTD 1 STAGE 2

FNo. 14113RTD 1 St.2 p.up

Moni-toring

FNo. 14111Fail: RTD 1

≥1FNo. 14101Fail: RTD

FNo. 00264Fail: RTD-Box 1

ized values

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The mounting location of RTD1 is set at address 9012A RTD 1 LOCATION. You canchoose between Oil, Ambient, Winding, Bearing and Other. This setting is onlypossible via DIGSI® 4 at “Additional Settings“.

Furthermore, you can set an alarm temperature and a tripping temperature. Depend-ingn on the temperature unit selected in Power System Data (section below address0276 TEMP. UNIT), you can enter the alarm temperature at address 9013 RTD 1 STAGE 1 in degree Celsius (°C) or in degree Fahrenheit (°F) at address 9014 RTD 1 STAGE 1. The tripping temperature is set at address 9015 RTD 1 STAGE 2 indegree Celsius (°C) or degree Fahrenheit (°F) at address 9016 RTD 1 STAGE 2.

The settings for the all other connected temperature detectors are made accordingly(see Settings 2.17.2.1).

RTD-boxSettings

If temperature detectors are used with two-wire connection, the line resistance (forshort-circuited temperature detector) must be measured and adjusted. For this pur-pose, select mode 6 in the RTD-box and enter the resistance value for the correspond-ing temperature detector (range 0 to 50.6 Ω). If a 3-wire connection is used, no furthersettings are required to this end.

A baudrate of 9600 bits/s ensures communication. Parity is even. The factory settingof the bus number 0. Modifications at the RTD-box can be made in mode 7. The fol-lowing convention applies:

Further information is provided in the operating manual of the RTD-box.

ProcessingMeasured Valuesand Messages

The RTD-box is visible in DIGSI® 4 as part of the 7SJ62/63/64 relays i.e., messagesand measured values are displayed in the configuration matrix besides the internalfunctions and like them they can be masked and processed. Messages and measuredvalues can thus be forwarded to the integrated user-defined logic (CFC) and intercon-nected as desired.

If it is desired that a message should appear in the event buffer, a cross must be en-tered in the intersecting box of column/row.

Table 2-19 Setting the bus address at the RTD-box

Mode Number of RTD-boxes Address

simplex 1 0

half duplex 1 1

half duplex 21st RTD-box: 1

2nd RTD-box: 2

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2.17.2.1 Settings

Addr. Setting Title Setting Options Default Setting Comments

9011A RTD 1 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

Pt 100 Ohm RTD 1: Type

9012A RTD 1 LOCATION OilAmbientWindingBearingOther

Oil RTD 1: Location

9013 RTD 1 STAGE 1 -50..250 °C; ∞ 100 °C RTD 1: Temperature Stage 1Pickup

9014 RTD 1 STAGE 1 -58..482 °F; ∞ 212 °F RTD 1: Temperature Stage 1Pickup

9015 RTD 1 STAGE 2 -50..250 °C; ∞ 120 °C RTD 1: Temperature Stage 2Pickup

9016 RTD 1 STAGE 2 -58..482 °F; ∞ 248 °F RTD 1: Temperature Stage 2Pickup

9021A RTD 2 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 2: Type

9022A RTD 2 LOCATION OilAmbientWindingBearingOther

Other RTD 2: Location

9023 RTD 2 STAGE 1 -50..250 °C; ∞ 100 °C RTD 2: Temperature Stage 1Pickup

9024 RTD 2 STAGE 1 -58..482 °F; ∞ 212 °F RTD 2: Temperature Stage 1Pickup

9025 RTD 2 STAGE 2 -50..250 °C; ∞ 120 °C RTD 2: Temperature Stage 2Pickup

9026 RTD 2 STAGE 2 -58..482 °F; ∞ 248 °F RTD 2: Temperature Stage 2Pickup

9031A RTD 3 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 3: Type

9032A RTD 3 LOCATION OilAmbientWindingBearingOther

Other RTD 3: Location

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9033 RTD 3 STAGE 1 -50..250 °C; ∞ 100 °C RTD 3: Temperature Stage 1Pickup

9034 RTD 3 STAGE 1 -58..482 °F; ∞ 212 °F RTD 3: Temperature Stage 1Pickup

9035 RTD 3 STAGE 2 -50..250 °C; ∞ 120 °C RTD 3: Temperature Stage 2Pickup

9036 RTD 3 STAGE 2 -58..482 °F; ∞ 248 °F RTD 3: Temperature Stage 2Pickup

9041A RTD 4 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 4: Type

9042A RTD 4 LOCATION OilAmbientWindingBearingOther

Other RTD 4: Location

9043 RTD 4 STAGE 1 -50..250 °C; ∞ 100 °C RTD 4: Temperature Stage 1Pickup

9044 RTD 4 STAGE 1 -58..482 °F; ∞ 212 °F RTD 4: Temperature Stage 1Pickup

9045 RTD 4 STAGE 2 -50..250 °C; ∞ 120 °C RTD 4: Temperature Stage 2Pickup

9046 RTD 4 STAGE 2 -58..482 °F; ∞ 248 °F RTD 4: Temperature Stage 2Pickup

9051A RTD 5 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 5: Type

9052A RTD 5 LOCATION OilAmbientWindingBearingOther

Other RTD 5: Location

9053 RTD 5 STAGE 1 -50..250 °C; ∞ 100 °C RTD 5: Temperature Stage 1Pickup

9054 RTD 5 STAGE 1 -58..482 °F; ∞ 212 °F RTD 5: Temperature Stage 1Pickup

9055 RTD 5 STAGE 2 -50..250 °C; ∞ 120 °C RTD 5: Temperature Stage 2Pickup

9056 RTD 5 STAGE 2 -58..482 °F; ∞ 248 °F RTD 5: Temperature Stage 2Pickup

9061A RTD 6 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 6: Type

Addr. Setting Title Setting Options Default Setting Comments

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9062A RTD 6 LOCATION OilAmbientWindingBearingOther

Other RTD 6: Location

9063 RTD 6 STAGE 1 -50..250 °C; ∞ 100 °C RTD 6: Temperature Stage 1Pickup

9064 RTD 6 STAGE 1 -58..482 °F; ∞ 212 °F RTD 6: Temperature Stage 1Pickup

9065 RTD 6 STAGE 2 -50..250 °C; ∞ 120 °C RTD 6: Temperature Stage 2Pickup

9066 RTD 6 STAGE 2 -58..482 °F; ∞ 248 °F RTD 6: Temperature Stage 2Pickup

9071A RTD 7 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 7: Type

9072A RTD 7 LOCATION OilAmbientWindingBearingOther

Other RTD 7: Location

9073 RTD 7 STAGE 1 -50..250 °C; ∞ 100 °C RTD 7: Temperature Stage 1Pickup

9074 RTD 7 STAGE 1 -58..482 °F; ∞ 212 °F RTD 7: Temperature Stage 1Pickup

9075 RTD 7 STAGE 2 -50..250 °C; ∞ 120 °C RTD 7: Temperature Stage 2Pickup

9076 RTD 7 STAGE 2 -58..482 °F; ∞ 248 °F RTD 7: Temperature Stage 2Pickup

9081A RTD 8 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 8: Type

9082A RTD 8 LOCATION OilAmbientWindingBearingOther

Other RTD 8: Location

9083 RTD 8 STAGE 1 -50..250 °C; ∞ 100 °C RTD 8: Temperature Stage 1Pickup

9084 RTD 8 STAGE 1 -58..482 °F; ∞ 212 °F RTD 8: Temperature Stage 1Pickup

9085 RTD 8 STAGE 2 -50..250 °C; ∞ 120 °C RTD 8: Temperature Stage 2Pickup

Addr. Setting Title Setting Options Default Setting Comments

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9086 RTD 8 STAGE 2 -58..482 °F; ∞ 248 °F RTD 8: Temperature Stage 2Pickup

9091A RTD 9 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 9: Type

9092A RTD 9 LOCATION OilAmbientWindingBearingOther

Other RTD 9: Location

9093 RTD 9 STAGE 1 -50..250 °C; ∞ 100 °C RTD 9: Temperature Stage 1Pickup

9094 RTD 9 STAGE 1 -58..482 °F; ∞ 212 °F RTD 9: Temperature Stage 1Pickup

9095 RTD 9 STAGE 2 -50..250 °C; ∞ 120 °C RTD 9: Temperature Stage 2Pickup

9096 RTD 9 STAGE 2 -58..482 °F; ∞ 248 °F RTD 9: Temperature Stage 2Pickup

9101A RTD10 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD10: Type

9102A RTD10 LOCATION OilAmbientWindingBearingOther

Other RTD10: Location

9103 RTD10 STAGE 1 -50..250 °C; ∞ 100 °C RTD10: Temperature Stage 1Pickup

9104 RTD10 STAGE 1 -58..482 °F; ∞ 212 °F RTD10: Temperature Stage 1Pickup

9105 RTD10 STAGE 2 -50..250 °C; ∞ 120 °C RTD10: Temperature Stage 2Pickup

9106 RTD10 STAGE 2 -58..482 °F; ∞ 248 °F RTD10: Temperature Stage 2Pickup

9111A RTD11 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD11: Type

9112A RTD11 LOCATION OilAmbientWindingBearingOther

Other RTD11: Location

9113 RTD11 STAGE 1 -50..250 °C; ∞ 100 °C RTD11: Temperature Stage 1Pickup

Addr. Setting Title Setting Options Default Setting Comments

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2.17.2.2 List of Information

Note: Further alarms regarding thresholds of the individual temperature detectors are available at the RTD-boxfor output via relay contacts.

9114 RTD11 STAGE 1 -58..482 °F; ∞ 212 °F RTD11: Temperature Stage 1Pickup

9115 RTD11 STAGE 2 -50..250 °C; ∞ 120 °C RTD11: Temperature Stage 2Pickup

9116 RTD11 STAGE 2 -58..482 °F; ∞ 248 °F RTD11: Temperature Stage 2Pickup

9121A RTD12 TYPE not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD12: Type

9122A RTD12 LOCATION OilAmbientWindingBearingOther

Other RTD12: Location

9123 RTD12 STAGE 1 -50..250 °C; ∞ 100 °C RTD12: Temperature Stage 1Pickup

9124 RTD12 STAGE 1 -58..482 °F; ∞ 212 °F RTD12: Temperature Stage 1Pickup

9125 RTD12 STAGE 2 -50..250 °C; ∞ 120 °C RTD12: Temperature Stage 2Pickup

9126 RTD12 STAGE 2 -58..482 °F; ∞ 248 °F RTD12: Temperature Stage 2Pickup

F.No. Alarm Comments

00264 Fail: RTD-Box 1 Failure: RTD-Box 1

14101 Fail: RTD Fail: RTD (broken wire/shorted)

14111 Fail: RTD 1 Fail: RTD 1 (broken wire/shorted)

14112 RTD 1 St.1 p.up RTD 1 Temperature stage 1 picked up

14113 RTD 1 St.2 p.up RTD 1 Temperature stage 2 picked up

14121 Fail: RTD 2 Fail: RTD 2 (broken wire/shorted)

14122 RTD 2 St.1 p.up RTD 2 Temperature stage 1 picked up

14123 RTD 2 St.2 p.up RTD 2 Temperature stage 2 picked up

14131 Fail: RTD 3 Fail: RTD 3 (broken wire/shorted)

14132 RTD 3 St.1 p.up RTD 3 Temperature stage 1 picked up

14133 RTD 3 St.2 p.up RTD 3 Temperature stage 2 picked up

14141 Fail: RTD 4 Fail: RTD 4 (broken wire/shorted)

Addr. Setting Title Setting Options Default Setting Comments

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14142 RTD 4 St.1 p.up RTD 4 Temperature stage 1 picked up

14143 RTD 4 St.2 p.up RTD 4 Temperature stage 2 picked up

14151 Fail: RTD 5 Fail: RTD 5 (broken wire/shorted)

14152 RTD 5 St.1 p.up RTD 5 Temperature stage 1 picked up

14153 RTD 5 St.2 p.up RTD 5 Temperature stage 2 picked up

14161 Fail: RTD 6 Fail: RTD 6 (broken wire/shorted)

14162 RTD 6 St.1 p.up RTD 6 Temperature stage 1 picked up

14163 RTD 6 St.2 p.up RTD 6 Temperature stage 2 picked up

00267 Fail: RTD-Box 2 Failure: RTD-Box 2

14171 Fail: RTD 7 Fail: RTD 7 (broken wire/shorted)

14172 RTD 7 St.1 p.up RTD 7 Temperature stage 1 picked up

14173 RTD 7 St.2 p.up RTD 7 Temperature stage 2 picked up

14181 Fail: RTD 8 Fail: RTD 8 (broken wire/shorted)

14182 RTD 8 St.1 p.up RTD 8 Temperature stage 1 picked up

14183 RTD 8 St.2 p.up RTD 8 Temperature stage 2 picked up

14191 Fail: RTD 9 Fail: RTD 9 (broken wire/shorted)

14192 RTD 9 St.1 p.up RTD 9 Temperature stage 1 picked up

14193 RTD 9 St.2 p.up RTD 9 Temperature stage 2 picked up

14201 Fail: RTD10 Fail: RTD10 (broken wire/shorted)

14202 RTD10 St.1 p.up RTD10 Temperature stage 1 picked up

14203 RTD10 St.2 p.up RTD10 Temperature stage 2 picked up

14211 Fail: RTD11 Fail: RTD11 (broken wire/shorted)

14212 RTD11 St.1 p.up RTD11 Temperature stage 1 picked up

14213 RTD11 St.2 p.up RTD11 Temperature stage 2 picked up

14221 Fail: RTD12 Fail: RTD12 (broken wire/shorted)

14222 RTD12 St.1 p.up RTD12 Temperature stage 1 picked up

14223 RTD12 St.2 p.up RTD12 Temperature stage 2 picked up

F.No. Alarm Comments

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2.18 Phase Rotation

2.18.1 Description of Phase Rotation

General Various functions of the 7SJ62/63/64 only function correctly if the phase rotation of thevoltages and currents is known. Among these functions are negative sequence pro-tection, undervoltage protection (based only on positive sequence voltages), direc-tional overcurrent protection, and measurement quantity monitors. A phase rotation isimplemented in the 7SJ62/63/64 device using binary inputs and settings, thus makingit possible for all protective and monitoring functions to operate correctly when thephase rotation is reversed.

If an “acb” phase rotationphase rotation is normal, the appropriate setting should beentered at address 0209. (See Subsection 2.1.3).

If the phase rotation can change during operation (e.g. the direction of a motor mustbe routinely changed), then a changeover signal at the input masked for this purposeis sufficient to inform the protective relay of the phase rotation changeover.

Logic As stated before, the phase rotation is always established at address 0209 PHASE SEQ.. The binary input (FNo. 05145, “>Reverse Rot.”) sets the phase rotation forthe opposite of the setting at 0209, via the exclusive-OR function (see Figure 2-84).

Figure 2-84 Message Logic for the phase rotation Changeover

Influence on Pro-tective Functions

The swapping of phases directly impacts the calculation of positive and negative se-quence quantities, as well as phase-to-phase voltages via the subtraction of onephase-to-ground voltage from another. Therefore, this function is vital so that phasedetection messages, fault values, and operating measurement values are not falsified.As stated before, this function influences the negative sequence protection function,directional overcurrent protection function, and some of the monitoring functions (seeSubsection 2.10.1.3) that issue messages if the required and calculated phase rota-tions do not match.

2.18.2 Programming Settings

The normal phase sequence is set at 0209 PHASE SEQ. (see Subsection 2.1.3).If, on the system side, phase rotation are made temporarily, then these are communi-cated to the protective device using the binary input “>Reverse Rot.”, FNo. 05145.

0209 PHASE SEQ.

>Reverse Rot..Rotation ABC

Rotation ACB

FNo. 05145

FNo. 05147

FNo. 05148

A B C

A C B„0“

„1“ Opposite Phase Sequence

To The Protective Functions

XOR

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2.19 Protection Function Logic

The function logic is the heart of the device. It coordinates the sequence of both theprotective and auxiliary functions, processes functional decisions, and processes datareceived from the system. In particular, the function logic is responsible for the follow-ing:

• Processing Measurement and Detection Logic

• Processing Tripping Logic

2.19.1 Pickup Logic for the Entire Device

General DevicePickup andDropout

The pickup signals for all protective functions in the device are connected via an “OR”function, and lead to the general device pickup. General device pickup is initiated bythe first function to pickup, and general device drop out occurs when the last functiondrops out. A corresponding message indicating that general device pickup has oc-curred is reported.

General device pickup is a precondition for a series of internal and external functionsthat occur subsequently. The following are among the internal functions controlled bygeneral device pickup:

• Start of Trip Log: From general device pickup to general device drop out, all faultmessages are entered in the trip log.

• Initialization of Oscillographic Records: The storage and maintenance of oscillo-graphic values can also be made dependent on the general device pickup.

External functions can be controlled by general device pickup, using an output con-tact. Examples are:

• Restarting devices

• Starting of additional devices, or similar

2.19.2 Tripping Logic of the Entire Device

2.19.2.1 Description

General Trip The tripping signals for all protective functions are connected by “OR” and generate amessage indicating that the device has initiated a trip signal.

This message can be configured to an LED or binary output, just as the individual trip-ping messages can.

Terminating theTripping Signal

• All trip signals from a protection function hold the 00511 “Relay TRIP” function,and start the minimum trip signal duration timer (set at address 210A TMin TRIP CMD, see Figure 2-85). This trip signal duration timer ensures the trip signal is trans-

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mitted to the circuit breaker for a sufficient amount of time, even if the function whichissued the trip signal drops out quickly. The trip signal is only terminated after allprotection functions drop out AND the minimum trip signal duration expires.

• Finally, it is possible to latch the trip signal until it is manually reset (lockout func-tion). The reset takes place either by pressing the LED reset key or by activating anappropriately masked binary input. A precondition, of course, is that the circuitbreaker trip coil – as usual – remains energized at the circuit breaker as long as thetrip signal is present, and that the trip coil current is interrupted by the auxiliary con-tacts of the circuit breaker.

Figure 2-85 Terminating the Trip Signal

2.19.2.2 Programming Settings for Tripping Logic

Trip Signal Dura-tion

The setting of the minimum trip signal duration at address 0210A TMin TRIP CMDwas already discussed in Subsection 2.1.3. This time is valid for all protective func-tions that can initiate trip signals, as well as for trip signals that are initiated using thedevice function controller.

2.19.3 Statistical Counters

2.19.3.1 Description

Number of Trips The number of trips initiated by the 7SJ62/63/64 is counted, as long as the position ofthe circuit breaker is monitored via breaker auxiliary contacts and binary inputs. Forthis purpose it is necessary to allocate the internal pulse counter “Number of TRIPs“to a binary input in the configuration matrix which is controlled by the TRIP position ofthe circuit breaker. The pulse count “Number of TRIPs“ can be found in the “Statistics“

T

S

R

Q

&

Trip

S

R

QLockout–Function(Output Relay Stored)

Lockout Reset(Using LED–Reset)

0210A TMin TRIP CMD

Relay TRIP

FNo. 000511

Fro

mP

rote

ctiv

eF

unct

ions

Addr. Setting Setting Options Default Setting Comment

210 TMin TRIP CMD 0.01 ~ 32.00 s 0.15 s Minimum Trip Command Duration

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group if the option “Measured and metered values only” was enabled in the configu-ration matrix.

Number ofAutomaticReclosingCommands

The number of reclosing commands initiated by the automatic reclosing function issummed up in separate counters for the 1st and ≥ 2nd cycle.

Fault Current Furthermore, the fault current in each pole of the circuit breaker is determined for eachtrip signal. The fault current is indicated in the fault messages and is added to previ-ously stored fault current values in the statistic-counters to maintain an accumulationof fault currents, per pole, experienced by the breaker over time.

Operating hours The operating hours under load are also stored (the current value in at least one phaseis larger than the limit value set under address 0212 BkrClosed I MIN). Thecounter and memory levels are secured against loss of auxiliary voltage.

2.19.3.2 Reading/Setting/Resetting

SIPROTEC® 4–System Manual describes how to read out the statistical counters viathe device front panel or DIGSI® 4. Setting or resetting of the statistical counters listedabove takes place under the menu item ANNUNCIATION → STATISTIC by overwrit-ing the counter values shown.

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2.20 Auxiliary Functions

The auxiliary functions of the 7SJ62/63/64 relay include:

Message Processing

Measurements

Waveform Capture

Commissioning Aids

2.20.1 Message Processing

After the occurrence of a system fault, data regarding the response of the protectiverelay and the measured quantities should be saved for future analysis. For this reasonmessage processing is done in three ways:

• LED Display and Binary Outputs (Output Relays)

• Information via Display Field or Personal Computer

• Information to a Control Center

LED Display and Bi-nary Outputs (Out-put Relays)

Important events and conditions are displayed, using LEDs on the front panel of therelay. The relay also contains output relays for remote signaling. All LEDs and binaryoutputs indicating specific messages can be freely configured. The relay is deliveredwith a default setting. The SIPROTEC® 4 System Manual gives a detailed descriptionof the configuration procedure. The Appendix of this manual deals in detail with thedelivery status and the allocation options.

The output relays and the LEDs can be operated in a latched or unlatched mode (in-dividually settable for each one).

The latched conditions are protected against loss of the auxiliary voltage. They are re-established after restart of the device. However they can be reset as follows:

− On site by pressing the LED key on the relay.

− Remotely using a binary input configured for that purpose.

− Using one of the serial interfaces.

− Automatically at the beginning of a new pickup.

Condition messages should not be stored. Also, they cannot be reset until the criterionto be reported is cleared. This applies to messages from monitoring functions, or sim-ilar.

A green LED (“RUN”) displays operational readiness of the relay, and cannot be reset.It goes out if the self-check feature of the microprocessor recognizes an abnormal oc-currence, or if the auxiliary voltage is lost.

When auxiliary voltage is present, but the relay has an internal malfunction, then thered LED (“ERROR”) lights up and the processor blocks the relay.

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Fault InformationDisplay or PersonalComputer

Events and conditions can be read out on the display on the front cover of the relay.Using the front PC interface or the rear service interface, a personal computer can beconnected, to which the information can be sent.

The relay is equipped with several event buffers, for operational messages, circuitbreaker statistics, etc., which are protected against loss of the auxiliary voltage by abuffer battery. These messages can be retrieved, at any time, using the operating key-pad in the display field, or transferred to a personal computer, using the serial operat-ing interface. Readout of messages during operation is described in detail in theSIPROTEC® 4–System Manual.

Division ofMessages

The messages are categorized as follows:

• Event Log: These are message that can occur during the operation of the device.They include information about the status of device functions, measurement data,system data, recording of control commands, and similar information.

• Trip Log: Fault messages are message from the last 8 network faults that were pro-cessed by the device.

• Sensitive Ground Fault Log: Ground fault messages, if the device has sensitiveground fault detection.

• Statistics: These values include a counter for the trip commands initiated by the de-vice, accumulated currents interrupted by the individual poles of the circuit breaker,and the operating hours of the network or equipment being protected.

A complete list of all message and output functions that can be generated by the de-vice, with the associated information number (FNo), can be found in the Appendix.The lists also indicate where each message can be sent. The lists are based on aSIPROTEC® 4 device with the maximum number of functions. If functions are notpresent in the specific version of the device, or if they are set as “Disabled” in DeviceConfiguration, then the associated messages cannot appear.

2.20.1.1 Event Log (Operating messages)

The Event Log contains operating messages that the device generates during opera-tion. All operating messages are stored in the Annunciation Logs. Up to 200 operat-ing messages are recorded in chronological order in the device. New messages areadded at the end of the list. If the memory has been exceeded, then the oldest mes-sage is written-over for each new message.

2.20.1.2 Trip Log (Fault messages)

After a short-circuit fault on the system, for example, important information about theprogression of the fault can be retrieved, such as the pickup of a protective element orthe initiation of a trip signal. The time the initial occurrence of the short-circuit fault oc-curred is accurately provided via the system clock. Time progression of the short-cir-cuit fault is reported based on the moment of pickup, so that the duration, until the tripsignal is issued and interrupted, is available. The time resolution used for reporting is1 ms.

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Spontaneousmessages

The spontaneous messages that can be viewed on the device front serve to displaythe most important data about a fault. For devices featuring a four-line text display themessages appear automatically in the display, after a general pickup of the device, inthe sequence shown in Figure 2-86.

If the device features a grahpical display, these messages will only occur if spontane-ous fault messages were set at address 0611 unlike the default setting.

Figure 2-86 Display of Spontaneous Messages in the HMI – Example

Retrievedmessages

The messages for the last eight network faults can be retrieved. The definition of a net-work fault is such that the time period from fault detection up to final clearing of thedisturbance is considered to be one network fault. If auto-reclosing occurs, then thenetwork fault ends after the last reclosing shot, which means after a successful reclos-ing or lockout. Therefore the entire clearing process, including all reclosing shots, oc-cupies only one fault record. Within a network fault, several indications can occur(from the first pickup of a protective function to the last dropout of a protective func-tion). These indications are recorded.

In total 600 indications can be recorded. Oldest data are erased for newest data whenthe buffer is full.

2.20.1.3 Ground Fault Messages

For devices with sensitive ground fault detection, special ground fault records areavailable. Messages are provided if the protection is set for “Alarm Only” in Address3101, and the ground fault remains long enough for the time delay T-DELAY Pickupto expire.

Up to 15 messages can be recorded for the last 3 faults.

2.20.1.4 General Interrogation

The general interrogation which can be retrieved via DIGSI® 4 enables the current sta-tus of the SIPROTEC® device to be read out. All messages requiring general interro-gation are displayed with their present value.

2.20.1.5 Spontaneous Messages

The spontaneous annunciations that can be displayed via DIGSI® 4 are refreshed im-mediately, an event or status change occur.

Protective Function that picked up first;Protective Function that dropped out last;Running time from general pickup to dropout;Running time from general pickup to the first trip command

501 picked up501 TRIPT Pickup= 320ms T OFF = 197ms

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2.20.1.6 Statistics

The messages in statistics are counters for the accumulation of interrupted current byeach of the breaker poles, the number of trips issued by the device to the breaker, andthe operating hours of the breaker and protected equipment. The interrupted currentsare in primary terms.

Statistics can be viewed on the LCD of the device, or on a PC running DIGSI® 4 andconnected to the operating or service interface.

A password is not required to read statistics; however, a password is required tochange or delete the statistics.

TransmittingInformation to aControl Center

If the device features a serial system port, stored information can be transmitted to acentral control and storage unit. Transmission is possible via different transmissionprotocols.

2.20.2 Measurements

Display ofMeasured Values

A series of measured values and the values derived from them are constantly avail-able for call up on site, or for data transfer (See table 2-20, as well as the following list).

A precondition for correctly displaying the primary and percentage values is completeand correct entry of the nominal values for the voltage transformers, current transform-ers, and protected equipment, in accordance with Subsections 2.1.3 and 2.1.6. Table2-20 shows the formulas which are the basis for the conversion from secondary valuesinto primary values and percentages.

Tabelle 2-20Conversion formula between secondary values and primary/percentage values

Measured Value Secondary

Primary %

IA, IB, IC,

I1, I2

ISEC.

IN = 3⋅I0(calculated)

IN SEC.

IN = measuredvalue of theI4 input

IN SEC.

INs(Irms

Ireal,Ireactive)

INs SEC.

CT PRIMARYCT SECONDARY------------------------------------------- ISEC.⋅

Iprim.

FullScaleCurr.--------------------------------------

CT PRIMARYCT SECONDARY------------------------------------------- IN SEC.⋅

IN prim.

FullScaleCurr.--------------------------------------

Ignd CT PRIM–Ignd CT SEC–

-------------------------------------------- IN SEC.⋅IN prim.

FullScaleCurr.--------------------------------------

Ignd CT PRIM–Ignd CT SEC–

-------------------------------------------- INs SEC.⋅INs prim.

FullScaleCurr.--------------------------------------

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Depending on the type of device ordered and the device connections, some of the op-erating measured values listed below may not be available. The phase-to-ground volt-ages are either measured directly, if the voltage inputs are connected phase-to-ground, or they are calculated from the phase-to-phase voltages Vab and Vbc and thedisplacement voltage V0.

The displacement voltage is either measured directly or calculated from the phase-to-ground voltages:

Vgn = 3V0/(Vph / Vdelta) with:

3V0 = (Va + Vb + Vc)

Vph/Vdelta = Transformation adjustment for ground

input voltage (setting 0206A)

VA, VB, VC,V0, V1, V2,

Vsynchr.

Vφg SEC.

VA-B, VB-C, VC-A VφφSEC.

VN VN SEC.

P, Q, S(P and Q phase-separated)

no secondary values

Power factor(phase-separat-ed)

cos ϕ cos ϕ cos ϕ · 100 in %

Frequency f in Hz f in Hz

Tabelle 2-20Conversion formula between secondary values and primary/percentage values

Measured Value Secondary

Primary %

Vnom PRIMARYVnom SECONDARY-------------------------------------------------- Vφg SEC.⋅

Vprim.

FullScaleVolt. 3( )⁄-----------------------------------------------------

Vnom PRIMARYVnom SECONDARY-------------------------------------------------- Vφφ SEC.⋅

Vprim.

FullScaleVolt.------------------------------------

Vph Vdelta⁄ Vnom PRIMARYVnom SECONDARY-------------------------------------------------- VN SEC.⋅ ⋅

Vprim.

3 FullScaleVolt.⋅------------------------------------------------

Powerprim.

3 (FullScaleVolt.) (FullScaleCurr.)⋅ ⋅------------------------------------------------------------------------------------------------------------------------------------

f in HzfNenn

----------------- 100⋅

Parameter Adresse Parameter Adresse

Vnom PRIMARY 0202 Ignd-CT PRIM 0217

Vnom SECONDARY 0203 Ignd-CT SEC 0218

CT PRIMARY 0204 FullScaleVolt. 1101

CT SECONDARY 0205 FullScaleCurr. 1102

Vph / Vdelta 0206A

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The ground current IG is either measured directly or calculated from the conductor cur-rents:

In addition, the following may be available:

− Minimum and maximum values for the three phase currents Ix; the three phase-to-ground voltages Vxg; the three phase-to-phase voltages Vxy; the positive se-quence components I1 and V1; the displacement voltage V0; the thermal measuredvalues of the overload protection Θ/ΘTrip; the real power P, reactive power Q, andapparent power S; the frequency; and the power factor cos ϕ; primary values. In-cluded are the date and time they were last updated.

− The long-term averages of the three phase currents Ix; the positive sequencecomponents I1 for the three phase currents; and the real power P, reactive powerQ, and apparent power S; in primary values. The period of time for averaging is se-lectable.

− Minimum and maximum values for the above mentioned long-term averages,including the date and time they were last updated, in primary values.

− Real and reactive energy flow (including direction of flow) in kWh, MWh, or GWhprimary; or in kVArh, MVArh, or GVArh primary. The measured-value resolution canbe configured.

− Θ/ΘTrip overload protection value for stator in % of the trip initiating excessivetemperature,

− Θ/ΘTrip thermal measured value of the restart inhibit (rotor winding),

− ΘRESTART restarting limit of the restart inhibit

− ΘRTD 1 to ΘRTD 12 temperature values at the RTD-boxes.

The measured values are updated at a period of ≥ 0.3 s and ≤ 1 s.

The minimum and maximum values are listed with the date and time of the latest up-date. Using binary inputs or a SCADA interface, the maximum and minimum valuescan be reset. In addition, the reset can also take place cyclically, beginning with a pre-selected point in time.

For the long-term averages mentioned above, the length of the time window for aver-aging and the frequency with which it is updated can be set. The associated minimumand maximum values can be reset, using binary inputs or by using the integrated con-trol panel in the DIGSI® 4 operating program.

Transfer ofMeasured Values

Measured values can be retrieved by SCADA, or through DIGSI® 4.

Set points To recognize extraordinary operational conditions, warning levels can be pro-grammed. When a programmed limit value is exceeded (or fallen below), a message

IG3 I0⋅

Ignd-CT CT( )⁄-----------------------------------=mit 3I0 = (Ia + Ib + Ic)Ignd-CT = Parameter 0217 or 0218

CT = Parameter 0204 or 0205

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is generated that can be masked to both output relays and LEDs. In contrast to theactual protective functions, such as time-overcurrent protection or overload protection,this monitoring program may becomes lower.

Ex works, the following individual limit value levels are configured:

− Exceeding a preset maximum average current in Phase A

− Exceeding a preset maximum average current in Phase B

− Exceeding a preset maximum average current in Phase C

− Exceeding a preset maximum average positive sequence current

− Exceeding a preset maximum average real power

− Exceeding a preset maximum average reactive power

− Exceeding a preset maximum average apparent power

− Exceeding a preset temperature

− Falling below a preset pressure

− Falling below a preset current in any phase

− Falling below a preset power factor

2.20.3 Commissioning Aids

2.20.3.1 Test Messages to the SCADA Interface during Test Operation

If the SIPROTEC®4 device is connected to a central or main computer system via theSCADA interface, then the information that is transmitted can be influenced. This isonly possible with some of the protocols available (see Table “Protocol-dependentfunctions” in the Appendix).

Depending on the type of protocol, all messages and measured values transferred tothe central control system can be identified with an added message “test operation”-bit while the device is being tested onsite (test mode). This identification prevents themessages from being incorrectly interpreted as resulting from an actual power systemdisturbance or event. As another option, all messages and measured values normallytransferred via the SCADA interface can be blocked during the testing (block datatransmission).

Data transmission block can be accomplished by controlling binary inputs, by usingthe operating panel on the device, or with a PC and DIGSI® 4 via the operator inter-face.

The activation and deactivation of the test mode and transmission block is describedin detail in the SIPROTEC® 4 System Manual.

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2.20.3.2 Testing System Ports

If the device features a system port and uses it to communicate with the control center,the DIGSI® 4 device operation can be used to test if messages are transmitted cor-rectly.

A dialog box shows the display texts of all messages which were allocated to the sys-tem interface in the configuration matrix. In another column of the dialog box you canspecify a value for the messages you intend to test (e.g. ON/OFF). Having enteredpassword no. 6 (for hardware test menus) a message can then be generated. The as-sociated message will be issued and can then be retrieved in the operational annun-ciations of the SIPROTEC® device and also in the control center of the station.

A detailed description of the procedure is given in Subsection 3.3.2.

2.20.3.3 Checking the Binary Inputs and Outputs

The binary inputs, outputs, and LEDs of a SIPROTEC®4 device can be individuallyand precisely controlled in DIGSI® 4. This feature can be used, for example, to verifycontrol wiring from the device to substation equipment (operational checks), duringstart-up.

A dialog box shows all binary inputs and outputs and LEDs of the device with theirpresent status. The operating equipment, commands, or messages that are config-ured (masked) to the hardware components are displayed also. After entering pass-word no. 6 (for hardware test menus), you can switch to the opposite status in anothercolumn of the dialog box. You can energize every single output relay to check the wir-ing between 7SJ62/63/64 and the system without having to create the alarm allocatedto it.

Subsection 3.3.3 gives a detailed description of the procedure.

2.20.3.4 Triggering Oscillographic Recordings

At the end of commissioning, an investigation of the stability of the protection duringclosing operations. For this, closing test should be carried out. Oscillographic eventrecordings obtain the maximum information about the behavior of the 7SJ62/63/64.

Along with the capability of storing waveform data and SER information for faults, the7SJ62/63/64 also has the capability of capturing the same data when commands aregiven to the device via the service program DIGSI® 4, the serial interface, or a binaryinput. For the latter, the binary input must be masked with event 4,“>Trig.Wave.Cap.”. Triggering for the oscillographic recording then occurs whenthe input is energized. An auxiliary contact of the circuit breaker or primary switch maybe used to control the binary input for triggering.

An oscillographic recording that is externally triggered (that is, without a protective el-ement pickup or device trip) is processed by the device as a normal oscillographic re-cording with the exception that data are not given in the Trip Log for the event. Theexternally triggered record has a number for establishing a sequence.

Subsection 3.3.15 gives a detailed description of the procedure.

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2.20.4 Programming Settings

Average Calcula-tion

The selection of the time period for measured value averaging is set at address 8301DMD Interval. The first number specifies the averaging time window in minuteswhile the second number gives the frequency of updates within the time window. A set-ting of 15 Min., 3 Subs, for example, means that time average generation occursfor all measured values that arrive within 15 minutes, and that output is updated threetimes during the 15 minute window, or every 15/3 = 5 minutes.

The point in time where averaging begins (On The Hour, 15 After Hour, 30 After Hour or 45 After Hour) is set at address 8302 DMD Sync.Time. If thesettings for averaging are changed, then the measured values stored in the buffer aredeleted, and new results for the average calculation are only available after the settime period has passed.

Minimum andMaximum Values

The tracking of minimum and maximum values can be reset automatically at a pro-grammable point in time. To select this feature, address 8311 MinMax cycRESETshould be set to YES. The point in time when reset is to take place (the minute of theday in which reset will take place) is set at address 8312 MiMa RESET TIME. Thereset cycle in days is entered at address 8313 MiMa RESETCYCLE, and the beginningdate of the cyclical process, from the time of the setting procedure (in days), is enteredat address 8314 MinMaxRES.START.

Limit Values Phase currents and the averages of the currents and powers can be monitored. Theseare stationary monitors that cannot be used as pre-warning levels by time-overcurrentprotection, for example. The percentages are relative to the nominal device quantities.

Furthermore, it is possible to monitor the power factor, and connected 20 mA values(if any).

The settings are entered under MEASUREMENT in the sub-menu SET POINTS(MV) byoverwriting the existing values.

Power Meter Parameter 8315 MeterResolution can be used to maximize the resolution of themetered energy values by Factor 10 or Factor 100 compared to the Standardsetting.

2.20.4.1 Settings for Auxiliary Functions

Demand Measure-ment Setup

Addr. Setting Title Setting Options Default Setting Comments

8301 DMD Interval 15 Min per., 1 Sub15 Min per., 3 Subs15 Min per., 15 Subs30 Min per., 1 Sub.60 Min per., 1 Sub.60 Min per., 10 Subs5 Min per., 5 Subs

60 Min per., 1 Sub. Demand Calculation Intervals

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Min/Max Measure-ment Setup

Energy

2.20.4.2 Information List for Auxiliary Functions

Demand meter

8302 DMD Sync.Time On the Hour15 Min. after Hour30 Min. after Hour45 Min. after Hour

On the Hour Demand Synchronization Time

Addr. Setting Title Setting Options Default Setting Comments

Addr. Setting Title Setting Options Default Setting Comments

8311 MinMax cycRESET NOYES

YES Automatic Cyclic Reset Function

8312 MiMa RESET TIME 0..1439 min 0 min MinMax Reset Timer

8313 MiMa RESET-CYCLE

1..365 day(s) 7 day(s) MinMax Reset Cycle Period

8314 MinMax-RES.START

1..365 Days 1 Days MinMax Start Reset Cycle in

Addr. Setting Title Setting Options Default Setting Comments

8315 MeterResolution StandardResolution Factor 10Resolution Factor 100

Standard Meter resolution

F.No. Alarm Comments

00963 Ia dmd= I A demand

00964 Ib dmd= I B demand

00965 Ic dmd= I C demand

00833 I1 dmd= I1 (positive sequence) Demand

00834 P dmd = Active Power Demand

00835 Q dmd = Reactive Power Demand

00836 S dmd = Apparent Power Demand

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Min/Max meter

F.No. Alarm Comments

00395 >I MinMax Reset >I MIN/MAX Buffer Reset

00396 >I1 MiMaReset >I1 MIN/MAX Buffer Reset

00403 >Idmd MiMaReset >Idmd MIN/MAX Buffer Reset

00412 > Θ MiMa Reset >Theta MIN/MAX Buffer Reset

00851 Ia Min= Ia Min

00852 Ia Max= Ia Max

00853 Ib Min= Ib Min

00854 Ib Max= Ib Max

00855 Ic Min= Ic Min

00856 Ic Max= Ic Max

00857 I1 Min= I1 (positive sequence) Minimum

00858 I1 Max= I1 (positive sequence) Maximum

00837 IAdmdMin I A Demand Minimum

00838 IAdmdMax I A Demand Maximum

00839 IBdmdMin I B Demand Minimum

00840 IBdmdMax I B Demand Maximum

00841 ICdmdMin I C Demand Minimum

00842 ICdmdMax I C Demand Maximum

00843 I1dmdMin I1 (positive sequence) Demand Minimum

00844 I1dmdMax I1 (positive sequence) Demand Maximum

01059 Θ /ΘTrpMin= Overload Meter Min

01058 Θ /ΘTrpMax= Overload Meter Max

00397 >V MiMaReset >V MIN/MAX Buffer Reset

00398 >VphphMiMaRes >Vphph MIN/MAX Buffer Reset

00399 >V1 MiMa Reset >V1 MIN/MAX Buffer Reset

00400 >P MiMa Reset >P MIN/MAX Buffer Reset

00401 >S MiMa Reset >S MIN/MAX Buffer Reset

00402 >Q MiMa Reset >Q MIN/MAX Buffer Reset

00404 >Pdmd MiMaReset >Pdmd MIN/MAX Buffer Reset

00405 >Qdmd MiMaReset >Qdmd MIN/MAX Buffer Reset

00406 >Sdmd MiMaReset >Sdmd MIN/MAX Buffer Reset

00407 >Frq MiMa Reset >Frq. MIN/MAX Buffer Reset

00408 >PF MiMaReset >Power Factor MIN/MAX Buffer Reset

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00859 Va-nMin= Va-n Min

00860 Va-nMax= Va-n Max

00861 Vb-nMin= Vb-n Min

00862 Vb-nMax= Vb-n Max

00863 Vc-nMin= Vc-n Min

00864 Vc-nMax= Vc-n Max

00865 Va-bMin= Va-b Min

00867 Va-bMax= Va-b Max

00868 Vb-cMin= Vb-c Min

00869 Vb-cMax= Vb-c Max

00870 Vc-aMin= Vc-a Min

00871 Vc-aMax= Vc-a Max

00872 Vn Min = V neutral Min

00873 Vn Max = V neutral Max

00874 V1 Min = V1 (positive sequence) Voltage Minimum

00875 V1 Max = V1 (positive sequence) Voltage Maximum

00876 Pmin= Active Power Minimum

00877 Pmax= Active Power Maximum

00878 Qmin= Reactive Power Minimum

00879 Qmax= Reactive Power Maximum

00880 Smin= Apparent Power Minimum

00881 Smax= Apparent Power Maximum

00882 fmin= Frequency Minimum

00883 fmax= Frequency Maximum

00885 PF Min= Power Factor Minimum

00884 PF Max= Power Factor Maximum

00845 PdMin= Active Power Demand Minimum

00846 PdMax= Active Power Demand Maximum

00847 QdMin= Reactive Power Minimum

00848 QdMax= Reactive Power Maximum

00849 SdMin= Apparent Power Minimum

00850 SdMax= Apparent Power Maximum

F.No. Alarm Comments

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Set Points

Energy

F.No. Alarm Comments

---- I Admd> I A dmd>

---- I Bdmd> I B dmd>

---- I Cdmd> I C dmd>

---- I1dmd> I1dmd>

00273 SP. I A dmd> Set Point Phase A dmd>

00274 SP. I B dmd> Set Point Phase B dmd>

00275 SP. I C dmd> Set Point Phase C dmd>

00276 SP. I1dmd> Set Point positive sequence I1dmd>

---- |Pdmd|> |Pdmd|>

---- |Qdmd|> |Qdmd|>

---- |Sdmd|> |Sdmd|>

00277 SP. |Pdmd|> Set Point |Pdmd|>

00278 SP. |Qdmd|> Set Point |Qdmd|>

00279 SP. |Sdmd|> Set Point |Sdmd|>

---- Press< Pressure<

---- Temp> Temp>

00270 SP. Pressure< Set Point Pressure<

00271 SP. Temp> Set Point Temp>

00284 SP. 37-1 alarm Set Point 37-1 Undercurrent alarm

---- 37-1 37-1 under current

---- |PF|< |Power Factor|<

00285 SP. PF(55)alarm Set Point 55 Power factor alarm

F.No. Alarm Comments

00924 WpForward Wp Forward

00925 WqForward Wq Forward

00928 WpReverse Wp Reverse

00929 WqReverse Wq Reverse

00888 Wp(puls) Pulsed Energy Wp (active)

00889 Wq(puls) Pulsed Energy Wq (reactive)

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2.21 Breaker Control

General In addition to the protective functions described thus far, a Control command processis integrated in the SIPROTEC® 7SJ62/63/64 to coordinate the operation of circuitbreakers and other equipment in the power system. Control commands can originatefrom four command sources:

− Local operation using the keypad on the local user interface of the device

− Local or remote operation using DIGSI® 4

− Remote operation using the SCADA Interface (via IEC, Profibus)

− Automatic functions (e.g., using a binary input)

The device supports the operation of circuit breakers/switchgear. The number ofswitchgear devices to be controlled is, basically, limited by the number of binary inputsand outputs present. High security against inadvertent device operations can be en-sured if interlocking checks are enabled. A standard set of optional interlocking checksis provided for each command issued to circuit breakers/switchgear.

Devices with integrated or detached operator panel can control switchgear via the op-erator panel of the device. Depending on the type of operator panel (text display orgraphic display) the procedure is slightly different:

Operating Usingthe Keypad withText Display

Control commands can be initiated using the keypad on the local user interface of therelay. Using the navigation keys , , , , the CONTROLmenu can be accessedand the circuit breaker/switchgear to be operated can be selected. After entering apassword, a new window is displayed in which multiple control actions (close, open,cancel) are available and can be selected using the and keys. Next a securitycheck takes place. After the security check is completed, the key must bepressed again to carry out the command. If the key is not pressed within oneminute, the selection is cancelled. Cancellation via the key is possible at any timebefore the control command is issued.

Operation Usingthe Keypad withGraphic Display

Commands can be initiated using the keypad on the local user interface of the relay.For this purpose, there are three independent keys located below the graphic display.Pressing the key causes the Control Display to appear in the LCD. The other twocontrol keys and then become active, and control of switching devices be-comes possible. The LCD must be changed back to the default display for other, non-control, operational modes.

The navigation keys , , , are used to select the desired device in the Con-trol Display. The key or the key is then pressed to convey the intended con-trol command. After pressing the appropriate key, the selected device in the ControlDisplay begins to blink in the targeted-position, and a message to confirm the controlcommand is given. The key is pressed to confirm. Next a security check takesplace. After the security check is complete, the key must be pressed again to car-ry out the control command. If the key is not pressed within one minute, the se-lection is cancelled. Cancellation via the key is possible at any time before the con-trol command is issued.

After a successful switching operation, the Control Display shows the new position ofthe device, and the message “Control Executed” is given at the bottom of the dis-

ENTER

ENTER

ESC

CTRL

OPEN CLOSE

CLOSE OPEN

ENTER

ENTER

ENTER

ESC

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play. For control commands with feedback, the message “Swgr. Feedback OK” isbriefly displayed.

If the selected control command is not accepted, because an interlocking condition isnot met, then an error message appears in the display. The message indicates whythe command was not accepted (see also SIPROTEC® 4–System Manual). This mes-sage must be acknowledged with before any further control commands can beissued.

Operation usingDIGSI® 4

The procedure for issuing control commands using the DIGSI® 4 program is describedin the SIPROTEC® 4–System Manual (Control of Switchgear).

Operation using theSCADA Interface

Commands can be issued remotely via the SCADA interface as well. Please checkMLFB order number to ensure that your individual relay has a SCADA interface mod-ule that supports this. Please refer to specific protocol documents for a complete listof supported commands (see SIPROTEC® 4–System Manual).

2.21.1 Types of Commands

Two (2) types of commands can be processed within the device:

− Control commands

− Internal / pseudo commands

Control Commands Control commands operate (OPEN/CLOSE) binary outputs. Examples are:

− Commands (e.g. operation of circuit breakers, etc.)

− Step Commands (e.g. raising and lowering transformer LTCs)

− Set-point Commands with configurable time settings (Petersen coils)

Internal / pseudoCommands

These commands do not directly operate binary outputs. They serve to initiate internalfunctions, simulate changes of state, or to acknowledge changes of state.

− Marking/Tagging commands are used to manually overwrite or set status functionsnormally controlled by binary inputs.

− Additionally, Tagging commands are issued to establish internal settings, such asswitching authority (remote vs. local), parameter set changeover, data transmissionblock to the SCADA interface, and measured value set-points.

− Acknowledgment and resetting commands for setting and resetting internal buffers.

− Status Information commands:

• Controlling activation of binary input status

• Binary Output Blocking

ENTER

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2.21.2 Steps in the Command Sequence

Safety mechanisms in the command sequence ensure that a command can only bereleased after a thorough check of preset criteria has been successfully concluded.Standard Interlocking checks are provided for each individual control command. Ad-ditionally, user-defined interlocking conditions can be programmed separately foreach command. The actual execution of the command is also monitored afterwards.The entire sequence of a command is described briefly in the following:

Check Sequence • Command Entry (e.g. using the keypad on the local user interface of the device)

− Check Password → Access Rights

− Check Switching Mode (interlocking activated/deactivated) → Selection of Deac-tivated Interlocking Recognition

• User configurable Interlocking checks that can be selected for each command

− Switching Authority (local, remote)

− Device Position (scheduled vs. actual comparison)

− Zone Controlled/Field Interlocking/ (logic using CFC)

− System Interlocking (centrally, using SCADA system or substation controller)

− Double Operation (interlocking against parallel switching operation)

− Protection Blocking (blocking of switching operations by protective functions)

• Fixed Command Checks

− Internal process time (software watch dog which checks the time for processingthe control action between initiation of the control and final close of the relay con-tact. After 1 second the control action will be aborted).

− Setting Modification in Process (if setting modification is in process, commandsare denied or delayed)

− Equipment not Present at Output (If a circuit breaker or other operable equipmentis not configured to a binary output, then the command is denied)

− Output Block (if an output block has been programmed for the circuit breaker,and is active at the moment the command is processed, then the command isdenied)

− Component Hardware Malfunction

− Command in Progress (only one command can be processed at a time for onecircuit breaker or switch)

− 1-of-n-check (for schemes with multiple assignments, such as common ground,whether a command has already been initiated for the affected output relay ischecked).

Monitoring theCommandExecution

− Interruption of a Command because of a Cancel Command

− Running Time Monitor (feedback message monitoring time)

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2.21.3 Interlocking

The interlocking checks are divided into:

• System Interlocking: checked by a central control system such as SCADA or sub-station controller

• Zone Controlled/Bay Interlocking: checked in the device

System interlocking relies on the system data base in the substation or central controlsystem. Circuit breakers (or other equipment) that require system interlocking in acentral control system (Substation Controller) must be configured in their specific com-mands object properties box for the specific control device. Interlocking conditions canbe selected.

Zone Controlled/Bay Interlocking relies on the status of the circuit breaker and otherswitches that are connected to the relay. The extent of the interlocking checks is de-termined by the configuration of the relay.

For all commands, operation with interlocking (normal mode) or without interlocking(test mode) can be selected:

− for Local commands, by activation of “Normal/Test“-key switch ,

− for automatic commands, via command processing by CFC,

− for local / remote commands, using an additional interlocking disable command, viaProfibus.

2.21.3.1 Interlocked/Non-Interlocked Switching

The command checks that can be selected for the 7SJ62/63/64 relay are also referredto as “standard interlocking”. These checks can be activated (interlocked) or deacti-vated (non interlocked).

Deactivated interlock switching means the configured interlocking conditions are notchecked in the relay.

Interlocked switching means that all configured interlocking conditions are checkedwithin the command processing. If a condition could not be fulfilled, the command willbe rejected by a message with a minus added to it (e.g. “CO-”), immediately followedby an operation response information. Table 2-21 shows some types of commandsand messages. For the device the messages designated with *) are displayed in theevent logs, for DIGSI® 4 they appear in spontaneous messages.

Table 2-21 types of command and messages

Type of command Abbrev. Message

Control issued CO CO+/–

Manual tagging (positive / negative) MT MT+/–

Input blocking IB IB+/– *)

Output blocking OB OB+/– *)

Control abortion CA CA+/–

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The “plus” appearing in the message is a confirmation of the command execution: thecommand execution was as expected, in other words positive. The “minus” is a neg-ative confirmation, the command was rejected. Figure 2-87 shows the messages re-lating to command execution and operation response information for a successful op-eration of the circuit breaker.

The check of interlocking can be programmed separately for all switching devices andtags that were set with a tagging command. Other internal commands such as manualentry or abort are not checked, i.e. carried out independent of the interlocking.

Figure 2-87 Example of a message when closing the circuit breaker Q0

Standard Interlock-ing Defaults(fixed programming)

The following is a list of Standard Interlocking Conditions that can be selected for eachcontrollable device. All of these are enabled as a default.

• Device Status Check (scheduled = actual): the switching command is rejected, andan error message is displayed, if the circuit breaker is already in the scheduled (de-sired) position. (If this check is enabled, then it works whether interlocking, e.g.zone controlled, is activated or deactivated.) This condition is checked in both inter-locked and non-interlocked status modes.

• System Interlocking/Substation Controlled: To check the system interlocking, a lo-cal command is transmitted to the central unit with Switch Authority = LOCAL. Aswitching device that is subject to system interlocking cannot be switched byDIGSI® 4.

• Zone Controlled/Bay Interlocking: All devices controlled by this relay can be inter-locked by the CFC logic.

• Blocked by protection: A CLOSE-command is rejected as soon as one of the pro-tective elements in the relay picks up. The OPEN-command, in contrast, can alwaysbe executed. Please be aware, activation of thermal overload protection elementsor sensitive ground fault detection can create and maintain a fault condition status,and can therefore block CLOSE commands. If the interlocking “Blocking by protection” is removed, consider that the restart blocking for motors will also bedisabled, and a CLOSE command to the motor would be possible. Restarting wouldthen have to be interlocked some other way. One method would be to use a specificinterlocking in the CFC logic.

• Double Operation Block: parallel switching operations are interlocked against oneanother; while one command is processed, a second cannot be carried out.

• Switch Authority LOCAL: When this interlocking check is enabled in the ObjectProperties dialog box, the status of Switching authority is checked prior to issuing acontrol command. If this particular setting is selected, a control command from theuser interface of the device is only allowed if the Key Switch (for devices without keyswitch via configuration) is set to LOCAL .

EVENT LOG ---------------------19.06.01 11:52:05,625Q0 CO+ close

19.06.01 11:52:06,134Q0 FB+ close

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• Switch Authority DIGSI: Switching commands can be issued locally or remotely viaDIGSI. As part of the safety features, the device will check the DIGSI configurationfile in regard to the virtual device number to ensure that the correct configuration fileis used. DIGSI must have the same virtual device number. It is important that onefile can not be reused with multiple relays. But it is possible to copy the file and usethe new file with another relay.

• Switch Authority REMOTE: When this interlocking check is enabled in the ObjectProperties dialog box, the status of Switching authority is checked prior to issuing acontrol command. If this particular setting is selected a control command from a re-mote DIGSI connection or via the SCADA interface is only allowed if the Key Switch(for devices without key switch via configuration) is set to REMOTE.

An overview for processing the interlocking conditions in the relay is shown by Figure2-88.

.

Figure 2-88 Standard Interlocking Arrangements

&

or

or

&Remote

&DIGSI

&

&

&

&

or

Device with Source

Switching Authority

Protection Blocking

Non-Interlocked

Interlocked

CommandSCHEDULED=ACT.y/nSystem Interlocking y/nField Interlocking y/nProtection Blocking y/nDouble Oper. Block y/nSW. Auth. LOCA> y/nSw. Auth. REMOTEy/n

LOCAL

DIGSI

AUTO

Switching Authority

Switching Mode

Switching Mode

52 Close

52 Open

feedback Indication

On/Off

Switching Authority Switching Mode

EventCondition

of Command =

SCHEDULED=ACT .y/n

&

1) Source REMOTE also includes SAS. Command using substation controller.REMOTE Command using remote source such as SCADA through controller to device.

(Local/Remote)

DIGSI

Local

or

SAS REMOTE1),

DIGSI

Local

Remote

Outputto Relay

Local

Remote

On/Off

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Figure 2-89 shows the configuration of the interlocking conditions using DIGSI® 4.

Figure 2-89 DIGSI® 4–Dialogue box: Object properties for a command (configuration of theinterlocking conditions)

For devices with operator panel the display shows the configured interlocking reasons.They are marked by letters explained in the following table 2-22.

Table 2-22 Interlocking commands

Interlocking commands Abbrev. Message

Control authorization L L

System interlock S S

Zone controlled Z Z

Target state = present state(check switch position)

P P

Block by protection B B

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Figure 2-90 shows all interlocking conditions (which usually appear in the display ofthe device) for three switchgear items with the relevant abbreviations explained intable 2-22. All parametrized interlocking conditions are indicated(see Figure 2-90).

Figure 2-90 Example of configured interlocking conditions

Control Logic usingCFC

For Zone Controlled (field interlocking), control logic can be developed, using theCFC. Via specific release conditions the information “released” or “bay interlocked”are available.

SwitchingAuthority (fordevices withoperator panel)

Switching authority configures the relay to perform Local/Remote Supervisory func-tions. Note, that only one source can have authority at a time. The following switchingauthority ranges are defined in the following priority sequence:

− LOCAL (commands are issued from the relay keyboard)

− DIGSI® 4

− REMOTE (commands are issued from SCADA)

The devices in housing of size 1/2 or 1/1 are equipped with key switches on the frontpanel. The top switch is reserved for switching authority between “Local” and “Re-mote” mode. The switching authority condition LOCAL allows commands from the userinterface of the relay, but not remote or DIGSI commands. The position “Remote“ en-ables remote control.

For devices in housing of size 1/3 the switching authority can be changed between“Remote” and “Local” in the operator panel after having entered the password or bymeans of CFC also via binary input and function key.

The switching authority condition DIGSI allows commands to be initiated usingDIGSI® 4. Commands are allowed for both a remote and a local DIGSI® 4 connection.

Configuration Programming:

1. Specific Device (e.g., switching device): Switching authority LOCAL (check forcommands initiated Locally via keypad):y/n

2. Specific Device (e.g., switching device): Switching authority REMOTE (check forSAS, REMOTE, or DIGSI commands:y/n

Q8 Close/Open S Z P B

Interlocking 01/03--------------------Q0 Close/Open S Z P BQ1 Close/Open S Z P B

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In detail, the following interlocking logic is derived when using default configurationsettings:

*1) By-passes Interlock if Configuration for: “switching authority LOCAL (check for Local status): is notmarked.*2) By-passes Interlock if Configuration for: “switch authority REMOTE (check for CLOSE, REMOTE, or

DIGSI status): is not marked

SC = source of command

SC = AUTO SICAM: Commands that are initiated internally (command processing inthe CFC) are not subject to switching authority and are therefore always allowed.

SwitchingAuthority (fordevices withoutoperator panel)

The dongle cable sets the switching authority of the device to “Remote”. The specifi-cations of the previous section apply.

Switching Mode(for devices withoperator panel)

There are three modes:

− Local

− Remote

− Auto

The switching mode determines whether selected interlocking conditions will be acti-vated or deactivated at the time of the switching operation.

The following switching modes are defined:

− Local commands (SC = LOCAL)

− interlocked, or

− non-interlocked switching.

The devices in housings of size 1/2 or 1/1 are equipped with key switches on the frontpanel. The bottom switch is reserved for switching mode. The “Normal” position allowsinterlocked switching while the “Interlocking OFF” position allows non-interlockedswitching. For devices in housings of size1/3 the switching authority can be changedbetween “Interlocked” and “Non-interlocked” in the operator panel after having enteredthe password or by means of CFC also via binary input and function key.

Current SwitchingAuthority Status

SwitchingAuthority

DIGSI

Command issued Lo-cally

Command issued fromSAS or SCADA

Command issued fromDIGSI

LOCAL Not checked Allowed Interlocked - switching

authority LOCAL*2Interlocked - DIGSI notchecked

LOCAL checked Allowed Interlocked - switching

authority LOCAL*2Interlocked - switching

authority LOCAL*2

REMOTE Not checked Interlocked - switching

authority REMOTE*1Allowed Interlocked - DIGSI not

checked

REMOTE checked Interlocked - switching

authority DIGSI*1Interlocked -switching

authority DIGSI*2Allowed

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− Remote or DIGSI® 4 commands (SC = SAS, REMOTE, or DIGSI)

− interlocked, or

− non-interlocked switching. Here, deactivation of interlocking is accomplished viaa separate command. The position of the key-switch is irrelevant.

− Auto: For commands from CFC (SC = AUTO SICAM), the notes in the CFC hand-book should be referred to (e.g. component: BOOL to command)

Switching Mode(for devices withoutoperator panel)

The dongle cable sets the switching authority of the device to “Interlocked”. The spec-ifications of the previous section apply.

Zone Controlled/Field Interlocking

Zone Controlled (field interlocking) includes the verification that predetermined switch-gear position conditions are satisfied to prevent switching errors as well as verificationof the state of other mechanical interlocking such as High Voltage compartment doorsetc.

Interlocking conditions can be programmed separately, for each switching device, fordevice control CLOSE and/or OPEN. Processing of the status of the release conditionfor an operation switching device can be based on information acquired:

− directly, using a single point or double point indication (binary inputs), key-switch,or internal indication (marking), or

− with logic using CFC.

When a switching command is initiated, the actual status of all relevant switching de-vices is scanned cyclically.

Substation Control-ler (System Inter-locking)

Substation Controller (System interlocking) involves switchgear conditions of otherbays evaluated by a central control system.

Double Operation Parallel switching operations are interlocked. When this function is enabled only onecontrol can be issued at a time. All control objects are checked prior to issuing a com-mand.

Blocked by Protec-tion

When configured, the pickup of Protective elements blocks switching operations, con-figurable separately for both closing and tripping commands. Operations in progresswill also be aborted by the pickup of a protective element.

Device Position(Scheduled = Actu-al)

For switching commands, a check takes place whether the selected switching deviceis already in the scheduled/desired position (Open/Closed; scheduled/actual compar-ison). This means, if a circuit breaker is already in the CLOSED position and an at-tempt is made to issue a closing command, the command will be refused, with the op-erating message “scheduled condition equals actual condition”. If the circuit breaker/switchgear device is in the intermediate position, then this check is not performed.

BypassingInterlocks

Bypassing configured interlocks at the time of the switching action happens device-internal via interlocking recognition in the command job or globally via so-calledswitching modes.

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VQ=ORT

− The switching modes “interlocked“ or “non-interlocked“ can be set via the keyswitch. The position “Test“ corresponds to non-interlocked switching and serves thespecial purpose of unlocking the standard interlocks.

REMOTE and DIGSI® 4

− Commands issued by SICAM® or DIGSI® 4 are unlocked via global switching modeREMOTE. A separate job order must be sent for the unlocking. The unlocking ap-plies only for one switching operation and for command caused by the samesource.

− Job order: command to object “switching mode REMOTE”, ON

− Job order: switching command to “switching device”

Derived command via CFC (automatic command, SC=Auto SICAM):

− Behavior is determined in the CFC block (“Bool to command“) via configuration

2.21.4 Recording and acknowledgement of commands

During the processing of the commands, independent of the further message routingand processing, command and process feedback information are sent to the messageprocessing centre. These messages contain message cause indication. The messag-es are entered in the event list.

Acknowledgementof commands to thedevice front

All messages which relate to commands that were issued from the device front “Com-mand Issued = Local” are transformed into a corresponding response and shown inthe display of the device. A listing of possible operating messages and their meaningis given in the SIPROTEC®4 System Manual.

Acknowledgementof commands to- Local- Remote- Digsi

The messages which relate to commands with the origin “Command Issued = Local/Remote/DIGSI” must be send independent of the routing (configuration on the serialdigital interface) to the initiating point.

The acknowledgement of commands is therefore not executed by a response indica-tion as it is done with the local command but by ordinary command and feedback in-formation recording.

Monitoring offeedbackinformation

The processing of commands monitors the command execution and timing of feed-back information for all commands. At the same time the command is sent, the moni-toring time is started (monitoring of the command execution). This time controlswhether the device achieves the required final result within the monitoring time. Themonitoring time is stopped as soon as the feedback information arrives. If no feedbackinformation arrives, a response “Timeout command monitoring time” appearsand the process is terminated.

Commands and information feedback are also recorded in the event list. Normally theexecution of a command is terminated as soon as the feedback information (FB+) ofthe relevant switchgear arrives or, in case of commands without process feedback in-formation, the command output resets.

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The “plus” appearing in a feedback information confirms that the command was suc-cessful, the command was as expected, in other words positive. The “minus” is a neg-ative confirmation and means that the command was not fulfilled as expected.

Command Outputand SwitchingRelays

The command types needed for tripping and closing of the switchgear or for raisingand lowering of transformer taps are described in the SIPROTEC®4–System Manual.

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Installation and Commissioning 3This section is primarily for personnel who are experienced in installing, testing, andcommissioning protective and control systems, and are familiar with applicable safetyrules, safety regulations, and the operation of a power system.

Installation of the 7SJ62/63/64 is described in this section. Connections for the deviceare discussed. Hardware modifications that might be needed in certain cases are ex-plained. Connection verifications required before the device is put in service are alsogiven. Commissioning tests are provided. Some of the tests require the protected lineor equipment to carry load. Preparation for the initial energization of the device is cov-ered.

3.1 Installation and Connections 266

3.2 Checking Connections 318

3.3 Commissioning 323

3.4 Final Preparation of the Device 344

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3.1 Installation and Connections

Requirements The rated device data is checked as recommended in the SIPROTEC® 4 SystemManual. The compliance these data is verified with the power system data.

3.1.1 Installation

Panel FlushMounting

The device housing can be 1/3, 1/2 or Full size depending on the version. For the 1/3and 1/2 size housing, there are four covers and four holes, as shown in Figures 3-1and 3-2). There are six covers and six holes for the full size housing, as indicated inFigure 3-3.

Remove the 4 covers located at the corners of the front cover, for size 1/1 the 2 ad-ditional covers located centrally at the top and bottom, reveal the 4 respectively 6slots in the mounting flange.

Insert the device into the panel cut-out and fasten it with four or six screws. For thedimensions refer to Figure 4-11 to 4-13 in Section 4.23.

Replace the four or six covers.

Connect the ground on the rear plate of the device to the protective ground of thepanel. Use at least one M4 screw for the device ground. The cross-sectional areaof the ground wire must be greater than or equal to the cross-sectional area of anyother control conductor connected to the device. Furthermore, the cross-section ofthe ground wire must be at least 2.5 mm2.

Connect the plug terminals and/or the screwed terminals on the rear side of the de-vice according to the wiring diagram for the panel.When using forked lugs or directly connecting wires to screwed terminals, thescrews must be tightened so that the heads are even with the terminal block beforethe lugs or wires are inserted.A ring lug must be centred in the connection chamber so that the screw thread fitsin the hole of the lug.SIPROTEC® 4 System Manual has pertinent information regarding wire size, lugs,bending radii (optical cables), etc.

Warning!Trouble free and safe use of this SIPROTEC® 4 device depends on proper transport,storage, installation, and application of the device according to the warnings in this in-struction manual.

Of particular importance are the general installation and safety regulations for work ina high-voltage environment (for example, ANSI, IEC, EN, DIN, or other national andinternational regulations.) These regulations must be observed. Failure to observethese precautions can result in death, personal injury, or severe damage of property.

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Figure 3-1 Panel mounting of a 7SJ62 or a 7SJ640 with a four-line display (housingsize 1/3) as an example

Figure3-2 Panel mounting of a 7SJ632 or 7SJ641 with graphic display (housing size 1/2)as an example

SIEMENS SIPROTEC

1 2

6

3

+/-0

54

7 8 9

7SJ62RUN ERROR

MENU

ESCLED ENTER

F4

F1

F2

F3

Annunciation

Meas. Val.

MAIN MENU 01/05

AnnunciationMeasurement

Elongated

12

Trip log

Holes

SIEMENS SIPROTEC

1 2

6

3

+/-0

54

7 8 9

7SJ641RUN ERROR

MENU

ESCLED CTRL ENTER

F4

F1

F2

F3

Annunciation

Meas. Val.Remote

Normal

Local

Interlocking

Schlossplatz

21 kV1000 A

Elongated

Trip log

Holes

OFF

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Figure 3-3 Panel mounting of a 7SJ635 or 7SJ645 with graphic display (housing size 1/1) as an example

Rack Mounting andCubicle Mounting

In housing sizes 1/3 (Figure 3-4) and 1/2 (Figure 3-5) there are 4 covers and 4 securingslots, with the housing size 1/1 (Figure 3-6) there are 6 covers and 6 securing slotsavailable.

To install the device in a frame or cubicle, two mounting brackets are required. Theordering codes are stated in Appendix A, Section A.1.

Loosely screw the two mounting brackets in the rack with four screws.

Remove the 4 covers at the corners of the front cover, for size 1/1 the 2 covers lo-cated centrally at the top and bottom also have to be removed. The 4 respectively.6 slots in the mounting flange are revealed and can be accessed.

Fasten the device to the mounting brackets with four or six screws.

Replace the four or six covers.

Tighten the mounting brackets to the rack using eight screws.

Connect the ground on the rear plate of the device to the protective ground of therack. Use at least one M4 screw for the device ground. The cross-sectional area ofthe ground wire must be greater than or equal to the cross-sectional area of any oth-er control conductor connected to the device. Furthermore, the cross-section of theground wire must be at least 2.5 mm2.

ElongatedHoles

Annunciation

Meas. Val

Trip log

SIEMENS SIPROTEC

1 2

6

3

+/-0

54

7 8 9

7SJ645RUN ERROR

MENU

ESCLED CTRL ENTER

F4

F1

F2

F3

Annunciation

Meas. Values

Trip Log

Remote

Normal

Local

Interlocking

Default Display

Fault Location With F4

21 kV1000 A

OFF

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Figure 3-4 Installing a 7SJ62 or 7SJ640 in a rack or cubicle (housing size 1/3 of 19 inch rack) as an example

SIEMENS SIPROTEC

1 2

6

3

+/-0

54

7 8 9

7SJ640RUN ERROR

MENU

ESCLED ENTER

F4

F1

F2

F3

Annunciation

Meas. Val.

MAIN MENU 01/04

Annunciation 1Measurement 2

Trip log

Mounting bracket

Mounting bracket

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Figure 3-5 Installing a 7SJ632 or 7SJ641 in a rack or cubicle (housing size 1/2 of 19 inch rack) as an example

SIEMENS SIPROTEC

1 2

6

3

+/-0

54

7 8 9

7SJ641RUN ERROR

MENU

ESCLED CTRL ENTER

F4

F1

F2

F3

Annunciation

Meas. Val.Remote

Normal

Local

Interlocking

21 kV1000 A

Trip log

Mounting bracket

Mounting bracket

OFF

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Figure 3-6 Installing a 7SJ635 or 7SJ645 in a rack or cubicle (housing size 1/1 of 19 inch rack) as an example

Connect the plug terminals and/or the screwed terminals on the rear side of the de-vice according to the wiring diagram for the rack.When using forked lugs or directly connecting wires to screwed terminals, thescrews must be tightened so that the heads are even with the terminal block beforethe lugs or wires are inserted.A ring lug must be centred in the connection chamber so that the screw thread fitsin the hole of the lug.SIPROTEC® 4 System Manual has pertinent information regarding wire size, lugs,bending radii, etc.

Panel SurfaceMounting

Secure the device to the panel with four screws. For dimensions refer to Figure4-14 to 4-16 in Section 4.23.

Connect the ground of the device to the protective ground of the panel. The cross-sectional area of the ground wire must be greater than or equal to the cross-sec-tional area of any other control conductor connected to the device. Furthermore, thecross-section of the ground wire must be at least 2.5 mm2.

Connect solid, low-impedance operational grounding (cross-sectional area ≥ 2.5 mm2) to the grounding surface on the side. Use at least one M4 screw for thedevice ground.

SIEMENS SIPROTEC

1 2

6

3

+/-0

54

7 8 9

7SJ645RUN ERROR

MENU

ESCLED CTRL ENTER

F4

F1

F2

F3

Annunciation

Meas. Val.

Trip log-

Remote

Normal

Local

Interlocking

21 kV1000 A

OFF

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Connections according to the circuit diagram via screw terminals, connections foroptical fibres and electrical communication modules via the inclined housings.SIPROTEC® 4 System Manual has pertinent information regarding wire size, lugs,bending radii, etc.

Mounting withDetached OperatorPanel

For mounting the device proceed as follows:

Fasten device of housing size 1/2 with 6 screws and device of housing size 1/1 with10 screws. For dimensions see Section 4.23, Figure 4-17 and 4-18.

Connect the ground on the rear plate of the device to the protective ground of thepanel. Using at least one M4 screw. The cross-sectional area of the ground wiremust be equal to the cross-sectional area of any other control conductor connectedto the device. The cross-section of the ground wire must be at least 2.5 mm2.

Connections are realized via the plug terminals or screw terminals on the rear sideof the device according to the circuit diagram.When using forked lugs for direct connections or screw terminal, the screws, beforehaving inserted the lugs and wires, must be tightened in such a way that the screwheads are even with the terminal block.A ring lug must be centred in the connection chamber, in such a way that the screwthread fits in the hole of the lug. SIPROTEC® 4 System Manual has pertinent infor-mation regarding wire size, lugs, bending radii, etc.

For mounting the detached operator panel please observe the following:

The removal of the 4 covers located at the corners of the front cover reveal 4 elon-gated holes in the mounting bracket.

Insert the operator panel into the panel cut-out and fasten with four screws. For di-mensions refer to Figure 4-17 and 4-18 in Section 4.23.

Mount the four covers.

Connect the ground on the rear plate of the operator control element to the protec-tive ground of the panel using at least one M4 screw. The cross-sectional area ofthe ground wire must be equal to the cross-sectional area of any other control con-ductor connected to the device. The cross-section of the ground wire must be atleast 2.5 mm2.

Connect the operator panel to the device. Furthermore, plug the 68-pin connectorof the cable belonging to the operator panel into the corresponding connection atthe rear side of the device (see SIPROTEC® 4 System Manual).

Mounting withoutOperator Panel

For mounting the device proceed as follows:

Fasten device of housing size 1/2 with 6 screws and device of housing size 1/1 with10 screws. For dimensions see Section 4.23, Figure 4-17 and 4-18.

Connect the ground on the rear plate of the device to the protective ground of thepanel. Using at least one M4 screw. The cross-sectional area of the ground wire

Caution!

Do never pull or plug the connector between the device and the detached operatorpanel while the device is alive!

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must be equal to the cross-sectional area of any other control conductor connectedto the device. The cross-section of the ground wire must be at least 2.5 mm2.

Connections are realized via the plug terminals or screw terminals on the rear sideof the device according to the circuit diagram.When using forked lugs for direct connections or screw terminal, the screws, beforehaving inserted the lugs and wires, must be tightened in such a way that the screwheads are even with the terminal block.A ring lug must be centred in the connection chamber, in such a way that the screwthread fits in the hole of the lug. SIPROTEC® 4–System Manual has pertinent infor-mation regarding wire size, lugs, bending radii, etc.

For mounting the D-subminiature connector of the dongle cable please observe thefollowing:

Plug the 9-pin connector of the dongle cable with the connecting parts into the con-trol panel or the cubicle door according to Figure 3-7. For dimensions refer to Figure4-20 in Section 4.23.

Plug the 68-pin connector of the cable into the corresponding connection at the rearside of the device.

Caution!

Do never pull or plug the Dongle–cable while the device is alive! Without the cable thedevice is not ready for operation!

The connector of the dongle cable at the device must always be plugged duringoperation!

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Figure3-7 Plugging the D-subminiature connector of the dongle cable into the control panelor cubicle door (housing size 1/2 as an example).

12

34

56

78

D

UH+

9c

7c

5c

3

1abc

2

4

6

8

10

12

14

16

18a b c

13c

11c

15c

17c

9

7

5

3

1abc

2

4

6

8

10

12a b c

11

9

7

5

3

1abc

2

4

6

8

10

12a b c

14

16

18a b c

13

11

15

17

F

K

J

UH-

A

9

7

5

3

1abc

2

4

6

8

10

12a b c

11

CD

Ch1

B

Ch1

B

Control panel orcubicle door

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3.1.2 Connections

Elementary diagrams for device family 7SJ62/63/64 are shown in Appendix A, SectionA.2. Anschlussbeispiele für die Strom- und Spannungswandlerkreise befinden sich imAnhang A.3. Connection examples for current and voltage transformer circuits areprovided in Appendix A, Section A.3. It must be checked that the setting configurationof the Power System Data 1 (P.System Data 1), Section , corresponds withthe connections to the device.

3.1.2.1 Connection Examples for 7SJ62

Currents The Figures A-45 to A-49 show examples of the current transformer connection op-tions for the model 7SJ62.

Voltages The Figures A-50 to A-54 show examples of the voltage transformer connection op-tions.

The device can either be connected with three phase–ground voltages as shown inFigure A-50 (address 0213 VT Connection = Van, Vbn, Vcn), or with two phase–phase voltages and 3V0 (also called the displacement voltage) from open delta VTsas shown in Figure A-51(address 0213 VT Connection = Vab, Vbc, VGnd). Forthe latter, only the phase–phase voltages can be connected as shown in Figures A-52and A-53 (open delta VTs), or only 3V0 can be connected as illustrated in Figure A-54.In the device settings the appropriate voltage connection must be entered under Ad-dress 0213, VT Connection, in P.System Data1.

The maximum continuous voltage rating of a 7SJ62 is 170 V. For the first case above(phase-ground voltage connections), phase-phase voltages of up to [√3 · 170V] =294 V can be continuously applied. For the second case, the steady state phase-phase voltages connected to the device must be 170 V or less.

3.1.2.2 Connection Examples for 7SJ63

Currents The Figures A-55 to A-58 show examples of the current transformer connection op-tions for the model 7SJ63.

Voltages The Figures A-59 to A-62 show examples of the voltage transformer connection op-tions.

The device can either be connected with three phase–ground voltages as shown inFigure A-59 (address 0213 VT Connection = Van, Vbn, Vcn), or with two phase–phase voltages and 3V0 (also called the displacement voltage) from open delta VTsas shown in Figure A-60 (address 0213 VT Connection = Vab, Vbc, VGnd). Forthe latter, only the phase–phase voltages can be connected as shown in Figure (opendelta VTs), or only 3V0 can be connected as illustrated in Figure A-62. In the devicesettings the appropriate voltage connection must be entered under Address 0213, VT Connection, in P.System Data1.

The maximum continuous voltage rating of a 7SJ63 is 170 V. For the first case above(phase-ground voltage connections), phase-phase voltages of up to [√3 · 170V] =

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294 V can be continuously applied. For the second case, the steady state phase-phase voltages connected to the device must be 170 V or less.

3.1.2.3 Connection Examples for 7SJ64

Currents The Figures A-63 to A-65 show examples of the current transformer connection op-tions for the model 7SJ64.

Voltages The Figures A-66 to A-71 show examples of the voltage transformer connection op-tions.

For the normal connection as shown in Figure A-66 the 4th voltage measuring inputU4 is not used. The other three voltage measuring inputs are supplied with the phase-ground voltages. Correspondingly the address 0213 must be set to VT Connection= Van, Vbn, Vcn. The factor in address 0205A Vph / Vdelta must however beset to 1.73 (this factor is used internally for the conversion of measurement and faultrecording values).

Figure A-67 shows an example of the additional connection of an e–n winding of theset of voltage transformers. Address 0213 must in this case be set to VT Connection = Van,Vbn,Vcn,VGn. The factor in address 0206A Vph / Vdelta isdependent on the ratio of the e–n winding. Notes may be referred to in Subsection at“Tranformation Ratio“.

Also Figure A-68 shows an example of a connection of the e–n winding of a set of volt-age transformers, in this case, however of a central set of transformers at a busbar.For more information refer to the previous paragraph.

Figure A-69 shows an example of the connection of a different voltage, in this case thebusbar voltage (for Synchronization). For synchronization address 0213 must be setto VT Connection = Van,Vbn,Vcn,VSy. The factor address 6X21 Balancing V1/V2 is always equal to 1 unless the feederside VT and busbarside VT have a dif-ferent transformation ratio. The factor in address 0206A Vph / Vdeltamust be 1.73(this factor is used internally for the conversion of measurement and fault recordingvalues).

The device can be also connected with two phase–phase voltages and 3V0 (alsocalled the displacement voltage) from open delta VTs as shown in Figure A-70 (ad-dress 0213 VT Connection = Vab, Vbc, VGnd). For the latter, only the phase–phase voltages can be connected or only 3V0 can be connected.

The maximum continuous voltage rating of a 7SJ64 is 170 V. For the first case above(phase–ground voltage connections), phase–phase voltages of up to [√3 · 170V] =294 V can be continuously applied. For the second case, the steady state phase–phase voltages connected to the device must be 170 V or less.

3.1.2.4 General Connections for 7SJ62/63/64

Binary Inputs andOutputs

The configuration of the binary in and outputs, i.e. the individual adaptation to the plantconditions, is described in the SIPROTEC® 4 System Manual. The connections to theplant are dependent on this actual configuration. The presettings of the device are list-ed in Appendix A, Section A.4. Check also if the labelling corresponds to the allocatedmessage functions.

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Changing SettingGroups with BinaryInputs

If binary inputs are used to switch setting groups, note:

• Two binary inputs must be dedicated to the purpose of changing setting groupswhen four groups are to be switched. One binary input must be set for “>Set Group Bit 0”, the other input for “>Set Group Bit 1”. If either of these inputfunctions is not assigned, then it is considered as not controlled.

• To control two setting groups, one binary input set for “>Set Group Bit 0” issufficient since the binary input “>Set Group Bit 1”, which is not assigned, isconsidered to be not controlled.

• The status of the signals controlling the binary inputs to activate a particular settinggroup must remain constant as long as that particular group is to remain active.

Table 3-1 shows the relationship between “>Set Group Bit 0”, “>Set Group Bit 1”, and the setting groups A to D. Principal connection diagrams for the two binary in-puts are illustrated in Figure 3-8. The figure illustrates an example in which both SetGroup Bits 0 and 1 are configured to be controlled (actuated) when the associated bi-nary input is energized (high).

no = not energizedyes =energized

Figure3-8 Connection diagram (example) for setting group switching with binary inputs

Table 3-1 Setting group selection with binary inputs — example

Binary Input EventsActive Group>Set Group Bit 0 >Set Group Bit 1

no no Group A

yes no Group B

no yes Group C

yes yes Group D

ABCD

L–L+

Selector switch forsetting group

Binary input set for: 7 “>Set Group Bit 0”, High

ABCD

L+

Binary input set for: 8 ”>Set Group Bit 1”, High

7SJ62/63/64

>Set Group Bit 0FNo 7

L– >Set Group Bit 1FNo 8

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Trip CircuitSupervision

It must be noted that two binary inputs or one binary input and one bypass resistor Rmust be connected in series. The pick-up threshold of the binary inputs must thereforebe substantially below half the rated control DC voltage.

If two binary inputs are used for the trip circuit supervision, these binary inputs mustbe potential free i.o.w. not be commoned with each other or with another binary input.

If one binary input is used, a bypass resistor R must be employed (refer to Figure3-9). This resistor R is connected in series with the second circuit breaker auxiliarycontact (Aux2), to also allow the detection of a trip circuit failure when the circuit break-er auxiliary contact 1 (Aux1) is open, and the command relay contact has reset. Thevalue of this resistor must be such that in the circuit breaker open condition (thereforeAux1 is open and Aux2 is closed) the circuit breaker trip coil (TC) is no longer pickedup and binary input (BI1) is still picked up if the command relay contact is open.

Figure 3-9 Trip circuit supervision with one binary input

This results in an upper limit for the resistance dimension, Rmax, and a lower limit Rmin,from which the optimal value of the arithmetic mean should be selected.

To ensure the minimum voltage for the control of the binary input, Rmax is derived as:

So the circuit breaker trip coil does not remain energized in the above case, Rmin isderived as:

IBI (HIGH) Constant current with BI on (= 1,7 mA)

UBI minMinimum control voltage for BI

=19 V for delivery setting for nominal voltage of 24/48/60 V;

=73 V for delivery setting for nominal voltage of 110/125/220/250 V;

L–

L+

RTC

Aux2Aux1

UBI >RTC Status

UCTR 7SJ62/63/64

7SJ62/63/64

TCCB

Legend:

RTC — Relay Tripping ContactCB — Circuit BreakerTC — Circuit Breaker Trip CoilAux1 — Circuit Breaker Auxiliary Contact

(Closed when CB is Closed)Aux2 — Circuit Breaker Auxiliary Contact

(Closed when CB is Open)R — bypass Resistor

UCTR — Control Voltage (Trip Voltage)UBI — Input Voltage for Binary Input

R

RRmax Rmin+

2---------------------------------=

Rmax

UCRT UBI min–

IBI (High)-------------------------------------- RCBTC–=

Rmin RTC

UCTR UTC (LOW)–

UTC (LOW)----------------------------------------------- ⋅=

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If the calculation results that Rmax < Rmin, then the calculation must be repeated, withthe next lowest switching threshold UBI min, and this threshold must be implementedin the relay using plug-in bridges (see Sub-section 3.1.3).

For the power consumption of the resistance:

Example:

The closest standard value of 39 kΩ is selected; the power is:

3.1.3 Hardware Modifications

3.1.3.1 General

Hardware modifications might be necessary or desired. For example, a change of thepick-up threshold for some of the binary inputs might be advantageous in certain ap-plications. Terminating resistors might be required for the communication bus. In ei-ther case, hardware modifications are needed. The modifications are done with jump-

UCTR Control voltage for trip circuit

RCBTC DC resistance of circuit breaker trip coil

UCBTC (LOW) Maximum voltage on the circuit breaker trip coil that does not lead to tripping

IBI (HIGH) 1.8 mA (from SIPROTEC® 7SJ62/63/64)

UBI min 19 V for delivery setting for nominal voltage 24/48/60 V73 V or delivery setting for nominal voltage 110/125/220/250 V

UCTR 110 V (from system / release circuit)

RCBTC 500 Ω (from system / release circuit)

UCBTC (LOW) 2 V (from system / release circuit)

PR I2

R⋅UCTR

R RCBTC+----------------------------

2R⋅= =

Rmax 50.1 kΩ=Rmax110 V - 19 V

1.8 mΑ--------------------------------- 500Ω–=

Rmin 27 kΩ=Rmin 500Ω 110 V - 2 V2V

------------------------------ ⋅=

RRmax Rmin+

2-------------------------------- 38.6 kΩ= =

PR110 V

39 kΩ 0.5 kΩ+----------------------------------------

239 kΩ⋅= PR 0.3 W≥

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ers on the printed circuit boards inside the device. Follow the procedure described inSubsection 3.1.3, whenever hardware modifications are done.

Since the design of the modules differs, detailed information on hardware adaption islisted separately for each of the three device types 7SJ62, 7SJ63 and 7SJ64.

Power SupplyVoltage

There are different ranges for the power supply voltage of the various power supplies.Refer to the data for the 7SJ62/63/64 ordering numbers in Section A.1 of the Appen-dix. The power supplies of the different variants are largely interchangeable by modi-fying the position of the jumpers. Jumper settings determine the rating. The assign-ment of these jumpers to the supply voltages is described in Subsubsections 3.1.3.3to 3.1.3.5, separately for 7SJ62, 7SJ63 and 7SJ64. When the relays are delivered,these jumpers are set according to the name-plate sticker. Generally, they need notbe altered.

Life Contact The life contacts of the devices are changeover contacts. In 7SJ62 all three connec-tions are conducted to device terminals. In case of 7SJ63 and 7SJ64 the NC contactor the NO contact can be connected to the device connections via a plug-in jumper(X40). The assignment of the plug-in jumper to the type of contact and the location ofthe jumper is described in Subsubsections 3.1.3.4 and 3.1.3.5 for the models 7SJ63and 7SJ64.

Nominal Currents The input transformers of the devices are set to a nominal current of 1 A or 5 A withjumpers. The position of the jumpers are set according to the name-plate sticker. Theassignment of the jumpers to the nominal rate and the arrangement of the jumpers isdescribed in 3.1.3.3 to 3.1.3.5, separately for 7SJ62, 7SJ63 and 7SJ64.

All jumpers must be set for the same nominal current, i.e. a jumper (X61 to X63) onejumper for each input transformer and additionally one jumper X 60.

Jumper X64 for the ground path is set to 1 A or 5 A (depending on the ordered variant)for the models with normal 1/5-A transformer irrespective of the other jumper posi-tions.

Jumper X64 is omitted for models featuring a sensitive ground fault input for the settingrange from 0.001 to 1.500 A.

Control Voltagesfor Binary Inputs

When the device is delivered from the factory, the binary inputs are set to operate witha voltage that corresponds to the rated DC voltage of the power supply. In general, tooptimize the operation of the inputs, the pick-up voltage of the inputs should be set tomost closely match the actual control voltage being used. Each binary input has apick-up voltage that can be independently adjusted; therefore, each input can be setaccording to the function performed.

A jumper position is changed to adjust the pick-up voltage of a binary input. The phys-ical arrangement of the binary input jumpers in relation to the pick-up voltages is de-scribed in 3.1.3.3 to 3.1.3.5 separately for 7SJ62, 7SJ63 and 7SJ64.

Note:

If nominal current ratings are changed exceptionally, then the new ratings must beregistered in addresses 0205 CT SECONDARY/ 0218 Ignd-CT SEC in the Power System Data 1 (P.System Data 1) (see Subsection 2.1.3).

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Type of Contact forBinary Outputs

Input and output boards can contain relays of which the contact can be set as normallyclosed or normally open contact. Therefore it is necessary to rearrange a jumper. Sub-sections 3.1.3.3 to 3.1.3.5 describe separately for 7SJ62, 7SJ63 and 7SJ64 to whichrelays on which modules this applies.

ReplacingInterfaces

Only serial interfaces of devices for panel and cubicle flush mounting as well as ofmounting devices with detached operator panel or without operator panel are replace-able. For more details on this matter refer to Subsubsection 3.1.3.6, “Replacing Inter-faces”.

ConfiguringRS232/RS485

When the device is delivered from the factory, the serial interfaces are matched to theordered version according to the 11th and 12th figure of the ordering code of the de-vice (or to the additional information of the ordering code). The configuration is deter-mined by jumpers on the interface modules (“RS232/RS485” in Subsection 3.1.3.6).

Termination ofSerial Interfaces

If the device is equipped with a serial RS485 port or Profibus, they must be terminatedwith resistors at the last device on the bus to ensure reliable data transmission. Forthis purpose, the printed circuit board of the central processor unit CPU and the RS485or Profibus interface module are provided with terminating resistors that can be con-nected to the system by means of jumpers. It is important to use only 1 of the options.The position of the jumpers on the printed circuit board of the corresponding centralprocessor unit CPU is described in Subsubsections 3.1.3.3 to 3.1.3.5, see “ProcessorBoard CPU” and the position of the jumpers on the interface modules in Subsubsec-tion 3.1.3.6, see „RS485/RS232“ und „Profibus (FMS/DP) DNP3.0/Modbus“. Bothjumpers must always be plugged in the same way.

As delivered from the factory, the resistors are switched out.

Spare Parts Spare parts can be the battery that provides for storage of the data in the battery-buff-ered RAM in case of a power failure, and the miniature fuse of the internal power sup-ply. Their physical location is shown in Figures 3-16, 3-17, 3-19, 3-20 and 3-23. Theratings of the fuse are printed on the board next the fuse itself. When exchanging thefuse, please observe the hints given in the SIPROTEC®4 System Manual in the chap-ter “Maintenance”.

3.1.3.2 Disassembly of the Device

Important!It is assumed for the following steps that the the device is not operative.

To perform work on the printed circuit boards, such as checking or moving switchingelements or exchanging modules, proceed as follows:

Note:

If the 7SJ62/63/64 performs trip circuit monitoring, two binary inputs, or one binary in-put and a resistor, are connected in series. The pick-up voltage of these inputs mustbe less than half of the nominal DC voltage of the trip circuit.

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Prepare area of work. Provide a grounded mat for protecting components subject todamage from electrostatic discharges (ESD). The following equipment is needed:

− screwdriver with a 5 to 6 mm wide tip,

− 1 Philips screwdriver,

− 4.5 mm socket or nut driver.

Unfasten the screw-posts of the D-subminiature connector on the back panel at loca-tion “A” and “C” (7SJ64). This activity does not apply if the device is for surface mount-ing.

If there are additional interfaces on location “B” , “C” and “D” next to the interfaces atlocation “A” to “C” (7SJ64), remove the screws located diagonally to the interfaces.This activity is not necessary if the device is for surface mounting.

Remove the four or six caps on the front cover and loosen the screws that becomeaccessible.

Carefully take off the front cover. The front cover is connected to the CPU board witha short ribbon-cable. With device versions with a detached operator panel it is possibleto remove the front cover of the device right after having unscrewed all screws.

Disconnect the ribbon cable between the front cover and the CPU board () at thefront cover side. To disconnect the cable, push up the top latch of the plug connectorand push down the bottom latch of the plug connector. Carefully draw out the plug con-nector.This action does not apply to the device version with detached operator panel. How-ever, on the central processor unit CPU () the 7-pole plug connector X16 behind theD-subminiture connector and the plug connector of the ribbon cable (connected to the68pole plug connector on the rear side) must be removed.

Disconnect the ribbon cables between the CPU unit () and the input/output printedcircuit boards (depending on the version () to ()).

Remove the boards and set them on the grounded mat to protect them from ESD dam-age. A greater effort is required to withdraw the CPU board, especially in versions ofthe device for surface-mounting, because of the communication connectors.

Caution!

Jumper-setting changes that affect nominal values of the device render the orderingnumber and the corresponding nominal values on the nameplate sticker invalid. Ifsuch changes are necessary, the changes should be clearly and fully noted on the de-vice. Self adhesive stickers are available that can be used as replacement name-plates.

Caution!

Electrostatic discharges through the connections of the components, wiring, plugs,and jumpers must be avoided. Wearing a grounded wrist strap is preferred. Otherwise,first touch a grounded metal part.

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Check the jumpers according to Figures 3-16 to 3-27 and the following informationChange or remove the jumpers as necessary.

The order of the boards for the individual device types and housings is shown in Fig-ures 3-10 to 3-15.

ModuleArrangement of7SJ62

Figure 3-10 shows the arrangement of the modules for 7SJ62.

Figure3-10 Front view of 7SJ62 after removal of the front cover (simplified and scaleddown

Slot 5 Slot 19

Binary inputs (BI)BI1 to BI4 to1 2

BI3 BI11

1

2 Input/output printed circuit board A–I/O–2Processor printed circuit board A–CPU

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Module Arrange-ment of 7SJ63

Figure 3-11shows the arrangement of the modules for 7SJ63 with housing size 1/2 andFigure 3-12 for the housing size 1/1.

Figure 3-11 Front view of the 7SJ63 with housing size 1/2 after removal of the front cover (simplified and scaled down)

1

2

3

Slot 5 Slot 19 Slot 33

Binary inputs (BI)BI1 to BI8 to BI21 to

Input/output printed circuit board B–I/O-1Input/output printed circuit board B–I/O-2

Processor printed circuit board B–CPU

1 23

BI7 BI20 BI24

7SJ632 and 7SJ633

Binary inputs (BI)BI1 to BI21 to1 2

BI7 BI24

7SJ631

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Figure 3-12 Front view of 7SJ635 and 7SJ636 with housing size 1/2 after removal of the front cover (simplified andscaled down)

1 42 1 42

1

2

3

Input/output p. c. b. B–I/O-1Input/output p. c. b. B–I/O-2

Prozessorbaugruppe

Processor p. c. b. B–CPU

Slot 5 Slot 33

Binary Inputs (BI)BI1 to BI8 to BI21 to1 23

Slot 5 Slot 333

BI25 toBI7 BI20 BI37 BI24

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ModuleArrangement of7SJ64

Figure 3-13 shows the arrangement of the modules for 7SJ64 with housing size 1/3and Figure 3-14 for the housing size 1/2 and Figure 3-15 for the housing size 1/1.

Figure3-13 Front view of device of housing size 1/3 after removal of the front cover(simplified and scaled down)

Slot 5 Slot 19

7SJ640BI1 toBI5

BI6 andBI7

1

2 Input/output printed circuit board C–I/O–11Processor printed circuit board C–CPU–2

Binary inputs (BI)

1 2

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Figure3-14 Front view of 7SJ64 with housing size 1/2 after removal of the front cover(simplified and scaled down)

Figure 3-15 Front view of 7SJ645 with housing size 1/1 after removal of the front cover (simplified and scaled down).

1

2

3

Slot 5 Slot 19 Slot 33

Binary inputs (BI)

Input/output p. c. b. C–I/O–11Input/output p. c. b. B–I/O–2

Processor p. c. b. C–CPU–2

1 2 7SJ641BI1 toBI5

Binary inputs (BI)BI8 to

1 3 2

BI20

7SJ642BI1 toBI5

BI6 andBI7

BI6 andBI7

4 Input/output p. c. b. C–I/O–1

4

BI8 toBI15

1 42 1 42

1

2

3

Input/output p. c. b. C–I/O–11Input/output p. c. b. B–I/O–2

Processor p. c. b. C–CPU–2

Slot 5 Slot 33

Binary Inputs (BI)BI8 to

1 2

Slot 19 Slot 33

BI21 to

3 3

BI20 BI33BI6 andBI7

7SJ645BI1 toBI5

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3.1.3.3 Jumper Settings on Printed Circuit Boards of 7SJ62

Processor BoardA–CPU for7SJ62.../DD

There are two different releases available of the A–CPU board. Figure 3-16 shows thelayout of the printed circuit board for the A–CPU board up to the release 7SJ62.../DD,Figure 3-17 for devices of the release 7SJ62.../EE.

The set nominal voltage of the integrated current supply is checked according to Table3-2 and the selected operating voltage of the binary inputs BI1 to BI3 to Table 3-3. Thelocation and ratings of the miniature fuse (F1) and of the buffer battery (G1) are shownin Figure 3-16.

Figure3-16 Processor printed circuit board A–CPU for 7SJ62.../DD with jumper settingsrequired for the module configuration

F1

X23

LH

X21

LH

LH

X22

31

X51

2

X533 12

X52

12

34

Lithium–Battery 3 V/1 Ah,Typ CR 1/2 AA

G1

+ –

Cable Binder

Battery

Time Syn-chronization(Port A)

FrontOperatorPanel

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Power Supply

Pickup Voltagesof BI1 to BI3

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC.2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and AC 115/230 V

Table 3-2 Factory Jumper Settings for the nominal voltage of the integrated Power Supplyon the A–CPU for 7SJ62.../DD

Jumper Nominal Voltage

60/110/125 VDC 110/125/220/250 DC115 VAC

24/48 VDC 230 VAC

X51 1–2 2–3Jumpers X51 through X53

are not usedX52 1–2 and 3–4 2–3

X53 1–2 2–3

Can be inter-changed Not changeable

Table 3-3 Factory Jumper Settings for the Pickup Voltages of the Binary Inputs BI1through BI3 on the A–CPU for 7SJ62.../DD

Binary Input Jumper 19 VDC

Pickup1)

88 VDC

Pickup2)

BI1 X21 L H

BI2 X22 L H

BI3 X23 L H

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Processor BoardA–CPU for7SJ62.../EE

The set nominal voltage of the integrated current supply is checked according to Table3-4, the selected operating voltage of the binary inputs BI1 to BI3 according to Table3-5 and the contact mode of the binary outputs BO1 and BO2 according to Table 3-6.The location and ratings of the miniature fuse (F1) and of the buffer battery (G1) areshown in Figure 3-17.

Figure 3-17 Processor printed circuit board A–CPU for 7SJ62.../EE with jumper settings required for themodule configuration

F1

Time Syn-chronization(Port A)

Frontoperator

G1

+ –

Cable binder

Battery

Fuse

X23

LH

X21

LH

LH

X22

31

X51

2

X533 12

X52

12

34

T2,0H250V

X41

1 23

X42

1 23

panel

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Power Supply

Pickup Voltagesof BI1 to BI3

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC.2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and AC 115/230 V

Contact Mode forBO1 and BO2

Table 3-4 Factory Jumper Settings for the nominal voltage of the integrated Power Supplyon the A–CPU for 7SJ62.../EE

JumperNominal Voltage

24 to 48 VDC 60 to125 VDC 110 to 250 VDC, 115 to 230 VAC

X51 none 1–2 2–3

X52 none 1–2 and 3–4 2–3

X53 none 1–2 2–3

Table 3-5 Factory Jumper Settings for the Pickup Voltages of the Binary Inputs BI1through BI3 on the A–CPU for 7SJ62.../EE

Binary Input Jumper 19 VDC

Pickup1)

88 VDC

Pickup2)

BI1 X21 L H

BI2 X22 L H

BI3 X23 L H

Table 3-6 Jumper setting for the Contact Mode of the binary outputs BO1 und BO2 on theprocessor printed circuit board A–CPU for 7SJ62.../EE

BO JumperOpen in the quiescent

stateClosed in the quiescent

statePresetting

BO1 X41 1–2 2–3 1–2

BO2 X42 1–2 2–3 1–2

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Input/Output BoardA–I/O–2

The layout of the printed circuit board for the input/output board A–I/O–2 is illustratedin Figure 3-18. The set nominal currents of the current input transformers and the se-lected operating voltage of the binary inputs BI4 to BI11 according to Table 3-7 arechecked.Jumpers X60 to X63 must all be set to the same rated current, i.e. one jumper (X61 toX63) for each input transformer of the phase currents and in addition the commonjumper X60.Jumper X64 determines the rated current for the input IE and may thus have a settingthat deviates from that of the phase currents. There is no jumper X64 for the versionwith sensitive earth current input.

Figure3-18 The input/output board A-I/O–2 with the jumpers necessary for the settingcheck

X63

5A1A

X62

5A1A

X60

5A1A

X64

5A1A

X61

5A1A

X28

HL

X27

HL

X26

HL

X22

HL

X21

HL

X25

HL

X24

HL

X23

HL

T4

T2 T1

T3

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Pickup Voltagesof BI4 to BI11

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 250 VDC and 115/230 VAC

Table 3-7 Jumper settings of the control voltages of the binary inputs BI4 to BI11 on theinput/output board A–I/O–2

Binary Inputs Jumper 19 VDCPick-up 1)

88 VDCPick-up 2)

BI4 X21 L H

BI5 X22 L H

BI6 X23 L H

BI7 X24 L H

BI8 X25 L H

BI9 X26 L H

BI10 X27 L H

BI11 X28 L H

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3.1.3.4 Switching Elements on the Printed Circuit Boards of 7SJ63

Processor BoardB–CPU for7SJ63.../DD

There exist two different releases of the B–CPU board with a different arrangementand setting of the jumpers. Figure 3-19 depicts the layout of the printed circuit boardfor the B-CPU board for devices up to the release 7SJ63.../DD, Figure 3-20 for devicesof release .../EE and higher.

For devices up to release 7SJ63.../DD check the provided nominal voltage of the inte-grated power supply according to Table 3-8, the quiescent state of the life contact ac-cording to Table 3-12 and the selected pickup voltages of the binary inputs BI1 throughBI7 according to Table 3-13. The location and ratings of the miniature fuse (F1) andof the buffer battery (G1) are shown in Figure 3-19.

Figure 3-19 Processor printed circuit board B–CPU for 7SJ63.../DDwith jumper settings required for the moduleconfiguration

F1

X21

LH

X53

3 12

X52

12

34

X22

LH

X23

LH

X40

31 2

X24

LH

X25

LH

X26

LH

X27

LH

X51

3 12

Lithium–Battery 3 V/1 Ah,Typ CR 1/2 AA

G1

+ –

Cable Binder

Battery

Time Syn-chronization(Port A)

FrontOperatorPanel

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Power Supply There is no 230-V AC power supply available for 7SJ63.../DD.

Live Status Contact

Pickup Voltagesof BI1 to BI7

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 250 VDC and 115 VAC

Table 3-8 Factory Jumper Settings for the Nominal Voltage of the integrated Power Sup-ply on B–CPU for 7SJ63.../DD

Jumper Nominal Voltage

60/110/125 VDC 110/125/220/250 VDC115 VAC

24/48 VDC

X51 1-2 2-3 Jumpers X51 through

X53 are not usedX52 1-2 and 3-4 2-3

X53 1-2 2-3

Can be inter-changed Not changeable

Table 3-9 Jumper Setting for Live Status Contact-Type brought out to device terminals,on B–CPU for 7SJ63.../DD

Jumper Normally Open Contact Normally Closed Contact Factory Set

X40 1-2 2-3 2-3

Table 3-10 Factory Jumper Settings for the Pickup Voltages of the Binary Inputs BI1through BI7 on the CPU Board

Binary Input Jumper 19 VDCPickup1)

88 VDC Pickup2)

BI1 X21 L H

BI2 X22 L H

BI3 X23 L H

BI4 X24 L H

BI5 X25 L H

BI6 X26 L H

BI7 X27 L H

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Processor BoardB–CPU for7SJ63.../EE

For devices of release 7SJ63.../EE and higher check the provided nominal voltage ofthe integrated power supply according to Table 3-11, the quiescent state of the lifecontact according to Table 3-12 and the selected pickup voltages of the binary inputsBI1 through BI7 according to Table 3-13. The location and ratings of the miniature fuse(F1) and of the buffer battery (G1) are shown in Figure 3-20.

Figure 3-20 Processor printed circuit board B–CPU for 7SJ63.../EE with jumper settings required for the moduleconfiguration

F1

X25L

H

12

34

X27 L

H

X51 1

3 2

3X40

21

X53

123

X52

X26

LH

X23LH

X21 LH

X22 LH

X24 LH

Lithium–Battery 3 V/1 Ah,Typ CR 1/2 AA

G1

+ –

Cable Binder

Battery

Time Syn-chronization(Port A)

FrontOperatorPanel

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Power Supply There is a 230-V AC power supply available for 7SJ63.../EE.

Live Status Contact

Pickup Voltagesof BI1 to BI7

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 250 VDC and 115/230 VAC

Table 3-11 Jumper settings for the nominal voltage of the integrated power supply on theprocessor printed circuit board B–CPU for 7SJ63.../EE

Jumper Nominal Voltage

60/110/125 VDC 220/250 VDC115/230 VAC

24/48 VDC

X51 1–2 2–3 1–2

X52 1–2 and 3–4 2–3 none

X53 1–2 2–3 none

Table 3-12 Jumper setting for the quiescent state of the life contact on theprocessor printed circuit board B–CPU for 7SJ63.../EE

Jumper Open in the quiescent state Closed in the quiescent state Presetting

X40 1–2 2–3 2–3

Table 3-13 Factory Jumper Settings for the Pickup Voltages of the Binary Inputs BI1through BI7 on the CPU Board for 7SJ63.../EE

Binary Input Jumper 19 VDCPickup1)

88 VDC Pickup2)

BI1 X21 L H

BI2 X22 L H

BI3 X23 L H

BI4 X24 L H

BI5 X25 L H

BI6 X26 L H

BI7 X27 L H

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Input/Output BoardB–I/O–1

The layout of the printed circuit board for the input/output board B–I/O–1 is illustratedin Figure 3-21. The set nominal currents of the current input transformers and the se-lected operating voltage of the binary inputs BI21 to BI24 according to Table 3-14 arechecked.The jumpers X60 to X63 must all be set to the same rated current, i.e. one jumper (X61to X63) for each input transformer of the phase currents and in addition the commonjumper X60.The jumper X64 determines the rated current for the input IE and may thus have a set-ting that deviates from that of the phase currents. There is no jumper X64 for the ver-sion with sensitive earth current input.

Figure3-21Input/output module B–I/O-1 with representation of the jumper settings required forthe module configuration

X60

1A5A

X21

HL

X61

X22

HL

X23

HL

X24

HL

T4

T2

T3

T1

5A 1A

X625A 1A

X635A 1A

X645A 1A

AD0X71H L

AD1X72AD2X73

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Pickup Voltagesof BI21 to BI24

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC.2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115/230 VAC.

Bus address Jumpers X71, X72 and X73 on the B– I/O-1 board serve to set up the bus address.The jumpers must not be changed. Table 3-15 shows the factory settings for the jump-ers.

Table 3-14 Factory jumper settings for the Pickup Voltages of the binary inputsBI21 through BI24 on the B–I/O-1 board

Binary Input Jumper 19 VDC Pickup1) 88 VDC Pickup2)

BI21 X21 L H

BI22 X22 L H

BI23 X23 L H

BI24 X24 L H

Table 3-15 Factory Settings for Jumpers X71, X72, and X73 on the B–I/O-1 Board

Jumper 1/2 Size and Full Size Housing

X71 L

X72 H

X73 L

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Input/Output BoardB–I/O–2

The layout of the printed circuit board for the input/output board B–I/O–2 is illustratedin Figure 3-22. Check the selected pickup voltages of the binary inputs BI8 throughBI20, and BI25 through BI37, according to Table 3-16.

The assignment of the binary inputs to the printed circuit board is shown in Figures 3-11 and 3-12.

Figure3-22Jumpers on the B–I/O-2 Board for the Binary Inputs BI8 through BI20, and BI25through BI37. (Jumpers X71, X72 and X73 apply to 1/2 size housing)

X71

X21

31

2

X223

12

1 2 3

X72 1 2 3

X73 1 2 3

X243

12

X333

12

X323

12

X313

12

X303

12

X263

12

X283

12

X293

12

X273

12

X233

12

X25

31

2

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Pickup Voltagesof BI8 to BI20

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC.2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115/230 VAC.

Bus address Jumpers X71, X72 and X73 on the B–I/O-2 board serve to set up the bus address. Thejumpers must not be changed. Table 3-17 shows the factory settings for the jumpers.

Table 3-16 Factory jumper settings for the Pickup Voltages of the binary inputs BI8through BI20 and BI25 through BI37on the B–I/O-2 board

Binary Input Jumper 19 VDC Pickup1) 88 VDC Pickup2)

BI8 BI25 X21 1-2 2-3

BI9 BI26 X22 1-2 2-3

BI10 BI27 X23 1-2 2-3

BI11 BI28 X24 1-2 2-3

BI12 BI29 X25 1-2 2-3

BI13 BI30 X26 1-2 2-3

BI14 BI31 X27 1-2 2-3

BI15 BI32 X28 1-2 2-3

BI16 BI33 X29 1-2 2-3

BI17 BI34 X30 1-2 2-3

BI18 BI35 X31 1-2 2-3

BI19 BI36 X32 1-2 2-3

BI20 BI37 X33 1-2 2-3

Table 3-17 Factory Settings for Jumpers X71, X72, and X73 on the B–I/O-2 Board

Jumper 1/2 Size Housing Full Size Housing

Slot 33 Slot 5

X71 2-3 1-2 1-2

X72 1-2 2-3 1-2

X73 1-2 2-3 2-3

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3.1.3.5 Switching Elements on the Printed Circuit Boards of 7SJ64

Processor BoardC-CPU-2

The layout of the printed circuit board of the processor printed circuit board C-CPU-2is illustrated in Figure 3-23.

The set nominal voltage of the integrated current supply is checked according to Table3-18, the quiescent state of the life contact according to Table 3-19 and the selectedoperating voltage of the binary inputs BI1 to BI5 according to Table 3-20 and the inte-grated interface RS232 / RS485 according to Table 3-21 to 3-23. The location and rat-ings of the miniature fuse (F1) and of the buffer battery (G1) are shown in Figure 3-23.

Figure3-23Processor printed circuit board C-CPU-2 with jumper settings required for themodule configuration

F1

X21

21

X51

3 12

X53

3

1 2

X52

12

34

X40

31

2

1 2X

55

34

X22

213

4

X23

213

4

X24

213

4

X25

213

4

X10

61

23

X10

41

23 X10

51

23X10

3X

109

12

3X

107

1 2 3

X111X110

1 2 3X108

X90

12

3

60-250V DC/115 V AC

T4H250V24/48V DC

T2H250V

Lithium–Battery 3 V/1 Ah,Typ CR 1/2 AA

Fuse

G1

+ –

Cable Binder

Battery

Time Syn-chronization(Port A)

FrontOperator

ServicePort(Port C)

Panel

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Power Supply

Live Status Contact

Pickup Voltagesof BI1 to BI5

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 250 VDC and 115 VAC

Port CRS232/RS485

By repositioning jumpers the service interface (port C) can either be operated asRS232 port or as RS485 port.

The jumpers X105 to X110 must be plugged in the same way!

The jumpers are preset at the factory according to the configuration ordered.

Table 3-18 Jumper settings for the nominal voltage of the integrated power supply on theprocessor printed circuit board C-CPU-2

Jumper Nominal Voltage

24 to 48 VDC 60 to 125 VDC 110 to 250 VDC,115 VAC

X51 none 1–2 2–3

X52 none 1–2 and 3–4 2–3

X53 none 1–2 2–3

X55 none none 1–2

Table 3-19 Jumper setting for the quiescent state of the life contact on theprocessor printed circuit board C-CPU-2

Jumper Open in the quiescent state Closed in the quiescent state Presetting

X40 1–2 2–3 2–3

Table 3-20 Jumper settings of the control voltages of the binary inputs BI1 to BI5 on theprocessor printed circuit board C-CPU-2

Binary Inputs Jumper 19 VDC Pickup1) 88 VDC Pickup2)

BI1 X21 1–2 (L) 2–3 (H)

BI2 X22 1–2 (L)) 2–3 (H)

BI3 X23 1–2 (L)) 2–3 (H)

BI4 X24 1–2 (L) 2–3 (H)

BI5 X25 1–2 (L) 2–3 (H)

Table 3-21 Jumper settings of the integrated interface RS232/RS485 on the processorprinted circuit board C-CPU-2

Jumper RS232 RS485

X103 and X104 1–2 1–2

X105 to X110 1–2 2–3

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CTS With jumper X111, CTS is activated which is necessary for the communication withthe modem.

*) Presetting

Jumper setting 2–3: the connection to the modem is usually done with star coupleror optical fibre converter. Therefore the modem control signal according to RS232standard DIN 66020 is not available. Modem signals are not required since communi-cation to SIPROTEC® devices is always carried out in the half duplex mode. Use con-netion cable with ordering number 7XV5100–4.

Jumper setting 1–2: this setting makes the modem signal available, i. e. for a directRS232-connection between the SIPROTEC® device and the modem this setting canbe selected optionally. We recommend to use a standard RS232 modem connectioncable (converter 9-pole on 25-pole).

Note: For a direct connection to DIGSI® 4 with interface RS232 jumper X111 must beplugged in position 2–3.

Terminating Resis-tors

If there are no external matching resistors in the system, the last devices on aRS485-bus must be configured via jumpers X103 and X104.

Note: Both jumpers must always be plugged in the same way!

Currently no function is assigned to the jumper X90. The presetting is 1-2.

The terminating resistors can also be connected externally (e.g. to the connectionmodule). In this case, the terminating resistors located on the RS485 interface moduleor the resistors located directly on the processor circuit board C–CPU–2 must be dis-connected.

Table 3-22 Jumper setting of CTS (Clear-To-Send) on the processor printed circuitboard C-CPU-2

Jumper /CTS of interface RS232 /CTS controlled by /RTS

X111 1–2 2–3 *)

Table 3-23 Jumper setting of matching resistors of the interface RS485 on the processorprinted circuit board C–CPU–2

Jumper Matching resistorclosed

Matching resistoropen

Presetting

X103 2–3 1–2 1–2

X104 2–3 1–2 1–2

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Figure3-24 Termination of the RS 485 interface (external)

390 Ω

220 Ω

390 Ω

+5 V

A/A´

B/B´

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Input/Output BoardC–I/O–11

The layout of the printed circuit board for the input/output board C-I/O–11 is illustratedin Figure 3-25.

The set nominal currents of the current input transformer are checked on the input/out-put board C–I/O–11. The jumpers X60 to X63 must all be set to the same rated cur-rent, i.e. one jumper (X61 to X63) for each input transformer of the phase currents andin addition the joint jumper X60.The jumper X64 determines the rated current for the input IE and may thus have a set-ting that deviates from that of the phase currents.There is no jumper X64 for the version with sensitive earth current input.

For normal earth current inputs the jumper X65 is plugged in position “IE” and for sen-sitive earth current inputs in position “IEE”.

Figure3-25 The input/output board C-I/O–11 with the jumpers necessary for the control ofsettings

T8

T10

T11

T9

X60

(AD2)

L

X62

1A5A

12

3

X63

1A5A

12

3

X61

1A5A

12

3X

641A

5A

12

3

X65

IEEIE

X73 1 2 3

(AD1)

X72 1 2 3

(AD0)

X71 H

1A5A123

X21

1X

221

LM

HL

MH

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Pickup Voltagesof BI6 and BI 7

Table 3-24 Jumper setting of control voltages of the binary inputs BI6 and BI7 on thebinary input/output boards C– I/O–11

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 VAC

Bus Address The jumpers X71, X72 and X73 on the input/output board C–I/O–11 are for setting thebus address and must not be changed. Table 3-25 lists the jumper presettings.

Mounting location:

for housing size 1/3 in Figure 3-13, slot 19,for housing size 1/2 in Figure 3-14, slot 33,for housing size 1/1 in Figure 3-15, slot 33 right.

.

Binary Inputs Jumper 19 VDC Pickup1) 88 VDC Pickup2)

BI6 X21 L M

BI7 X22 L M

Table 3-25 Jumper setting of printed circuit board addresses of binary input/outputboards C-I/O-11

Jumper Presetting

X71 1–2 (H)

X72 1–2 (H)

X73 2–3 (L)

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Input/Output BoardB–I/O–2

The layout of the printed circuit board for the input/output board B–I/O–2 is illustratedin Figure 3-26.

Check for control voltages of binary inputs:

BI8 to BI20 (for housing size 1/2) according to Table 3-26.BI8 to BI33 (for housing size 1/1) according to Table 3-27.

The assignment of the binary inputs to the printed circuit board is shown in Figures3-14 and 3-15.

Figure3-26 The input/output board B–I/O–2 with the jumpers necessary for the settingcheck

X71

X213

12

X223

12

1 2 3

X72 1 2 3

X73 1 2 3

X243

12

X333

12

X323

12

X313

12

X303

12

X263

12

X283

12

X293

12

X273

12

X233

12

X253

12

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Pickup Voltagesof BI8 to BI20

Check for control voltages of binary inputs BI8 to BI20 (for housing size 1/2) accordingto Table 3-26.

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 VAC

Pickup Voltagesof BI8 to BI33

Check for control voltages of binary inputs BI8 to BI20 (for housing size 1/1) accordingto Table 3-27.

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 VAC

Table 3-26 Jumper setting of control voltages of the binary inputs BI8 and BI20 on thebinary input/output boards B–I/O–2 for version 7SJ642–... (Size 1/2)

Binary inputsJumper 19 VDC Pickup1) 88 VDC Pickup2)

Slot 19

BI8 X21 1–2 2–3

BI9 X22 1–2 2–3

BI10 X23 1–2 2–3

BI11 X24 1–2 2–3

BI12 X25 1–2 2–3

BI13 X26 1–2 2–3

BI14 X27 1–2 2–3

BI15 X28 1–2 2–3

BI16 X29 1–2 2–3

BI17 X30 1–2 2–3

BI18 X31 1–2 2–3

BI19 X32 1–2 2–3

BI20 X33 1–2 2–3

Table 3-27 Jumper setting of control voltages of the binary inputs BI8 and BI20 on thebinary input/output boards B–I/O–2 for version 7SJ645–... (Size 1/1)

Binary inputsJumper 19 VDC Pickup1) 88 VDC Pickup2)

Slot 33 left Slot 19 right

BI8 BI21 X21 1–2 2–3

BI9 BI22 X22 1–2 2–3

BI10 BI23 X23 1–2 2–3

BI11 BI24 X24 1–2 2–3

BI12 BI25 X25 1–2 2–3

BI13 BI26 X26 1–2 2–3

BI14 BI27 X27 1–2 2–3

BI15 BI28 X28 1–2 2–3

BI16 BI29 X29 1–2 2–3

BI17 BI30 X30 1–2 2–3

BI18 BI31 X31 1–2 2–3

BI19 BI32 X32 1–2 2–3

BI20 BI33 X33 1–2 2–3

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Bus address Jumpers X71, X72 and X73 on the input/output board B–I/O–2 are for setting the busaddress and must not be changed. Table 3-28 and 3-29 lists the jumper presettings.

The mounting locations are shown in Figures 3-14 and 3-15.

Table 3-28 Jumper setting of printed circuit board addresses of the binary input/outputboards B– I/O–2 for housing size 1/2

Jumper

Mountinglocation

Slot 19

X71 1–2

X72 2–3

X73 1–2

Tabelle 3-29 Jumper setting of printed circuit board addresses of the binary input/outputboards B– I/O–2 for housing size 1/1

JumperMounting location

Slot 19 right Slot 33 left

X71 1–2 2–3

X72 2–3 1–2

X73 1–2 1–2

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Input/Output BoardC–I/O–1

The layout of the printed circuit board for the input/output board C-I/O–1 is illustratedin Figure 3-27.

The selected operating voltage of the binary inputs BI8 to BI15 is checked accordingto Table 3-30.

The contacts of the output relay BO6 can be changed from normally open to normallyclosed operation. The selected contact mode is checked according to Table 3-32.

The mounting locations are shown in Figure 3-14.

Figure3-27 The input/output board C–I/O–1 with the jumpers necessary for the control ofsettings

HL

M

X22

X21

HL

M

X24

X23

HL

M

X26

X25

HL

M

X28

X27

HL

M

X30

X29

HL

M

X32

X31

HL

M

X34

X33

HL

M

X36

X35

X40

3

1

2

X71 (AD0)H L

X72 (AD1)X73 (AD2)

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Pickup Voltagesof BI8 to BI 15

1) Factory settings for devices with power supply voltages of 24 VDC to 125 VDC2) Factory settings for devices with power supply voltages of 110 VDC to 250 VDC and 115 VAC

Contact mode For the version 7SJ641∗ – the contacts of binary output BO6 can be changed from nor-mally open to normally closed operation. Table 3-31 shows the jumper settings for thecontact mode.

Bus address The jumpers X71, X72 and X73 on the input/output board C–I/O–1 are for setting thebus address and must not be changed. Table 3-32 lists the jumper presettings.

The mounting location of the PCB is illustrated in Figure 3-14.

Table 3-30 Jumper settings for the Pick-up Voltages of the binary inputs BI8 to BI15 on theinput/output board C–I/O–11 for 7SJ641 (housing size 1/2)

Binary Inputs Jumper 19 VDC Pickup1) 88 VDC Pickup2)

BI8 X21/X22 L M

BI9 X23/X24 L M

BI10 X25/X26 L M

BI11 X27/X28 L M

BI12 X29/X30 L M

BI13 X31/X32 L M

BI14 X33/X34 L M

BI15 X35/X36 L M

Table 3-31 Jumper setting for the contact mode of output BO6 on the input/output boardC– I/O–1

Device version7SJ641∗ –

for Jumper Open in quiescentstate (NO)

Closed in quiescent state(NC) Presetting

BO6 X40 1–2 2–3 1–2

Table 3-32 Jumper setting of printed circuit board addresses of binary input/outputboards C–I/O–1 for 7SJ641

Jumper Presetting

X71 H

X72 L

X73 H

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3.1.3.6 Interface Modules

Exchanging Inter-face Modules

The interface modules are located on the processor printed circuit boards CPU ( inFigure 3-10 to 3-15) of the devices 7SJ62/63/64. Figure 3-28 shows the printed circuitboard and the modules.

Figure3-28 Processor printed circuit board CPU with interface modules

Please note the following:

Only interface modules of devices with panel flush mounting and cubicle mountingas well as of mounting devices with detached operator panel or without operatorpanel can be exchanged. Interface modules of devices in surface mounting hous-ings with double-level terminals must be exchanged in our manufacturing centre.

System interface

Mounting Location(Rear Side of Housing)

Service interface (7SJ62/63)

Port B

Port C (7SJ62/63)additional port (7SJ64) Port D (7SJ64)

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• Use only interface modules that can be ordered in our facilities(see also Appendix A, Section A.1.1).

• You may have to ensure the termination of the ports featuring bus capability accord-ing to the marging heading “Termination“.

1) for 7SJ64 the Port C / service port is fix, it is not a plug-in module

For the order numbers of the exchangeable modules please refer to Subsection A.1.6Accessories in the Appendix.

RS232/RS485 The interface RS232 can be modified to interface RS485 and vice versa, according toFigure 3-30.

Figure 3-28 shows the printed circuit board C–CPU and the interface modules.

Figure 3-29 shows the location of the jumpers of interface RS232 on the interfacemodule.

Terminating resistors are not required. They are disconnected.

Table 3-33 Exchangeable interface modules

Interface Mounting Location/Port Exchange Modules

System Interface(7SJ62/63/64)

B

RS232

RS485

Optical 820 nm

Profibus FMS RS485

Profibus FMS Double Ring

Profibus FMS Single Ring

Profibus DP RS485

Profibus DP Double Ring

Modbus RS485

Modbus 820 nm

DNP 3.0 RS485

Optical DNP 3.0 820 nm

DIGSI® 4/Modem Inter-face/RTD-Box(7SJ62/63)1)

C

RS232

RS485

Optical 820 nm

Additional Interface /RTD-Box(7SJ64)

DRS485

Optical 820 nm

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Figure 3-29 Location of the jumpers for configuration of RS232

CTS With jumper X11, CTS is activated which is necessary for the communication with themodem.

*) Default Setting

Jumper setting 2–3: the connection to the modem is usually done with star coupleror optical fibre converter. Therefore the modem control signal according to RS232standard DIN 66020 is not available. Modem signals are not required since communi-cation to SIPROTEC® devices is always carried out in the half duplex mode. Use con-netion cable with ordering number 7XV5100–4.

Jumper setting 1–2: this setting makes the modem signal available, i. e. for a directRS232-connection between the SIPROTEC® device and the modem this setting canbe selected optionally. We recommend to use a standard RS232 modem connectioncable (converter 9-pole on 25-pole).

Note: For a direct connection to DIGSI® 4 with interface RS232 jumper X11 must beplugged in position 2–3.

RS485/RS232 Interface RS485 can be modified to interface RS232 and vice versa, according to Fig-ure 3-29.

Termination Busbar capable interfaces require a termination at the last device of the bus, i.e. ter-minating resistors must be connected. For 7SJ62/63/64 this applies to the variant withinterface RS485 or Profibus.

The terminating resistors are located on the corresponding interface module that ismounted to the processor input/output board CPU ( in Figure 3-10 to 3-15).

X31 32

X101 32

8X

1

32

X121 32

C53207-A324-B180

1

32 X

11

X6X7X4X5

1 32

1

32

X13

JumperTerminating Resistors

disconnected

X3 1–2 *)

X4 1–2 *)

*) Default Setting

Tabelle 3-34 Jumper setting of CTS (Clear-To-Send) on the interface module

Jumper /CTS from interface RS232 /CTS triggered by /RTS

X11 1–2 2–3 *)

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The module for interface RS485 is illustrated in Figure 3-30, the module for Profibus(FMS and DP) and DNP3.0 and Modbus in Figure 3-31.

With default setting, jumpers are plugged in such a way that terminating resistors aredisconnected.

For the configuration of the terminating resistors both jumpers have to be plugged inthe same way.

Figure3-30 Location of jumpers for the configuration of terminating resistors of interfaceRS485

Profibus (FMS/DP)DNP3.0/Modbus

Figure 3-31 Location of jumpers for the configuration of terminating resistors at the interface Profibus (FMS and DP),DNP3.0 and Modbus

The terminating resistors can also be connected externally (e.g. to the connectionmodule) as illustrated in Figure 3-24. In this case, the terminating resistors located onthe interface module must be disconnected.

X31 32

X101 32

8X

1

32

X121 32

C53207-A324-B180

1

32 X

11

X6X7X4X5

1 32

1

32

X13

JumperTerminating Resistors

connected disconnected

X3 2–3 1–2 *)

X4 2–3 1–2 *)

*) Default Setting

X33 12

X43 12Jump-

er

Terminating Resistors

connected disconnected

X3 1–2 2–3 *)

X4 1–2 2–3 *)

C53207-A322- 2 3 4B100B101

*)Default Setting

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3.1.3.7 Reassembly of Device

To reassemble the device, proceed as follows:

Carefully insert the boards into the case. The installation locations of the boards areshown in Figure 3-10 to 3-15.For the model of the device designed for surface mounting, use the metal lever to in-sert the processor circuit board CPU board. The installation is easier with the lever.

First plug the plug connectors of the ribbon cable into the input/output boards I/O andthen onto the processor module CPU. Be careful to not bend any of the connectingpins! Do not use force!

Insert the plug connector of the ribbon cable between the processor moduleCPU and the front cover into the socket of the front cover.For the version with detached operator panel the latter is to be ignored. Instead theplug connector of the ribbon cable connected to a 68pole plug connector on the rearside of the device must be plugged into the plug connector of the processor circuitboard CPU. The 7-pole plug connector X16 connected to the ribbon cable must beplugged behind the D-subminiature female connector. Since the connection is protect-Press the latches of the plug connectors together.

Replace the front cover and secure to the housing with the screws.

Replace the covers.

Re-fasten the interfaces on the rear of the device housing.This activity is not necessary if the device is designed for surface mounting.

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3.2 Checking Connections

3.2.1 Data Connections

The following tables list the pin-assignments for the various serial interfaces of the de-vice and the time synchronization interface. The position of the connections can beseen in Figure 3-32.

Figure3-32 9 pin D-subminiature Connector

PC OperatingInterface at Front

When the recommended communication cable is used, correct connection betweenthe SIPROTEC® device and the PC is automatically ensured. See the Appendix, Sub-section A.1 for an ordering description of the cable.

ServicePort

Check the data connection if the service (port C) is used to communicate with the de-vice via fix wiring or a modem. If the service port is used as input for one or two ther-moboxes, verify the interconnection according to one of the connection examples giv-en in the Appendix A.3.4.

System (SCADA)Interface

When a serial interface of the device is connected to a central substation control sys-tem, the data connection must be checked. A visual check of the transmit channel andthe receive channel is important. Each connection is dedicated to one transmission di-rection. The data output of one device must be connected to the data input of the otherdevice, and vice versa.

The data cable connections are designated in sympathy with DIN 66020 and ISO2110 (see also Table 3-35):

− TxD data transmit

− RxD data receive

− RTS request to send

− CTS clear to send

− DGND signal/chassis ground

P-Sl

ave

AME

RS23

2RS

232-

LWL RS

485

16

59

rear side

59

16

Oprerating Interfacefront side

16

59

Serial System InterfacesTime Synchronization

rear sideand Service Interface

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The cable shield is to be grounded at both ends so that potential differences cannotcause circulating currents to flow along the shield. In areas of extremely strong EMCinterferences, the interference immunity factor can be improved by leading the groundwire in a separate shielded pair of strands.

Additional Interface(only7SJ64)

The additional interface available only for 7SJ64 (port D) serves for signal injection ofone or two thermoboxes. The interconnection according to one of the connection ex-amples in Appendix (A.3.4) must be checked.

.

*) Pin 7 also can carry the RS 232 RTS signal to an RS 485 interface. Pin 7 must thereforenot be connected!

Termination The RS485 interface is capable of half-duplex service with the signals A/A' and B/B'with a common relative potential C/C' (DGND). Verify that only the last device on thebus has the terminating resistors connected, and that the other devices on the bus donot. The jumpers for the terminating resistors are on the interface module RS485(Figure 3-30) or on the Profibus module RS485 (Figure 3-31) or for 7SJ64 also directlyon C–CPU–2 (see Figure 3-23 and Table 3-23). The terminating resistors can also beconnected externally (e.g. to the connection module) as illustrated in Figure 3-24. Inthis case, the terminating resistors located on the RS485 or the Profibus interfacemodule or directly on the printed circuit board of the C–CPU–2 board of 7SJ64 mustbe disconnected.

If the bus is extended, make sure again that only the last device on the bus has theterminating resistors switched-in, and that all other devices on the bus do not.

Table 3-35 Installation of the D-Subminiature Port

Pin No. PC Interfaceat Front

RS 232 RS 485 Profibus FMS Slave, RS 485Profibus DP Slave, RS485

Modbus, RS485DNP3.0, RS485

1 Shield (with shield ends electrically connected)

2 RxD RxD – – –

3 TxD TxD A/A’ (RxD/TxD–N) B/B’ (RxD/TxD–P) A

4 – – – CNTR–A (TTL) RTS (TTL Pegel)

5 GND GND C/C’ (GND) C/C’ (GND) GND1

6 – – – + 5 V voltage supply(max. load < 100 mA)

VCC1

7 RTS RTS –*) –*) –

8 CTS CTS B/B’ (RxD/TxD–P) A/A’ (RxD/TxD–N) B

9 – – – – –

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TimeSynchronizationInterface

Either 5-VDC-, 12-VDC- or 24-VDC- time synchronization signals can be processed ifthe connections are made as indicated in Table 3-36.

Optical Fibers Signals transmitted via optical fibers are unaffected by interference. The fibers guar-antee electrical isolation between the connections. Transmit and receive connectionsare shown with the symbols for transmit and for receive.

The normal setting for the optical fiber interface is”Light off.” If this setting is to bechanged, use the operating program DIGSI® 4, as described in the SIPROTEC® 4–System Manual.

TemperatureMeter (Thermobox)

If one or two 7XV566 temperature meters are connected, check their connections tothe ports (port C or D).

Verify also the termination: the terminating resistors must be connected to 7SJ62/63/64 (see Subsection 3.1.3.6 at “Termination“.

For further information refer to the operating manual of 7XV566. Check the transmis-sion settings at the temperature meter. Besides the baudrate and the parity observealso the bus number.

• For connection of one 7XV566 thermobox:Bus number = 0 (to be set at 7XV566)

• For connection of two 7XV566 thermoboxes:Bus number = 1 for the 1st thermobox (to be set at 7XV566 for RTD1 to 6),Bus number = 2 for the 2nd thermobox (to be set at 7XV566 for RTD7 to 12).

Please observe that the detector input 1 (RTD1) of the 1st thermobox is reserved forthe input of the ambient temperature/coolant temperature for the overload protection.

Table 3-36 Pin-assignments for the D-subminiature port of the Time SynchronizationInterface

Pin-No.

Designation Signal Meaning

1 P24_TSIG Input 24 V

2 P5_TSIG Input 5 V

3 M_TSIG Return Line

4 –*) –*)

5 Shield Shield Potential

6 – –

7 P12_TSIG Input 12 V

8 P_TSYNC*) Input 24 V*)

9 Shield Shield Potential*) assigned, but not available

Warning!Laser injection! Do not look directly into the fibre-optic elements!

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3.2.2 Checking Power Plant Connections

If an undervoltage element (27) is enabled and ON and the current supervision of the27 element is OFF, then the 27 element will immediately trip when voltage is removedfrom the device. This will prevent the user from being able to set the device or performother actions. To avoid this possible problem, current supervision must be set ON orthe voltage protection must be blocked. This can be accomplished via the operation(see note in Subsection 2.5.2.2).

Before the device is energized for the first time, the device should be in the final oper-ating environment for at least 2 hours to equalize the temperature, to minimize humid-ity and avoid condensation. Connection are checked with the device at its final loca-tion. The plant must first be switched off and grounded.

Protective switches (e.g. test switches, fuses, or miniature circuit breakers) for thepower supply and the measured voltages must be opened.

Check the continuity of all current and voltage transformer connections against thesystem and connection diagrams:

Are the current transformers grounded properly?

Are the polarities of the current transformers the same?

Is the phase relationship of the current transformers correct?

Are the voltage transformers grounded properly?

Are the polarities of the voltage transformers correct?

Is the phase relationship of the voltage transformers correct?

Is the polarity for current input I4 correct (if used), also refer to Subsection 3.1.2,“Currents“?

Is the polarity for voltage input U4 correct (only 7SJ64 and if used, e.g. with brokendelta winding or busbar voltage), cf. also Subsection 3.1.2.3 “Connection Examplesfor 7SJ64“.

Check the functions of all test switches that may be installed for the purposes of sec-ondary testing and isolation of the device. Of particular importance are test switchesin current transformer circuits. Be sure these switches short-circuit the current trans-formers when they are in the test mode (open).

Warning!The following procedures are carried out with dangerous voltages present. Therefore,only qualified people who are familiar with and adhere to the safety procedures andprecautionary measures shall perform the procedures.

Caution!

Operating the device on a battery charger without a connected battery can lead to un-usually high voltages and consequently, the destruction of the device. For limit valuessee Sub-section 4.2.1 under Technical Data.

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The short-circuit feature of the current circuits of the device are to be checked. Anohmmeter or other test equipment for checking continuity is needed.

Remove the front panel of the device (see Figure 3-10 to 3-15).

Remove the ribbon cable connected to the I/O board with the measured current andmeasured voltage inputs (on the front side it is the right printed circuit board, forhousing size 1/3, see Figure 3-10 [slot 19], for housing size 1/2 see Figure 3-11 or3-14 [slot 33], for housing size 1/1 see Figure 3-12 or 3-15 [slot 33 right]). Further-more, remove the printed circuit board so that there is no more contact anymorewith the plug-in terminal.

At the terminals of the device, check continuity for each pair of terminals that re-ceives current from the CTs.

Firmly re-insert the I/O board. Carefully connect the ribbon cable. Do not bend anyconnector pins! Do not use force!

Check continuity for each of the current terminal-pairs again.

Attach the front panel and tighten the screws.

Connect an ammeter in the supply circuit of the power supply. A range of about 1 Afor the meter is appropriate.

Close the protective switches to apply voltage to the power supply. The measuredsteady state current should be insignificant. Transient movement of the ammetermerely indicates the charging current of capacitors.

Check the polarity and magnitude of the voltage at the device terminals.

Remove the voltage from the power supply by opening the protective switches.

Disconnect the measuring test equipment; restore the normal power supply connec-tions.

Apply voltage to the power supply.

Close the protective switches for the voltage transformers.

Verify that the voltage phase rotation at the device terminals is correct. Note that thedevice can be set for ABC rotation or ACB rotation under Address 0209 PHASE SEQ.in P.System Data1.

Open the protective switches for the voltage transformers and the power supply.

Check the trip and close circuits to the power system circuit breakers and the otherprimary equipment that is to be controlled by the 7SJ62/63/64.

Verify that the control wiring to and from other devices is correct.

Check the signalling connections.

Close the protective switches to apply voltage to the power supply.

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3.3 Commissioning

When testing the device with secondary test equipment, make sure that no other mea-surement quantities are connected and that the trip and close commands to the circuitbreakers and other primary switches are disconnected from the device unless ex-pressly stated.

For the commissioning switching operations have to be carried out. A prerequisite forthe prescribed tests is that these switching operations can be executed without dan-ger. They are accordingly not meant for operational checks.

Warning!When operating an electrical device, certain parts of the device inevitably have dan-gerous voltages. Severe personal injury or property damage can result if the device isnot handled properly.

Only qualified people shall work on and around this device after becoming thoroughlyfamiliar with all warnings and safety notices in this instruction manual as well as withthe applicable safety steps, safety regulations, and precautionary measures.

The main points to observe are:

• The device is to be grounded to the substation ground before any other connectionsare made.

• Hazardous voltages can exist in the power supply and at the connections to currenttransformers, voltage transformers, and test circuits.

• Hazardous voltages can be present in the device even after the power supply volt-age has been removed, i.e. capacitors can still be charged.

• After removing voltage from the power supply, wait a minimum of 10 seconds be-fore re-energizing the power supply. This wait allows the initial conditions to be firm-ly established before the device is re-energized.

• The limit values given in Technical Data (Chapter 10) must not be exceeded, neitherduring testing nor during commissioning.

DANGER!Current transformer secondary circuits must be short-circuited before the cur-rent leads to the device are disconnected!

If test switches are installed that automatically short-circuit the current transformer cir-cuits, opening these test switches (placing them in the "Test" position) is sufficient pro-vided the short-circuit function has been previously tested.

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3.3.1 Testing mode and transmission blocking

If the SIPROTEC®4 device is connected to a central or main computer system via theSCADA interface, then the information that is transmitted can be influenced. This isonly possible with some of the protocols availabel (see Table “Protocol-dependentfunctions” in the Appendix).

If Test mode is set ON, then a message sent by the device to the main system hasan additional test bit. This bit allows the message to be recognized as resulting fromtesting and not an actual fault or power system event.

If DataStop is set ON, transmission to the SCADA is blocked.

Both of these features should be checked. The procedures for setting Test mode andDataStop are described in the SIPROTEC® 4 System Manual. Note that whenDIGSI® 4 is being used, the program must be in the Online operating mode for thetest features to be used.

3.3.2 Checking the System (SCADA) Interface

PreliminaryRemarks

Provided that the device is equipped with a system (SCADA) interface that is used forthe communication with a substation, it is possible to test via the DIGSI® 4 operationalfunction if messages are transmitted correctly. Do not apply this test function in thereal operating mode of the device.

Warning!Primary test may only be carried out by qualified personnel, who are familiar with thecommissioning of protection systems, the operation of the plant and the safety rulesand regulations (switching, earthing, etc.).

DANGER!The transmission and reception of messages via the system (SCADA) interfaceby means of the testing mode is the real exchange of information between theSIPROTEC®4 device and the substation. Connected equipment such as circuitbreakers or disconnectors can be operated as a result of these actions!

Note:

After termination of this test, the device will reboot. All annunciation buffers areerased. If required, these buffers should be extracted with DIGSI® 4 prior to the test.

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The system interface test is carried out Online using DIGSI® 4:

Double-click on the Online directory to open the required dialogue box.

Click on Test and the functional options appear on the right side of the window.

Double-click on Testing Messages for System Interface shown in the listview. The dialogue box Testing System Interface opens (refer to 3-33).

Structure of theDialogue Box

In the column Indication, all message texts that were configured for the system in-terface in the matrix will then appear. In the column Status Scheduled the user hasto define the value for the messages to be tested. Depending on the type of messagedifferent entering fields are available (e.g. message ON / message OFF). By double-clicking onto one of the fields the required value can be selected from the list.

Figure 3-33 Dialog Box: Generate indications

Changing theOperating State

Clicking for the first time onto one of the field in column Action you will be asked forpassword n° 6 (for hardware test menus). Having entered the correct password mes-sages can be issued. To do so, click on Send. The corresponding message is issuedand can be read out either from the event log of the SIPROTEC®4 - device or from thesubstation.

As long as the windows is open, further tests can be performed.

Test in MessageDirection

For all information that is transmitted to the central station the following is tested inStatus Scheduled:

Make sure that each checking process is carried out carefully without causing anydanger (see above and refer to DANGER!)

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Click on Send and check whether the transmitted information reaches the centralstation and shows the desired reaction.

Exiting the TestMode

To end the System Interface Test, click on Close. The device is briefly out of servicewhile the start-up routine is executed. The dialogue box closes.

Test in CommandDirection

The information beginning with “>” is transmitted towards the device. This kind of in-formation must be indicated by the central station. Check whether the reaction is cor-rect.

f

3.3.3 Checking the Binary Inputs and Outputs

Preliminary Notes The binary inputs, outputs, and LEDs of a SIPROTEC®4 device can be individuallyand precisely controlled using DIGSI® 4. This feature is used to verify control wiringfrom the device to plant equipment during commissioning. This test feature shall notbe used while the device is in service on a live system.

Note: After termination of the hardware test, the device will reboot. Thereby, all annun-ciation buffers are erased. If required, these buffers should be extracted with DIGSI® 4prior to the test.

The hardware test can be done using DIGSI® 4 in the online operating mode:

Open the Online directory by double-clicking; the operating functions for the de-vice appear.

Click on Test; the function selection appears in the right half of the screen.

Double-click in the list view on Hardware Test. The dialogue box of the samename opens (see Figure 3-34).

DANGER!Changing the status of a binary input or output using the test feature of DIGSI® 4results in an actual and immediate corresponding change in the SIPROTEC® de-vice. Connected equipment such as circuit breakers or disconnectors will beoperated as a result of these actions!

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Figure3-34 Dialogue box for hardware test — example

Structure of theTest Dialogue Box

The dialogue box is divided into three groups: BI for binary inputs, REL for outputrelays, and LED for light-emitting diodes. Each of these groups is associated with anappropriately marked switching area. By double-clicking in an area, components with-in the associated group can be turned on or off.

In the Status column, the present (physical) state of the hardware component isdisplayed. The binary inputs and outputs are indicated by an open or closed switchsymbol, the LEDs by a dark or illuminated LED symbol.

The possible intended condition of a hardware component is indicated with clear textunder the Scheduled column, which is next to the Status column. The intendedcondition offered for a component is always the opposite of the present state.

The right-most column indicates the commands or messages that are configured(masked) to the hardware components.

Changing theHardwareConditions

To change the condition of a hardware component, click on the associated switchingfield in the Scheduled column.

Password No. 6 (if activated during configuration) will be requested before the firsthardware modification is allowed. After entry of the correct password a conditionchange will be executed.

Further condition changes remain possible while the dialog box is open.

Test of the BinaryOutputs

Each individual output relay can be energized allowing a check of the wiring betweenthe output relay of the 7SJ62/63/64 and the plant, without having to generate the mes-sage that is assigned to the relay. As soon as the first change of state for any one ofthe output relays is initiated, all output relays are separated from the internal devicefunctions, and can only be operated by the hardware test function. This implies that a

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switching signal to an output relay from e.g. a protection function or control commandcannot be executed.

Ensured that the switching of the output relay can be executed without danger (seeabove under DANGER!).

Each output relay must be tested via the corresponding Scheduled–cell in the di-alog box.

The test sequence must be terminated (refer to margin heading “Exiting the Proce-dure”), to avoid the initiation of inadvertent switching operations by further tests.

Test of the BinaryInputs

To test the wiring between the plant and the binary inputs of the 7SJ62/63/64 the con-dition in the plant which initiates the binary input must be generated and the responseof the device checked.

To do this, the dialogue box Hardware Testmust again be opened to view the phys-ical state of the binary inputs. The password is not yet required.

Each state in the plant which causes a binary input to pick up must be generated.

The response of the device must be checked in the Status–column of the dialoguebox. To do this, the dialogue box must be updated. The options may be found belowunder the margin heading “Updating the Display”.

If however the effect of a binary input must be checked without carrying out any switch-ing in the plant, it is possible to trigger individual binary inputs with the hardware testfunction. As soon as the first state change of any binary input is triggered and thepassword nr. 6 has been entered, all binary inputs are separated from the plant andcan only be activated via the hardware test function.

Terminate the test sequence (see above under the margin heading „Exiting the Pro-cedure“).

Test of the LED’s The LED’s may be tested in a similar manner to the other input/output components.As soon as the first state change of any LED has been triggered, all LEDs are sepa-rated from the internal device functionality and can only be controlled via the hardwaretest frunction. This implies that no LED can be switched on anymore by e.g. a protec-tion function or operation of the LED reset key.

Updating theDisplay

When the dialog box Hardware Test is opened, the present conditions of the hard-ware components at that moment are read in and displayed. An update occurs:

− for each harware component, if a command to change the condition is successfullyperformed,

− for all hardware components if the Update button is clicked,

− for all hardware components with cyclical updating if the Automatic Update (20sec) field is marked.

Exiting theProcedure

To end the hardware test, click on Close. The dialog box closes. The device becomesunavailable for a brief start-up period immediately after this. Then all hardware com-ponents are returned to the operating conditions determined by the plant settings.

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3.3.4 Tests for the Circuit Breaker Failure Protection

If the device provides a breaker failure protection and if this is used, the integration ofthis protection function in the system must be tested under practical conditions.

Due to the variety of application options and the available system configurations, it isnot possible to make a detailed description of the necessary tests. It is important toconsider the local conditions and the protection and plant drawings.

It is advised to isolate the circuit breaker of the tested feeder at both sides, i.e. to keepthe busbar isolator and the line isolator open, in order to ensure operation of the break-er without risk.

The trip command of the tested Multi-Functional Protective Relay is made ineffectiveso that the local breaker can be tripped only by the breaker failure protection functionof 7SJ62/63/64.

Although the following lists do not claim to be complete it may also contain pointswhich are to be ignored in the current application.

Circuit BreakerAuxiliary Contacts

If the circuit breaker auxiliary contacts are connected to the device, these provide anessential input to the functionality of the breaker failure protection. Make sure thecorrect assignment has been checked (Section 3.3.3).

External StartConditions

If the breaker failure protection can also be started by external protection devices, theexternal start conditions should be checked.

In order for the breaker failure protection to be started, a current must flow at least viathe monitored phase. This may be a secondary injected current.

Starting by trip command of the external protection:binary input functions “>50BF ext SRC“ (FNo 01431) (in spontaneous or faultmessages).

After every start, the message “50BF ext Pickup“ (FNo 01457) must appear inthe spontaneous or fault messages.

After time expiration TRIP-Timer (address 7005) tripping command of the circuitbreaker failure protection.

Switch off test current.

If BF start is possible without current flow:

To close the circuit breaker to be monitored to both sides with the disconnectorswitches open.

Caution!

Also for tests on the local circuit breaker of the feeder a trip command to the surround-ing circuit breakers can be issued for the busbar. Therefore the tripping of the sur-rounding circuit breakers (busbar) must be deactivated, e. g. by switching off the cor-responding control voltages.Nevertheless ensure that trip remains possible in case ofa real primary fault if parts of the power plant are in service.

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BF start by trip command of the external protection without current flow:binary input functions “>50BF ext SRC“ (FNo 01431) ((in spontaneous or faultmessages).

After every start, the message “50BF ext Pickup“ (FNo 01457) must appear inthe spontaneous or fault messages.

After time expiration TRIP-Timer (address 7005) tripping command of the circuitbreaker failure protection.

Opening the circuit breaker again.

Busbar tripping For testing the distribution of the trip commands in the substation in the case of break-er failures it is important to check that the trip commands to the surrounding circuitbreakers is correct.

The surrounding circuit breakers are all those which need to trip when the feeder cir-cuit breaker fails. These are therefore the circuit breakers of all feeders which feed thebusbar or busbar section to which the feeder with the fault is connected.

A general detailed test guide cannot be specified because the layout of the surround-ing circuit breakers largely depends on the switchgear topology.

In particular with multiple busbars the trip distribution logic for the surrounding circuitbreakers must be checked. Here it should be checked for every busbar section that allcircuit breakers which are connected to the same busbar section as the feeder circuitbreaker under observation are tripped, and no other breakers.

Tripping of theRemote End

If the trip command of the circuit breaker failure protection must also trip the circuitbreaker at the remote end of the feeder under observation, the transmission channelfor this remote trip must also be checked.

Termination All temporary measures taken for testing must be undone, e.g. especially switchingstates, interrupted trip commands, changes to setting values or individually switchedoff protection functions.

3.3.5 Testing User-Defined Functions

A 7SJ62/63/64 has a vast capability for allowing functions to be defined by the user,especially with the CFC logic. Any special function or logic added to the device mustbe checked.

Naturally, general test procedures cannot be given. Rather, the configuration of theseuser-defined functions and the necessary associated conditions must be known andverified. Of particular importance are the possible interlocking conditions of the circuitbreakers and other primary switching devices. They must be considered and tested.

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3.3.6 Current, Voltage, and Phase Rotation Testing

Load Current≥ [10% IN]

The connections of the current and voltage transformers are tested using primaryquantities. Secondary load current of at least 10 % of the nominal current of the deviceis necessary. With proper connections of the measuring circuits, none of the mea-sured-values supervision elements in the device should pick up. If an element detectsa problem, the relevant condition can be viewed in the Event Log. If current summationerrors occur, then check the matching factors. See Subsection ).

Messages from the symmetry monitoring could occur because there actually areasymmetrical conditions in the network. If these asymmetrical conditions are normalservice conditions, the corresponding monitoring functions should be made less sen-sitive. See Subsection 2.10.2).

Current andVoltage Values

Currents and voltages can be seen in the display field on the front of the device underMeasurement. The quantities can also be viewed under Measurement in theDIGSI® 4 window. The currents and voltages displayed by the device can be com-pared to the quantities measured by an independent source.

If the measured values are not plausible, the connection must be checked and correct-ed after the line has been isolated and the current transformer circuits have beenshort-circuited. The measurements must then be repeated.

Phase Rotation The phase rotation must correspond to the configured phase rotation, in general aclockwise phase rotation. If the system has an anti-clockwise phase rotation, this musthave been considered when the power system data was set (address 0209 PHASE SEQ., refer to Subsection ). If the phase rotation is incorrect, the alarm “Fail Ph. Seq.“ (FNo 00171) is generated. The measured value phase allocation must bechecked and corrected, if required, after the line has been isolated and current trans-formers have been short-circuited. The phase rotation check must then be repeated.

VoltageTransformerMiniature CircuitBreaker (VT mcb)

The VT mcb of the feeder must be opened. The measured voltages in the operationalmeasured values appear with a value close to zero (small measured voltages are ofno consequence).

Check in the spontaneous messages that the VT mcb trip was entered (message“>FAIL:FEEDER VT ON“ in the spontaneous messages). Beforehand it has to be as-sured that the position of the VT mcb is connected to the device via a binary input.

Close the VT mcb: The above messages appear under the spontaneous messagesas “OFF”, i.e. “>FAIL:FEEDER VT OFF“.

If one of the events does not appear, the connection and routing of these signalsmust be checked.

If the “ON“–state and “OFF“–state are swapped, the contact type (H–active or L–active)must be checked and remedied.

7SJ64 only If a busbar voltage is used (for synchronism check) and the assigned VT mcb is con-nected to the device, the following function must also be checked:

If the VT mcb is open the message “>FAIL: BUS VT ON“ appears, if it is closed themessage “>FAIL: BUS VT OFF“ is displayed.

Switch off the protected power line.

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3.3.7 Testing the Reverse Interlocking Scheme (if applicable)

This testing causes trip contacts of the 7SJ62/63/64 to close. If tripping of the relevantcircuit breakers and primary interrupting devices is to be avoided, the 7SJ62/63/64 tripcontacts must be isolated. Proper backup relaying should exist.

An operational check of the reverse interlocking scheme might cause tripping by theprotective relays that block the 7SJ62/63/64 (depending on the procedure used). If theblocking relays will trip, the trip contacts that control primary interrupting devices mustbe isolated if the devices are not to be operated. Again, proper backup relaying shouldexist.

Simple methods of testing and operational checking a reverse interlocking scheme areillustrated with an example. In this example, the 50-2 element and the 50N-2 elementof the 7SJ62/63/64 are employed in a reverse interlocking scheme that provides busprotection in a radial distribution system with three feeders. The tripping of both ele-ments is blocked when Binary Input 1 is energized. The input mask is [>BLOCK 50-2 (H) or >BLOCK 50N-2 (H)]. The elements have slight time delays to provide co-ordination with the blocking protective relays. The blocking relays are the three feederrelays. Each feeder relay has a blocking contact programmed to close when the 51element or 51N element picks up. The three contacts are connected in parallel to applycontrol voltage to Binary Input 1 when any one of them closes.

An actual scheme might employ elements and binary inputs other than those given inthe example. The binary inputs could also be set to block tripping when the inputs arede-energized. The blocking devices might be configured differently as well. In anycase, testing and operationally checking a reverse interlocking scheme are typicallysimple. The procedures below can be adapted as needed.

With the 7SJ62/63/64 isolated from the current transformers and tripping circuits, in-ject test current into any one phase current input and the ground current input. Slowlyramp-up the current until the pickup values of 50-2 and 50N-2 are found (monitor con-tacts or LEDs). Slowly decrease the current until the dropout values are found. Verifythat the pickup and dropout values are as expected.

The time delays of the elements can be measured with a timer set to start on the ap-plication of current and stop on the closure of the trip contact masked to close wheneither 50-2 or 50N-2 trips. Test one element at a time. For either element, first set thetime delay for 0.00 second. Suddenly apply current greater than the pickup value.Record the time. Repeat the test with the time delay included. The difference betweenthe results provides an estimate of the time delay. Be sure the time delays are as ex-pected.

The tripping block can be verified by manually applying voltage to Binary Input 1, andinjecting a test current above the pickup of the element under consideration, for a timeperiod much longer than the time delay setting.

To operationally check the scheme, current can be simultaneously injected into the7SJ62/63/64 and one of the feeder relays. The feeder relay must be isolated from cur-rent transformers and trip circuits of primary equipment. Proper backup relaying

Caution!

During testing, observe the current ratings of the inputs given in Technical Data, Sub-section 4.1.1. Allow a cool-down period if the continuous ratings are exceeded.

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should be available. The magnitude of the test current must be high enough to pickupboth the feeder blocking element and the 7SJ62/63/64 tripping element. (The blockingelement could be less sensitive in secondary terms.) Suddenly apply the current andverify that 50-2 and 50N-2 are blocked. Suddenly remove the current and verify that50-2 and 50N-2 do not trip. If the blocking element has an equal or higher sensitivitythan the tripping element, then tests in which the current is slowly decreased can bedone to verify that there are no element dropout-miscoordinations.

Repeat the testing for each blocking device.

Restore the current and tripping circuits of the 7SJ62/63/64 and the feeder relays.

3.3.8 Directional Checks with Load Current

Load Current≥ 10 % IN

The connections of the current and voltage transformers are checked using load cur-rent on the protected line. The secondary load current must be at least 0.10 · IN. Theload current should be in-phase or lagging the voltage (resistive or resistive-inductiveload). The direction of the load current must be known. If there is a doubt, networkloops should be opened or other action taken to guarantee the direction of the loadcurrent. The line remains energized during this directional test.

DThe direction can be derived directly from the operational measured values. Initiallythe correlation of the measured load direction with the actual direction of load flow ischecked. In this case the normal situation is assumed whereby the forward direction(measuring direction) extends from the busbar towards the line (Figure 3-35).

P positive, if active power flows into the line,

P negative, if active power flows towards the busbar,

Q positive, if reactive power flows into the line,

Q negative, if reactive power flows toward the busbar.

Figure 3-35 Apparent Power

Positive Reactive PowerNegative Reactive Power

SLoad = Apparent Power

P

jQ

Phasor

Positive Real Power inthe Direction of the Line

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The power measurement provides an initial indication as to whether the measured val-ues have the correct polarity. If both the active power as well as the reactive powerhave the wrong sign, the polarity in addresse 0201 CT Starpoint must be checkedand rectified.

However, energy metering itself is not able to detect all connection errors. For this rea-son, directional messages should be generated by means of the directional overcur-rent protection. The 67-TOC element is used to generate directional messages. Thepickup threshold of 67-TOC, approximately [1.1 · Address 1507 67-TOC PICKUP],must be reduced so that the available load current causes a continuous pickup of theelement. The direction reported in the messages, such as “Phase A forward“ or„Phase A reverse“ must correspond to the actual power flow. While performing thistest and interpreting the results, be careful that the “Forward” direction of 67-TOC isin the direction of the line (or object to be protected). This is not necessarily identicalwith the direction of the normal network current flow or the load current flow for thistest. For all three phases, the corresponding power flow directional messages must bereported properly.

If all directions are incorrect, then there is conflict between the polarity of the currenttransformers and the polarity set under Address 0201 CT Starpoint, in P.System Data1. The polarity of the current transformers must be determined and properly setin the 7SJ62/63/64 according to Subsection 2.1.3. If the directional data are diverse,then individual phases in the current or voltage connections are interchanged, or thephase sequence is not correct. The connections must be checked and corrected. Fi-nally the phase is again de-energized.

Note! Set the pickup values that have been changed for testing back to the valid set-tings!

3.3.9 Polarity check for the voltage input U4 (only 7SJ64)

Depending on the application of the voltage measuring input U4 of a 7SJ64, a polaritycheck may be necessary. If no measuring voltage is connected to this input, this sub-section is irrelevant.

If the input U4 is used for measuring the displacement voltage Uen (power system data1 address 0213 VT Connection = Van,Vbn,Vcn,VGn or Vab, Vbc, VGnd), thepolarity is checked together with the measured current test according to Subsection3.3.11.

Only for Synchro-nism Check in7SJ64

If the input U4 is used for measuring a voltage for synchronism check (power systemdata 1 address 0213 VT Connection = Van,Vbn,Vcn,VSy , observe the following:

• The single-phase voltage U2 to be synchronized must be connected to the input U4;

• The polarity must be checked as follows using the synchronism check function:

The device must be equipped with the synchronism and voltage check. For verifyingthe synchrocheck function at address 016x, SYNC Funktion xmust be configuredto SYNCHROCHECK (refer to Subsection 2.1.1).

The voltage U2 to be synchronized must be specified correctly under address 6X23 CONNECTIONof V2 (refer to Subsection 2.16.2).

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If a transformer is located between the measuring points of reference voltage U1 andthe voltage to be synchronized U2, the angle must correspond to the phase rotationthrough which the vector group of the transformer as seen from the feeder in the di-rection of the busbar rotates the voltage. For this purpose an angle corresponding tothe transformer vector group is entered in address 6X22 ANGLE ADJUSTM. An ex-ample is shown in Subsection 2.16.2 gegeben.

If necessary different transformation ratios of the voltage transformers on the busbarand the feeder may have to be considered under address ON under address 6X01Synchronizing X.

A further aid for checking in the connection are the messages 170.2090 “25 V2>V1“,170.2091 “25 V2<V1“, 170.2094 “25 a2>a1“ and 170.2095 “25 a2<a1“ in thespontaneous annunciations.

Circuit breaker is open. The feeder is isolated (zero voltage). The VTmcbs of bothvoltage transformer circuits must be closed.

The program Direct CO = YES (address 6X10A) must be set for the synchro-check; the other programs (addresses 6X07 to 6X09) are set to NO.

A request for synchro-check is initiated via binary input (FNo. 170.0043 “>25 Measu. Only“). The synchro-check must give close release (message “25 Clos-eRelease“, FNr 170.0049). If not, check all relevant parameters again (synchro-check configured and switched on correctly, see sections 2.1.1 and 2.16.2).

Set address 6X10 Direct CO to NO.

Then the circuit breaker is closed while the line isolator is open (see Figure 3-36).Both voltage transformers therefore measure the same voltage.

The program SYNC-Funktionsgruppe X = ASYN/SYNCHRON (Adresse 016X) isset.

A request for synchro-check measurement is initiated via binary input (FNo.170.0043 “>25 Measu. Only“). The synchro-check must give close release(message “25 CloseRelease“, FNo 170.0049).

Figure3-36 Measuring voltages for synchro-check

Busbar

7SJ64

U2

U1

U4

Injection

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If not, first check whether one of the aforenamed messages 170.2090 „25 V2>V1“or 170.2091 „25 V2<V1“ or 170.2094 „25 a2>a1“ or 170.2095 „25 a2<a1“ isavailable in the spontaneous messages.

The messages „25 V2>V1“ or „25 V2<V1“ indicates that the magnitude (ratio) ad-aptation is incorrect. Check address 6X21 Balancing V1/V2 and recalculate theadaptation factor.

The messages „25 a2>a1“ or „25 a2<a1“ indicates that the phase relation of thebusbar voltage does not match the setting under address 6X23 CONNECTIONof V2 (see Subsection 2.16.2.2). When measuring across a power transformer, ad-dress 6X22 ANGLE ADJUSTM. must also be checked; this must adapt the vectorgroup (see Subsection 2.16.2.2). If these are correct, there is probably a reversepolarity of the voltage transformer terminals U1.

For the synchro-check the program SYNC V1>V2< = YES (address 6X08) andSYNC Funktion X = ASYN/SYNCHRON (address 016X) is set.

Open the VT mcb of the busbar voltage.

A request for synchro-check measurement is initiated via binary input (FNo.170.0043 “>25 Measu. Only“). There is no close release. If there is, the VT mcbfor the busbar voltage is not allocated. Check whether this is the required state, al-ternatively check the binary input “>FAIL: BUS VT“ if necessary (FNo 06510).

Close the VT mcb of the busbar voltage is to be closed again.

Open the circuit breaker.

The program SYNC V1<V2> = YES (address 6X07) and SYNC V1>V2< = NO (ad-dress 6X08) is set for the synchro-check.

A request measurement for synchro-check is initiated via binary input (FNo.170.0043 “>25 Measu. Only“). The synchronism check must release closing(message “25 CloseRelease“, FNo 170.0049). If not, check all voltage connec-tions and the corresponding parameters again carefully as described in Subsection2.16.2.

Open the VT mcb of the feeder voltage.

Via binary input (FNo. 170.0043 „>25 Measu. Only“) initiate the measuring re-quest. No close release is given.

Close the VT mcb of the busbar voltage again.

Addresses 6X07 to 6X10 must be restored as they were changed for the test. If therouting of the LEDs or signal relays was changed for the test, this must also be re-stored.

3.3.10 Ground Fault Check in a Non-Grounded System

The ground fault check is only necessary if the device is connected to an isolated orresonant-grounded system and the ground fault detection is applied. The device musttherefore be provided with the ground fault detection function according to its ordering

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code (position 15 in ordering code: D or B or F or H). Furthermore, address 0131Sens. Gnd Fault = Enabledmust have been preset during configuration to enablethis function (according to Subsction 2.1.1). If none of this is the case, Subsection3.3.10 is not relevant.

The primary check serves to find out the correct polarity of the transformer connec-tions for the determination of the earth fault direction.

Using the primary earth fault method a most reliable test result is guaranteed. There-fore please proceed as follows:

Isolate the line and earth it on both ends. During the whole testing procedure theline must be open at the remote end.

Make a test connection between a single phase and ground. On overhead lines itcan be connected anywhere, however, it must be located behind the current trans-formers (looking from the busbar of the feeder to be checked). Cables are earthedon the remote end (sealing end).

Remove the protective earthing of the line.

Connect a circuit breaker to the line end that is to be checked.

Check the direction indication (LED if allocated)

The faulty phase (FNo 01272 for L1 or 01273 for L2 or 01274 for L3) and the di-rection of the line, i.e. “SensGnd Forward“ (FNo 01276) must be displayed in theearth fault protocol.

The active and reactive components of the earth current are also displayed. The re-active current (“INs Reac“, FNo 000702) is the most relevant for isolated systems,for resonant-earthed systems it is the active current (“INs Real“, FNo 000701). Ifthe display shows the message “SensGnd Reverse“ (FNo 01277), either the cur-rent or voltage transformer terminals are swopped in the neutral path. In case themessage “SensGnd undef.“ (FNo 01278) appears the earth current may be toolow.

Deenergize and earth the line.

The check is then finished.

3.3.11 Polarity Check for the Current Measuring Input IN

If the standard connection of the device is used whereby the current measuring inputIN is connected in the star-point of the set of current transformers (refer also to the con-nection circuit diagrams in the Appendix A.3, Figure A-45, A-55, then the correct po-larity of the earth current path in general will result automatically.

DANGER!Primary measurements must only be carried out on disconnected and groundedequipment of the power system. Danger to life exists even on disconnectedequipment because of capacitive coupling from other energized equipment ofthe power system!

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If however the current IN is derived from a separate summation CT (e.g. a core bal-ance CT, see Section A.3, Figure A-47, A-57, A-64) an additional polarity check withthis current is necessary.

If the device is provided with the sensitive current measuring input IN and it is connect-ed to an isolated or resonant-grounded system, the polarity check for IN was alreadycarried out with the earth fault check according to 3.3.10. Then this Subsection 3.3.11can be ignored.

Otherwise the test is done with a disconnected trip circuit and primary load current. Itmust be noted that during all simulations that do not exactly correspond with situationsthat may occur in practice, the non-symmetry of measured values may cause themeasured value monitoring to pick up. This must therefore be ignored during suchtests.

Directional Testingfor a Grounded Net-work

The check can either be carried out with function “directional ground fault protection”(address 0116) or function “ground fault detection” (address 0131), which can be op-erated as additional short-circuit protection.

In the following the check is described using the “directional ground fault protection”function (address 0116) as an example.

To establish 3V0 (a displacement voltage), the connection of one VT winding is re-moved from the device. In Figure 3-37, the open delta VTs are modified so that onlyVb and Vc are connected to the inputs Ve-n of the device. Alternatively, Va from thewye-VTs can be disconnected. If no connection for VNs (Ve-n connection) is foreseen,the secondary side of the corresponding phase can be disconnected as shown in Fig-ure 3-38. The device receives only the current from the phase where the associatedvoltage connection at the device is missing. If the line current is in-phase or laggingthe voltage (resistive or resistive-inductive load), the same current-voltage relation-ships exist for the device in this test simulation as during a phase-ground fault in thedirection of the line.

At least one stage of the ground fault protection must be set to be directional. The pick-up threshold of this stages must be below the load current flowing on the line; if nec-essary the pick-up threshold must be reduced. The parameters that have beenchanged must be noted.

After switching the line on and off again, the direction indication must be checked: inthe fault messages the messages “67N picked up“ and „Ground forward“ mustat least be present. If the directional pick up is not present, either the earth current con-nection or the displacement voltage connection is incorrect. If the wrong direction isindicated, either the direction of load flow is from the line toward the busbar or theearth current path has a swapped polarity. In the latter case, the connection must berectified after the line has been isolated and the current transformers short-circuited.

In the event that the pick-up alarms were not even generated, the measured earth (re-sidual) current or the displacement voltage evolved may be too small. This can be che-cked by means of the operational measured values.

DANGER!Working on measurement transformers requires the highest precautions!Short-circuit current transformers before any current connections to the deviceare opened!

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Attention! If parameters were changed for this test, they must be returned to theiroriginal state after completion of the test!

Figure 3-37 Polarity Testing for IN, Example with Current Transformers Configured in aHolmgreen-Connection (VTs with Broken Delta Connection — e-n Winding)

.

Figure 3-38 Polarity Testing for IN, Example with Current Transformers Configured in aHolmgreen-Connection (VTs Wye-Connected)

3.3.12 Checking the Temperature Measurement via RTD-Box

After the termination of the RS485 port and the setting of the bus address have beenverified according to Subsection 3.2.1, the measured temperature values and thresh-olds can be checked.

If temperature sensors are used with 2-phase connection you must first determine theline resistance for the temperature detector being short-circuited. Select mode 6 at the

Bus

Line

A

B

C

en

7SJ62/63/64

Ia

Ic

Ve

Ib

Vn

IN

Ib'Ia'

Ic'

IN'

Bus

Line

A

B

C

7SJ62/63/64

Ia

IcIb

IN

Va Vb Vc Vn

Ib'Ia'

Ic'

IN'

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RTD-Box and enter the resistance value you have determined for the correspondingsensor (range: 0 to 50.6 Ω) to the RTD-Box.

When using the preset 3-phase connection for the temperature detectors no furtherentry must be made.

For checking the measured temperature values the temperature detectors are re-placed by settable resistances (e.g. precision resistance decade) and the correct as-signment of the resistance value and the displayed temperature for 2 or 3 temperaturevalues from table 3-37 are verified.

Table 3-37 Assignment of temperature and resistance of the detectors

Temperature in °C Ni 100DIN 43760

Ni 120DIN 34760

Pt 100IEC 751

–50 74,255 89,106 80,3062819

–40 79,1311726 94,9574071 84,270652

–30 84,1457706 100,974925 88,2216568

–20 89,2964487 107,155738 92,1598984

–10 94,581528 113,497834 96,085879

0 100 120 100

10 105,551528 126,661834 103,902525

20 111,236449 133,483738 107,7935

30 117,055771 140,466925 111,672925

40 123,011173 147,613407 115,5408

50 129,105 154,926 119,397125

60 135,340259 162,408311 123,2419

70 141,720613 170,064735 127,075125

80 148,250369 177,900442 130,8968

90 154,934473 185,921368 134,706925

100 161,7785 194,1342 138,5055

110 168,788637 202,546364 142,292525

120 175,971673 211,166007 146,068

130 183,334982 220,001979 149,831925

140 190,88651 229,063812 153,5843

150 198,63475 238,3617 157,325125

160 206,58873 247,906476 161,0544

170 214,757989 257,709587 164,772125

180 223,152552 267,783063 168,4783

190 231,782912 278,139495 172,172925

200 240,66 288,792 175,856

210 249,79516 299,754192 179,527525

220 259,200121 311,040145 183,1875

230 268,886968 322,664362 186,835925

240 278,868111 334,641733 190,4728

250 289,15625 346,9875 194,098125

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Temperature thresholds that are configured in the protection device can be checkedby slowly approaching the resistance value.

3.3.13 Measuring the operating time of the circuit breaker (only 7SJ64)

Only forSynchronismCheck

If the device 7SJ64 is equipped with the function for synchronism and voltage checkand it is applied, it is necessary — under asynchronous system conditions — that theoperating time of the circuit breaker is measured and set correctly when closing. If thesynchronism check function is not used or only for closing under synchronous systemconditions, this subsection is irrelevant.

For measuring the operating time a setup as shown in figure 3-39. The timer is set to1 s and a graduation of 1 ms.

The circuit breaker is closed manually. At the same time the timer is started. After clos-ing the poles of the circuit breaker, the voltage UFeeder appears and the timer isstopped. The time displayed by the timer is the real circuit breaker closing time.

If the timer is not stopped due to an unfavourable closing moment, the attempt will berepeated.

It is particularly favourable to calculate the mean from several (3 to 5) successfulswitching attempts.

Set the calculated time under address 6X20 as T-CB close (under power systemdata 2). Select the next lower adjustable value.

Figure3-39 Measuring the circuit breaker closing time

3.3.14 Switching Check for the Configured Operating Devices

Control by LocalCommand

If the configured operating devices were not switched sufficiently in the hardware testalready described (Subsection 3.3.3), all configured switching devices must beswitched on and off from the device via the integrated control element. The feedback

UFeeder

Feeder

Busbar

L+

L–

Timer

Start

Stop

Close

UBusbar

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information of the circuit breaker position injected via binary inputs is read out at thedevice and compared with the actual breaker position. For devices with graphic dis-play this is easy to do with the control display.

The switching procedure is described in the SIPROTEC® 4–System Manual. Theswitching authority must be set in correspondence with the source of commands used.The switching mode can be selected from interlocked and non-interlocked switching.Please take note that non-interlocked switching can be a safety hazard.

Control by Protec-tive Function

Tripping of the primary equipment by protective elements can be verified if desired.However, be fully aware that such testing can result in closing of the circuit breaker bythe reclosing element in the 7SJ62/63/64 or an external reclosing device. If circuitbreaker closing is to be avoided, be sure the closing is defeated before the test is per-formed. If reclosing is desired, select an element in the 7SJ62/63/64 that initiates re-closing, and test the control by tripping this element in the testing. To avoid a trip-close-trip event, be sure the protective element is dropped out before the close occurs.

Control from a Re-mote Control Cen-tre

If the device is connected to a remote substation via a system (SCADA) interface, thecorresponding switching tests may also be checked from the substation. Please alsotake into consideration that the switching authority is set in correspondence with thesource of commands used.

3.3.15 Triggering Oscillographic Recordings

At the end of commissioning, an investigation of switching operations of the circuitbreaker(s) or primary switching device(s), under load conditions, should be done toassure the stability of the protection during the dynamic processes. Oscillographic re-cordings obtain the maximum information about the behaviour of the 7SJ62/63/64.

Requirements Along with the capability of recording waveform data during system faults, the 7SJ62/63/64 also has the capability of capturing the same data when commands are givento the device via the service program DIGSI® 4, the serial interfaces, or a binary input.For the latter, the binary input must be assigned to the function “>Trig.Wave.Cap.”(FNo 00004). Triggering for the oscillographic recording then occurs when the input isenergized. For example, an auxiliary contact of the circuit breaker or control switchmay be used to control the binary input for triggering.

An oscillographic recording that is externally triggered (that is, without a protective el-ement pick-up or device trip) is processed by the device as a normal fault recordingwith the exception that data are not given in the fault messages (trip log). The exter-nally triggered record has a number for establishing a sequence.

DANGER!A successfully started test cycle can lead to the closing of the circuit breaker!

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Triggering withDIGSI® 4

To trigger oscillographic recording with DIGSI® 4, click on Test in the left part of thewindow. Double click the entry Test Wave Form in the list in the right part of the win-dow to trigger the recording. See Figure 3-40.

Figure 3-40 Triggering oscillographic recording with DIGSI® 4

A report is given in the bottom left region of the screen. In addition, message segmentsconcerning the progress of the procedure are displayed.

The SIGRA® program or the Comtrade Viewer program is required to view and ana-lyse the oscillographic data.

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3.4 Final Preparation of the Device

Tighten the used screws at the terminals; those ones not being used should be slightlyfastened. Ensure all pin connectors are properly inserted.

Verify that all service settings are correct. This is a crucial step because somesetting changes might have been made during commissioning. The protectivesettings under device configuration, input/output configuration are especially impor-tant (Section 2.1.1) as well as the power system data, and activated Groups A throughD (if applicable). All desired elements and functions must be set ON. See Chapter 2.Keep a copy of all of the in-service settings on a PC.

Check the internal clock of the device. If necessary, set the clock or synchronize theclock if it is not automatically synchronized. For assistance, refer to the SIPROTEC®

4 System Manual.

The Annunciation memory buffers should be cleared, particularly the Event Log andTrip Log. Future information will then only apply for actual system events and faults.To clear the buffers, press MAIN MENU → Annunciation → Set/Reset. The num-bers in the switching statistics should be reset to the values that were existing prior tothe testing, or to values in accordance with the user's practices. Set the statistics bypressing MAIN MENU → Annunciation → Statistic. Refer to the SIPROTEC® 4System Manual if more information is needed.

Press the key, several times if necessary, to return to the default display.

Clear the LEDs on the front panel by pressing the key. Any output relays that werepicked up prior to clearing the LEDs are reset when the clearing action is performed.Future indications of the LEDs will then apply only for actual events or faults. Pressingthe key also serves as a test for the LEDs because they should all light when thebutton is pushed. Any LEDs that are lit after the clearing attempt are displaying actualconditions.

The green “RUN” LED must be on. The red “ERROR” LED must not be lit.

Close the protective switches. If test switches are available, then these must be in theoperating position.

The device is now ready for operation.

Caution!

Do not use force! The tightening torques must not be exceeded as the threads andterminal chambers may otherwise be damaged!

ESC

LED

LED

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Technical Data 4This chapter provides the technical data of the SIPROTEC® 4 7SJ62/63/64 devicesand the individual functions of the devices, including the limiting values that under nocircumstances may be exceeded. The electrical and functional data for devicesequipped with all options are followed by the mechanical data with dimensional draw-ings.

4.1 General Device Data 346

4.2 Definite-Time Overcurrent Protection (50 and 50N Elements) 359

4.3 Inverse-Time Overcurrent Protection (51 and 51N Elements) 360

4.4 Directional Time Overcurrent Protection (67 and 67N Elements) 370

4.5 Inrush Restraint 371

4.6 Dynamic Cold Load Pick-up Function (50c, 50Nc, 51Nc, 67c, 67Nc) 371

4.7 Voltage Protection (27 and 59) 372

4.8 Negative Sequence Protection (46) 373

4.9 Motor Starting Protection (48) 379

4.10 Start Inhibit for Motors (66/68) 380

4.11 Frequency Protection (81 Over-Frequency and Under-Frequency) 381

4.12 Thermal Overload Protection (49) 382

4.13 Sensitive Ground Fault Detection (64, 50Ns, 67Ns) 384

4.14 Intermittent Ground Fault Protection 387

4.15 Automatic Reclosing System (79M) 388

4.16 Fault Location 389

4.17 Breaker Failure Protection (50BF) 389

4.18 Synchronism and Voltage Check (25) (7SJ64 only) 390

4.19 RTD-Boxes for Temperature Detection 391

4.20 User Defined Functions with CFC 392

4.21 Additional Functions 395

4.22 Breaker Control 399

4.23 Dimensions 400

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4.1 General Device Data

4.1.1 Analog Inputs

Nominal Frequency fN 50 Hz or 60 Hz (adjustable)

Current Inputs Nominal Current IN 1 A or 5 A

Ground Current, SensitiveINs ≤ 1.6 A1)

Burden per Phase and Ground Path– At IN = 1 A approx. 0.05 VA– At IN = 5 A approx. 0.3 VA– Sensitive Ground Fault Detection 1 A approx. 0.05 VA

AC Current Overload Capability– Thermal (rms) 100 · IN < 1 s

30 · IN < 10 s4 · IN continuous

– Dynamic (current pulse) 250 · IN for 0.5 cycle

AC Current Overload Capability for Sensitive Ground Fault Detection INs1)

– Thermal (rms) 300 A < 1 s100 A < 10 s15 A continuous

– dynamic (impulse) 750 A for 0.5 cycle

Voltage Inputs Secondary Nominal Voltage 100 V to 225 V ACMeasuring Range 0 V to 170 V ACBurden at 100 V approx. 0.3 VA

AC Voltage Input Overload Capacity– Thermal (rms) 230 V continuous

Measuring Trans-ducer Inputs(7SJ63 only)

Input Current 0 mA DC to 20 mA DCInput Resistance 10 ΩBurden 5.8 mW at 24 mA

1) only in versions with input for sensitive ground fault detection (ordering data see Ap-pendix A.1)

4.1.2 Power Supply

Direct Voltage Voltage Supply Via Integrated Converter

Nominal Power Supply Direct Voltage UH DC 24/48 VDC 60/110/125 VDCPermissible Voltage Ranges 19 to 58 VDC 48 to 150 V DC

Nominal Power Supply Direct Voltage UH DC 110/125/220/250 VDCPermissible Voltage Ranges 88 to 300 V DC

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Permissible AC Ripple Voltage, peak to peak ≤15 % of the power supply voltageto IEC 60255–11

Bridging Time for Failure/Short Circuit ≥ 50 ms at U ≥ 110 VDCto IEC 60255–11 ≥ 20 ms at U ≥ 24 VDC

Alternative Voltage Voltage Supply via Integrated Converter

*) 7SJ62 and 7SJ63 only

Bridging Time for Failure/Short Circuit ≥ 200 ms

4.1.3 Binary Inputs and Outputs

Binary Inputs Number

7SJ621*– 8 (configurable)7SJ622*– 11 (configurable)

7SJ631*– 11 (configurable)7SJ632*– 24 (configurable)7SJ633*– 20 (configurable)

Power Consumption Quiescent Energized

7SJ621, 7SJ622 approx. 4 W approx. 7 W

7SJ631 approx. 4 W approx. 10 W

7SJ632, 7SJ633 approx. 5,5 W approx. 16 W

7SJ635, 7SJ636 approx. 7 W approx. 20 W

7SJ640 approx. 5 W approx. 7,5 W

7SJ641 approx. 5 W approx. 12 W

7SJ642 approx. 5 W approx. 12 W

7SJ645 approx. 5 W approx. 16 W

Nominal Power Supply Alternating VoltageUH AC

115 VAC 230 VAC*)

Permissible Voltage Ranges 92 to 132 VAC 184 to 265 VAC*)

Power Consumption Quiescent Energized

7SJ621, 7SJ622 approx. 3 VA approx. 9 VA

7SJ631 approx. 3 VA approx. 12 VA

7SJ632, 7SJ633 approx. 5 VA approx. 18 VA

7SJ635, 7SJ636 approx. 7 VA approx. 23 VA

7SJ640 approx. 6.5 VA approx. 12.5 VA

7SJ641 approx. 6.5 VA approx. 12.5 VA

7SJ642 approx. 6.5 VA approx. 16.5 VA

7SJ645 approx. 6.5 VA approx. 21 VA

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7SJ635*– 37 (configurable)7SJ636*– 33 (configurable)

7SJ640*– 7 (configurable)7SJ641*– 15 (configurable)7SJ642*– 20 (configurable)7SJ645*– 33 (configurable)

Nominal Voltage Range 24 VDC to 250 VDC, bipolar

Switching Thresholds adjustable voltage range with jumpers– For Nominal Voltages 24/48/60 VDC UPU ≥ 19 VDC

and 60/110/125 VDC UDO ≤ 14 VDC

– For Nom. Voltages 110/125 VDC UPU ≥ 88 VDCand 220/250 VDC UDO ≤ 66 VDCand 115/230 VAC

Maximum Permissible Voltage 300 VDC

Impulse Filter on Input 220 nF Coupling Capacitor at 220 V withrecovery time > 60 ms

Output Relays Output Relay for Commands/Annunciations1) (see also General Diagrams inHigh-duty relays (motor control)2 Appendix A.2)

Number and Information acc. to the order variant (allocatable):Values in ( ): up to release .../DD

Device Binary Inputs7SJ62 --- BI 1 ... BI 11

7SJ63 BI 1....6; BI 8....19BI 25....36

BI 7; BI 20....24BI 37

7SJ640 --- BI 1...7

7SJ641 --- BI 1...15

7SJ642 BI 8...19 BI 1...7; BI 20

7SJ645 BI 8...19; BI 21...32 BI 1...7; BI 20; BI 33

Current Consumption, Energized(independent of the control voltage)

approx. 0.9 mA approx. 1.8 mA

Pickup Times approx. 9 ms approx. 4 ms

Order Variant NOContact

NO/NC (switchselectable)

High-dutyrelay

7SJ621∗ – 6 (8) 3 (1) –

7SJ622∗ – 4 (6) 3 (1) –

7SJ631∗ – 8 1 –

7SJ632∗ – 11 1 4

7SJ633∗ – 11 1 4

7SJ635∗ – 14 1 8

7SJ636∗ – 14 1 8

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General Device Data

1) UL–listed with the following nominal value:120 V ac Pilot duty, B300240 V ac Pilot duty, B300240 V ac 5 A General Purpose24 V dc 5 A General Purpose48 V dc 0.8 A General Purpose240 V dc 0.1 A General Purpose120 V ac 1/6 hp (4.4 FLA)240 V ac 1/2 hp (4.9 FLA)

2) UL–listed with the following nominal value:240 V dc 1.6 FLA120 V dc 3.2 FLA60 V dc 5.5 FLA

4.1.4 Communications Interfaces

PC Front Interface – Connection front panel, non-isolated, RS 232,9-pin DSUB port for connecting a personalcomputer

– Operation with DIGSI® 4

– Transmission Speed min. 4800 Baud; max. 38400 Baudfor 7SJ63/64: max. 115 200 BaudFactory Setting: 38400 Baud; Parity: 8E1

– Maximum Distance of Transmission 15 meters / 50 feet

7SJ640∗ – 5 1 –

7SJ641∗ – 12 2 –

7SJ642∗ – 8 1 4

7SJ645∗ – 11 1 8

Switching Capability MAKEBREAK

1000 W/VA 1)30 W/VA

40 W resistive25 W/VA at L/R ≤ 50 ms

––––

Switching Voltage 250 V 250 V

Permissible Current per Contact /Max. inrush peak

5 A continous30 A ≤ 0,5 s 30 A ≤ 0,5 s

Permissible Current per Contactand Total Current on common path

5 A continous30 A for 0,5 s

––

Switching Capabilityfor 30 s

for 28 V to 250 Vfor 24 V

––

1000 W 2)500 W

Permissible relative closing time – 1 %

Operating time, approx.. 8 ms 8 ms –

Order Variant NOContact

NO/NC (switchselectable)

High-dutyrelay

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Technical Data

Rear Service–/Mo-dem– Interface

– Connection isolated interface for data transfer

– Operation with DIGSI® 4

– Transmission Speed min. 4800 Bd, max. 38400 Baudfor 7SJ63/64: max. 115 200 BaudFactory Setting: 38400 Bd

RS232/RS485 RS232/RS485 depends on order code

– Connection for flush mounted case rear panel, mounting location “C“9 pin DSUB port

for panel-surface on the case bottommounted case shielded data cable

– Test Voltage 500 V AC

RS232

– Maximum Distance of Transmission 15 meters / 50 feet

RS485

– Maximum Distance of Transmission 1 km / 3280 feet / 0.62 mile

Fibre Optical Link1)– Connector Type ST–Connector

with flush-mounted case rear panel, mounting location “C“with panel surface- at FO housingmounted case on the case bottom

– Optical Wavelength λ = 820 nm

– Laser Class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm orusing glass fiber 62.5/125 µm

– Optical Link Signal Attenuation max. 8 dB, with glass fiber 62.5/125 µm– Channel Distance max. 1.5 km (0.95 miles)– Character Idle State selectable: factory setting “Light off”1) not for 7SJ64

Additional Port(only 7SJ64)

– Connection isolated interface for data transferwith RTD-boxes

– Transmission Speed min. 4800 Bd, max. 115 200 BaudFactory Setting: 38400 Bd

RS485

– Connection for Flush Mounted Case rear panel, installation location “D“9 pin DSUB Port RS 485

for panel surface- at the housing on the case bottommounted case shielded data cable

– Test Voltage 500 V AC

– Maximum Distance of Transmission 1 km / 3280 feet / 0.62 mile

Fibre Optical Link– Connector Type ST–Connector

with flush-mounted case rear panel, mounting location “D“

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General Device Data

with panel surface- at housingmounted case on the case bottom

– Optical Wavelength λ = 820 nm

– Laser Class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm orusing glass fiber 62.5/125 µm

– Optical Link Signal Attenuation max. 8 dB, with glass fiber 62.5/125 µm– Channel Distance max. 1.5 km (0.95 miles)– Character Idle State selectable: factory setting “Light off”

System (SCADA)Interface (optional)

IEC 60870–5–103

RS232/RS485/ floating interface for data transferdepends on order code to a master terminal

RS232

– Connection for flush mounted case rear panel, mounting location “B“9 pin DSUB port

for panel surface- at the housing on the case bottommounted case

– Test Voltage 500 V AC

– Transmission Speed min. 4800 Bd, max. 38400 BdFactory Setting: 38400 Bd

– Maximum Distance of Transmission 15 meters / 49 feet

RS485– Connection for Flush Mounted Case rear panel, installation location “B“

9 pin DSUB Port RS 485for panel surface- at the housing on the case bottommounted case

– Test Voltage 500 V AC

– Transmission Speed min. 4800 Bd, max. 38400 BdFactory Setting: 38400 Bd

– Maximum Distance of Transmission 1 km / 3280 feet / 0.62 mile

Fibre Optical Link– Connector Type ST–Connector

with flush-mounted case rear panel, mounting location “B“with panel surface- at housingmounted case on the case bottom

– Optical Wavelength λ = 820 nm

– Laser Class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm orusing glass fiber 62.5/125 µm

– Optical Link Signal Attenuation max. 8 dB, with glass fiber 62.5/125 µm– Channel Distance max. 1.5 km (0.95 miles)– Character Idle State selectable: factory setting “Light off”

PROFIBUS RS485 (FMS and DP)– Connection for Flush Mounted Case rear panel, installation location “B“

9 pin DSUB Port RS 485

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Technical Data

for panel surface- at the housing on themounted case case bottom

– Test Voltage 500 V AC

– Transmission Speed up to 1.5 M Baud

– Maximum Distance of Transmission 1 km / 3280 feet / 0.62 mile at≤ 93.75 kBd500 m /1640 feet /0.31 mile at≤ 187.5 kBd200 m / 660 feet at ≤ 1.5 MBd

Profibus (FMS and DP)Fibre Optical Link– Connector type integrated ST connector for OWG

direct access; for FMS single ring ortwin ring, depending on orderfor DP only double ring

For Flush-Mounted Case rear panel, mounting location “B“For Panel Surface- at the housingMounted Case on the case bottom

– Transmission Speed up to 1.5 M Baudrecommended: > 500 k Baud with normal casing

≤ 57600 Bd with detached operator panel

– Optical Wavelength λ = 820 nm

– Laser class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm orusing glass fiber 62.5/125 µm

– Optical Link Signal Attenuation max. 8 dB, with glass fiber 62.5/125 µm– Channel Distance max. 1.5 km (0.95 miles)

DNP3.0 / MODBUS RS485

– Connection for Flush Mounted Case rear panel, installation location “B“9 pin DSUB Port

for panel surface- at the housing on themounted case case bottom

– Test Voltage 500 V; 50 Hz

– Transmission Speed max. 19200 Bd

– Maximum Distance of Transmission 1 km / 3280 feet / 0.62 mile

DNP3.0 / MODBUS Fibre Optical Link

– Connector Type ST–Connector transmitter/receiver

– Connection with flush-mounted case rear panel, mounting location “B“with panel surface- at the housingmounted case on the case bottom

– Transmission Speed max. 19200 Bd

– Optical Wavelength λ = 820 nm

– Laser Class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm orusing glass fiber 62.5/125 µm

– Optical Link Signal Attenuation max. 8 dB, with glass fiber 62.5/125 µm

– Channel Distance max. 1.5 km (0.95 miles)

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General Device Data

Clock – Time Synchronization DCF77/IRIG B–Signal– Connection For Flush-mounted Case rear panel, mounting location “A“

9 - pin DSUB portFor Panel Surface- at the double-deck terminal onMounted Case the case bottom

– Signal Rated Voltage selectable 5 V, 12 V or 24 V

– Signal Levels and Burdens:

4.1.5 Electrical Tests

Specifications Standards: IEC 60255 (Product Standards)ANSI/IEEEC37.90.0,.C37.90.0.1,C37.90.0.2UL 508DIN 57 435 Part 303See also standards for individual tests

Insulation Tests Standards: IEC 60255–5, IEC 60870–2–1

– High Voltage Test (routine test) 2.5 kV (rms) ACAll circuits except power supply,Binary Inputs, andCommunications Interface

– High Voltage Test (routine test) 3.5 kVDConly power supply and binary inputs

– High Voltage Test (routine test) 500 V (rms) ACOnly Isolated Communicationsand Time Synchronization Interfaces

– Impulse Voltage Test (type test) 5 kV (peak): 1.2/50 µs: 0.5 Ws: 3 positiveAll Circuits Except Communications and 3 negative impulses in intervals of 5 sand Time Synchronization Interfaces,Class III

EMC Tests for Im-munity (Type Tests)

Standards: IEC 60255–6 and –22, (Product standards)EN 50082–2 (Generic standard)DIN 57 435 Part 303 ANSI/IEEE C37.90.1and C37.90.2

Rated Signal Voltage5 V 12 V 24 V

VIHigh 6.0 V 15.8 V 31 V

VILow 1.0 V at IILow = 0.25 mA 1.4 V at IILow = 0.25 mA 1.9 V at IILow = 0.25 mA

IIHigh 4.5 mA to 9.4 mA 4.5 mA to 9.3 mA 4.5 mA to 8.7 mA

RI 890 Ω at VI = 4 V640 Ω at VI = 6 V

1930 Ω at VI = 8.7 V1700 Ω at VI = 15.8 V

3780 Ω at VI = 17 V3560 Ω at VI = 31 V

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Technical Data

– High Frequency Test 2.5 kV (Peak): 1 MHz: τ = 15 µs;IEC 60255–22–1, Class III 400 Surges per s: Test Duration 2 sand VDE 0435 Part 303, Class III Ri=200 Ω

– Electrostatic Discharge 8 kV contact discharge: 15 kV air-IEC 60255–22–2 Class IV discharge, both polarities:150 pF:Ri=330 Ωand IEC 61000–4–2, Class IV

– Irradiation with HF Field, 10 V/m: 27 MHz to 500 MHznon-modulatedIEC 60255–22–3 (Report) Class III

– Irradiation with HF Field, 10 V/m: 80 MHz to1000 MHz: 80 % AM:amplitude modulated 1 kHzIEC 61000–4–3, Class III

– Irradiation with HF Field, 10 V/m: 900 MHz: repetition frequencyPulse Modulated 200 Hz: duty cycle of 50 %IEC 61000–4–3/ENV 50204, Class III

– Fast Transient Disturbance Variables/ 4 kV: 5/50 ns: 5 kHz: Burst length = 15 ms;Burst IEC 60255–22–4 and repetition rate 300 ms: both polarities:IEC 61000-4-4, Class IV Ri = 50 Ω: Test Duration 1 min

– High Energy Surge Voltages(SURGE), IEC 61000–4–5Installation Class 3Power Supply common mode: 2 kV: 12 Ω: 9 µF

diff. mode: 1 kV: 2 Ω: 18 µFMeasuring Inputs, Binary Inputs common mode: 2 kV: 42 Ω: 0.5 µFand Relay Outputs diff. mode: 1 kV: 42 Ω: 0.5 µF

– Line Conducted HF, amplitude module.10 V: 150 kHz to 80 MHz: 80 % AM: 1 kHzIEC 61000–4–6, Class III

– Power System Frequency Magnetic 30 A/m continuous: 300 A/m for 3 s: 50 HzField IEC 61000–4–8, Class IV 0.5 mT: 50 HzIEC 60255–6

– Oscillatory Surge Withstand Capability 2.5 to 3 kV (Peak Value): 1MHz to 1.5 MHzANSI/IEEE C37.90.1 damped wave: 50 surges per s:

duration 2 s: Ri = 150 Ω to 200 Ω

– Fast Transient Surge Withstand Cap. 4 kV to 5 kV: 10/150 ns: 50 Pulse per s;ANSI/IEEE C37.90.1 both polarities: Duration 2 s: Ri = 80 Ω

– Radiated Electromagnetic Interference 35 V/m: 25 MHz to 1000 MHzANSI/IEEE C37.90.2 amplitude and pulse modulated

– Damped Oscillations 2.5 kV (Peak Value), polarity alternatingsimilar to IEC 60694–4–12, 100 kHz, 1 MHz, 10 MHz and 50 MHz,IEC 61000–4–12 Ri = 200 Ω

EMC Tests ForNoise Emission(type test)

Standard: EN 50081–1 (Generic Standard)

– Radio Noise Voltage to Lines, 150 kHz to 30 MHzOnly Power Supply Voltage Limit Class BIEC–CISPR 22

– Radio Noise Field Strength 30 MHz to 1000 MHzIEC–CISPR 22 Limit Class B

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General Device Data

– Harmonic Currents Device is to be assigned Class Don the Network Lead at 230 VAC*) (applies only for devices with > 50 VAIEC 61000–3–2 power consumption)

– Voltage Variations Limits are observedand Flicker on the Network Leadat 230 VAC*)IEC 61000–3–3

*) for 7SJ62 and 7SJ63

4.1.6 Mechanical Stress Tests

Vibration andShock Stress Dur-ing Operation

Standards: IEC 60255–21 and IEC 60068

– Vibration SinusoidalIEC 60255–21–1, Class 2 10 Hz to 60 Hz: ±0.075 mm Amplitude;IEC 60068–2–6 60 Hz to 150 Hz: 1 g acceleration

frequency sweep rate 1 Octave/min20 cycles in 3 orthogonal axes.

– Shock Half-sine shapedIEC 60255–21–2, Class 1 acceleration 5 g, duration 11 ms,IEC 60068–2–27 3 shocks in each direction of

3 orthogonal axes

– Seismic Vibration SinusoidalIEC 60255–21–3, Class 1 1 Hz to 8 Hz ± 3.5 mm AmplitudeIEC 60068–3–3 (horizontal axis)

1 Hz to 8 Hz: ± 1.5 mm Amplitude(Vertical axis)8 Hz to 35 Hz: 1 g acceleration(horizontale axis)8 Hz to 35 Hz: 0.5 g acceleration(Vertical axis)Frequency Sweep Rate1 Octave/min1 cycle in 3 orthogonal axes

Vibration andShock Stress Dur-ing Transport

Standards: IEC 60255–21 and IEC 60068–2

– Vibration SinusoidalIEC 60255–21–1, Class 2 5 Hz to 8 Hz: ±7.5 mm Amplitude;IEC 60068–2–6 8 Hz to 150 Hz: 2 g acceleration

Frequency sweep rate1 Octave/min20 cycles in 3 orthogonal axes.

– Shock Half-sine shapedIEC 60255–21–2, Class1 Acceleration 15 g, duration 11 ms,IEC 60068–2–27 3 shocks in each direction of

3 orthogonal axes.

– Continuous Shock Half-sine shapedIEC 60255–21–2, Class 1 Acceleration 10 g, duration 16 ms,IEC 60068–2–29 1000 shocks in each direction of

3 orthogonal axes.

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Technical Data

4.1.7 Climatic Stress Tests

Ambient Tempera-tures1)

– Type tested (acc. IEC60086–2–1 – 13°F to +185°F or –25 °C to +85 °Cand –2, Test Bd, for 16 h)

– Limiting temporary (transient)operating temperature – 4°F to +158°F or –20 °C to +70 °C

– Recommended permanent operating +23°F to +131°F or –5 °C to +55 °Ctemperature (acc. IEC 60255–6)

Visibility of display may be impaired at+131°F (or +55 °C) and above

– Limiting temperatures for storage –13°F to +131°F or –25 °C to +55 °C

– Limiting temperatures for transport –13°F to +158°F or –25 °C to +70 °C

STORE AND TRANSPORT THE DEVICE WITH FACTORY PACKAGING.

1) UL–certified (Standard 508, Industrial Control Equipment):

– Limiting temperatures for normal operation(output relays not energized) 23°F to +158°F or –5 °C to +70 °C

– Limiting temperatures with max. load(max. cont. permissible energizationof inputs and outputs) for 7SJ62 23°F to +131°F or –5 °C to +55 °C

for 7SJ63/64 23°F to +104°F or –5 °C to +40 °

Humidity Permissible Humidity Mean value per year ≤75% relativehumidity, on 56 days of the year up to 93%relative humidity.

CONDENSATION MUST BE AVOIDED

Siemens recommends that all devices be installed such that they are not exposed todirect sunlight, nor subject to large fluctuations in temperature that may cause conden-sation to occur.

4.1.8 Service Conditions

The protective device is designed for use in an industrial environment and an electricalutility environment. Proper installation procedures should be followed to ensure elec-tromagnetic compatibility (EMC). In addition, the following are recommended:

• All contacts and relays that operate in the same cubicle, cabinet, or relay panel asthe numerical protective device should, as a rule, be equipped with suitable surgesuppression components.

• For substations with operating voltages of 100 kV and above, all external cablesshould be shielded with a conductive shield grounded at both ends. The shield mustbe capable of carrying the fault currents that could occur. For substations with loweroperating voltages, no special measures are normally required.

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General Device Data

• Do not withdraw or insert individual modules while the protective device is ener-gized. When handling the modules or the device outside of the case, standards forcomponents sensitive to electrostatic discharge (ESD) must be observed. The mod-ules and device are not endangered when inserted into the case.

4.1.9 Certifications

1) in preparation (April 2002)

4.1.10 Construction

Case 7XP20

UL–certification conditions: “For use on a Flat Surface of a Type 1Enclosure”

Dimensions see dimensional drawings, Section 4.23

UL listing UL recognition

7SJ62∗∗ –∗ B∗∗∗ –∗∗∗∗

Models withthreaded termi-nals

7SJ62∗∗ –∗ D∗∗∗ –∗∗∗∗

Models withplug–in termi-nals

7SJ62∗∗ –∗ E∗∗∗ –∗∗∗∗

7SJ63∗∗ –∗ B∗∗∗ –∗∗∗∗ 7SJ63∗∗ –∗ A∗∗∗ –∗∗∗∗

7SJ63∗∗ –∗ C∗∗∗ –∗∗∗∗ 7SJ63∗∗ –∗ D∗∗∗ –∗∗∗∗

7SJ63∗∗ –∗ E∗∗∗ –∗∗∗∗

7SJ64∗∗ –∗ B∗∗∗ –∗∗∗∗ 1) 7SJ64∗∗ –∗ A∗∗∗ –∗∗∗∗ 1)

7SJ64∗∗ –∗ C∗∗∗ –∗∗∗∗ 1) 7SJ64∗∗ –∗ D∗∗∗ –∗∗∗∗ 1)

7SJ64∗∗ –∗ E∗∗∗ –∗∗∗∗ 1) 7SJ64∗∗ –∗ G∗∗∗ –∗∗∗∗ 1)

7SJ64∗∗ –∗ F∗∗∗ –∗∗∗∗ 1)

Variant Case Size Weight (mass)

7SJ62∗∗ –∗ B in surface mounting housing 1/3 9.9 pounds (4,5 kg)

7SJ62∗∗ –∗ D/E in flush mounting housing 1/3 8.8 pounds (4 kg)

7SJ631/2/3∗ –∗ B in surface mounting housing 1/2 16.5 pounds (7,5 kg)

7SJ635/6∗ –∗ B in surface mounting housing 1/1 33 pounds (15 kg)

7SJ631/2/3∗ –∗ D/E in flush mounting housing 1/2 14.3 pounds (6,5 kg)

7SJ63/5/6∗ –∗ D/E in flush mounting housing 1/1 28.6 pounds (13 kg)

7SJ631/2/3∗ –∗ A/C in housing for detached operator panel 1/2 17.6 pounds (8 kg)

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Technical Data

International Protection Under IEC 60529– for the equipment

in the surface mounted case IP 51in the flush mounted case and in modelwith the offsett operating element

Front IP 51Back IP 50

– For personal protection IP 2x Terminals covered with cap

7SJ63/5/6∗ –∗ A/C in housing for detached operator panel 1/1 33 pounds (15 kg)

7SJ631/2/3∗ –∗ F/G in housing without operator panel 1/2 17.6 pounds (8 kg)

7SJ63/5/6∗ –∗ F/G in housing without operator panel 1/1 33 pounds (15 kg)

7SJ640∗ –∗ B in surface mounting housing 1/3 17.6 pounds (8 kg)

7SJ641/2∗ –∗ B in surface mounting housing 1/2 24.3 pounds (11 kg)

7SJ645∗ –∗ B in surface mounting housing 1/1 33 pounds (15 kg)

7SJ641/2∗ –∗ A/C in housing for detached operator panel 1/2 17.6 pounds (8 kg)

7SJ645∗ –∗ A/C in housing for detached operator panel 1/1 26.4 pounds (12 kg)

7SJ641/2∗ –∗ F/G in housing without operator panel 1/2 17.6 pounds (8 kg)

7SJ645∗ –∗ F/G in housing without operator panel 1/1 26.4 pounds (12kg)

7SJ640∗ –∗ D/E in flush mounting housing 1/3 11.0 pounds (5 kg)

7SJ641/2∗ –∗ D/E in flush mounting housing 1/2 13.2 pounds (6 kg)

7SJ645∗ –∗ D/E in flush mounting housing 1/1 22.0 pounds (10 kg)

Detached operator panel 5.5 pounds (2,5 kg)

Variant Case Size Weight (mass)

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Definite-Time Overcurrent Protection (50 and 50N Elements)

4.2 Definite-Time Overcurrent Protection (50 and 50N Elements)

Pickup and TimeDelay Ranges/Resolutions

Pickup Current 50–1 (phases) 0.50 A to 175.00 A1)(increments 0.05 A)1)or ∞ (ineffective, no pickup)

Pickup Current 50N–1 (ground)0.25 A to 175.00 A1)(increments 0.05 A)1)or ∞ (ineffective, no pickup)

Pickup Current 50–2 (phases) 0.50 A to 175.00 A1)(increments 0.05 A)1)or ∞ (ineffective, no pickup)

Pickup Current 50N–2 (ground)0.25 A to 175.00 A1)(increments 0.05 A)1)or ∞ (ineffective, no pickup)

Delay Times T 50–1, 50–2, 0.00 s to 60.00 s (increments 0.01 s)50N–1, 50N–2 or ∞ (does not expire)

The set times are pure delay times.

Inherent OperatingTimes

Pickup times without delay (T) or inrush stabilization. With inrush stabilization add10 ms

50–1, 50–2, 50N–1, 50N–2

– Current = 2 x Pickup Value approx. 30 ms– Current = 10x Pickup Value approx. 25 ms

Dropout Times

50–1, 50–2, 50N–1, 50N–2 approx. 40 ms

Dropout Dropout/Pickup (ratio) approx. 0.95 for I/IN ≥ 0.3

Tolerances Pickup Current 50–1, 50–2,50N–1, 50N–2 2 % of setting value or 50 mA1)Delay Times T 1 % of setting value or 10 ms

Influencing Vari-ables for Pickup

Power supply direct voltage in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1 %

Temperatur in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1 %

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonic currents– Up to 10 % 3. Harmonic 1 %– Up to 10 % 5. Harmonic 1 %

1) For IN = 1 A, divide all limits and increments by 5.

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Technical Data

4.3 Inverse-Time Overcurrent Protection (51 and 51N Elements)

Pickup and TimeMultiplier Ranges/Resolutions

Pickup Current 51 0.50 A to 20.00 A1) (Increments 0.05 A)1)

Pickup Current 51N 0.25 A to 20.00 A1) (Increments 0.05 A)1)

Time Multipliers for Tp, TEp 0.05 s to 3.20 s (Increments 0.01 s)Ip, IEp, IEC–Characteristics or ∞ (delay does not expire)

Time Multiplier for 51, 51N D 0.05 s to 15.00 s (Increments 0.01 s)ANSI characteristics or ∞ (delay does not expire)

Trip Time Charac-teristics as per IEC

As per IEC 60255-3, Section 3.5.2 or BS 142 (See also Figure 4-1 and 4-2)

The trip times for I/Ip ≥ 20 are identical to those for I/Ip = 20.

Pickup threshold approx. 1.10 · Ip

1) For IN = 1 A, divide all limits and increments by 5.

t 0.14

I Ip⁄( )0.021–

---------------------------------- Tp⋅= NORMAL INVERSE (Type A)

t13.5

I Ip⁄( )11–

--------------------------- Tp⋅= VERY INVERESE (Type B)

t80

I Ip⁄( )21–

--------------------------- Tp⋅= EXTREMELY INV. (Type C)

t 120

I Ip⁄( )11–

--------------------------- Tp⋅= LONG INVERSE (Type B)

For All Characteristics

t trip time in secondsTp setting value of the time multiplierI fault currentIp setting value of the pickup current

[s]

[s]

[s]

[s]

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Inverse-Time Overcurrent Protection (51 and 51N Elements)

Reset Time Charac-teristic as per IEC

As per IEC 60255–3, Section 3.5.2 or BS 142 (See also Figure 4-1 and 4-2))

Dropout IEC without Disk–Emulation approx. [1.05 · Ip setting value] for Ip/IN>0.3,Dropout/Pickup (ratio) corresponds to approx. [0.95·pickup

threshold]

IEC with Disk Emulation approx. [0.90 · Ip setting value]Dropout/Pickup (ratio)

Tolerances Pickup-, Dropout Thresholds Ip, IEp 2 % of setting value or 50 mA1)

Trip Time for 2 ≤ I/Ip ≤ 20 5 % of reference (calculated) value + 2 %current tolerance, respectively 30 ms

Dropout Time for 0.05≤ I/Ip ≤ 0.90 5 % of reference (calculated) value + 2 %current tolerance, respectively 30 ms

Influencing Vari-ables

Power Supply Direct Voltage in Range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1 %

Temperature in Range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in Range0.95 ≤ f/fN ≤ 1.05 1 %, referring to reference time

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonic currents– Up to 10 % 3. Harmonic 1 %– Up to 10 % 5. Harmonic 1 %

1) For IN = 1 A, divide all limits and increments by 5.

tReset9.7

I Ip⁄( )21–

--------------------------- Tp⋅=NORMAL INVERSE (Type A)

tReset43.2

I Ip⁄( )21–

--------------------------- Tp⋅=VERY INVERSE (Type B)

tReset58.2

I Ip⁄( )21–

--------------------------- Tp⋅=EXTREMELY INV. (Type C)

tReset80

I Ip⁄( )21–

--------------------------- Tp⋅=LONG INVERSE (Type B)

For all Characteristics

tRESET = Reset time in secondsTp = Setting value of the time multiplierI = Fault CurrentIp = Setting value of the pickup current

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Technical Data

Figure 4-1 Reset Time and Trip Time Characteristics Of The Inverse-time Overcurrent Protection, As Per IEC 60755–3

10

3

0,1

1000

200

100

50

20

5

0,2

0,05

t [s]

30

300

0,05 0,1 0,2 0,3 0,7 1I/Ip

0,5

Tp

3,2

1,6

0,8

0,4

0,2

0,1

0,05

0,1

0,2

0,4

1,6

3,2

0,05

1

0,3

0,1

1 2 3 5 10 20

100

20

10

5

2

0,5

0,2

0,05

Normal inverse:

Very inverse:(Type B)

Tp

t [s]

t [s]

I/Ip

I/Ip

1 2 3 5 10 20

[s]

[s]

3

30

t0 14,

I Ip⁄( )0 02,1–

------------------------------------ Tp⋅=(Type A)

t 13 5,

I Ip⁄( )11–

---------------------------- Tp⋅=

0,8

0,1

0,2

0,4

1,6

3,2

0,05

0,8

7

Tp

Operate TimeReset Time

Reset Normal inverse: [s]t 9 7,

I Ip⁄( )2

1–---------------------------- Tp⋅=

Reset Very inverse:(Type B)

[s]t 43 2,

I Ip⁄( )2

1–---------------------------- Tp⋅=

(Type A)

1

0,3

0,1

100

20

10

5

2

0,5

0,2

0,05

t [s]

3

30

0,05 0,1 0,2 0,3 0,7 1I/Ip

0,5

Tp

3,2

1,6

0,8

0,4

0,2

0,1

0,05

3,2

0,30,5

1

2

500

10

3

0,1

1000

200

100

50

20

5

0,05

30

300

0,3

0,5

1

2

500

362 7SJ62/63/64 ManualC53000–G1140–C147–1

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Inverse-Time Overcurrent Protection (51 and 51N Elements)

Figure 4-2 Reset Time and Trip Time Characteristics Of The Inverse-time Overcurrent Protection, As Per IEC 60755–3

I/Ip

1 2 3 5 10 20

t [s]

0,1 0,20,4

1,6

3,2

0,8

Tp

0,05

Extremely inverse:(Type C)

[s]t 80

I Ip⁄( )21–

---------------------------- Tp⋅=

0,1

0,2

0,4

3,2

0,05

10

3

1

1 2 3 5 10 20

1000

200

100

50

20

5

2

0,5

Long inverse:

Tp

t [s]

I/Ip

[s]

30

300

0,8

7

t 120

I Ip⁄( )1 1–---------------------------- Tp⋅=

1,6

Reset Extremely inverse:(Type C)

[s]t58 2,

I Ip⁄( )2 1–---------------------------- Tp⋅=

Reset Long inverse: [s]t80

I Ip⁄( )2

1–---------------------------- Tp⋅=

Operate TimeReset Time

t [s]

I/Ip

10

3

0,1

1000

200

100

50

20

5

0,05

30

300

0,30,5

1

2

500

10

3

0,1

1000

200

100

50

20

5

0,05

30

300

0,3

0,5

1

2

500

0,05 0,1 0,2 0,3 0,7 10,5

Tp

1,6

0,8

0,4

0,2

0,1

0,05

3,2

I/Ip

500

I/Ip

0,05 0,1 0,2 0,3 0,7 10,5

10

3

0,1

1000

200

100

50

20

5

0,05

30

300

0,3

0,5

1

2

500t [s] Tp

1,6

0,8

0,4

0,2

0,1

0,05

3,2Tp

(Type B) (Type B)

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Technical Data

Trip Time Charac-teristics as perANSI

As per ANSI/IEEE (see also Figures 4-3 to 4-6)

The trip times for I/Ip ≥ 20 are identical to those for I/Ip = 20.

Pickup Threshold approx. 1.10 · Ip

1) For IN = 1 A, divide all limits and increments by 5.

t 8.9341

I Ip⁄( )2.09381–

--------------------------------------- 0.17966+

D⋅=INVERSE

VERY INVERSE

EXTREMELY INVERSE

For all Characteristics

t = Trip time in secondsD = Setting value of the time multiplierI = Fault CurrentIp = Setting value of the pickup current

DEFINITE INVERSE

SHORT INVERSE

LONG INVERSE

MODERATELY INV.

t 0.2663

I Ip⁄( )1.29691–

--------------------------------------- 0.03393+

D⋅=

t 5.6143I Ip⁄( ) 1–

------------------------ 2.18592+ D⋅=

t0.0103

I Ip⁄( )0.021–

---------------------------------- 0.0228+

D⋅=

t3.922

I Ip⁄( )21–

--------------------------- 0.0982+

D⋅=

t5.64

I Ip⁄( )21–

--------------------------- 0.02434+

D⋅=

t0.4797

I Ip⁄( )1.56251–

--------------------------------------- 0.21359+

D⋅=

[s]

[s]

[s]

[s]

[s]

[s]

[s]

364 7SJ62/63/64 ManualC53000–G1140–C147–1

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Inverse-Time Overcurrent Protection (51 and 51N Elements)

Reset Time Charac-teristic as per ANSI

As per ANSI/IEEE (see also Figures 4-3 to 4-6)

Dropout ANSI without Disk–Emulation approx. [1.05 · Ip setting value] for Ip/IN>0.3,Dropout/Pickup (ratio) corresponds to approx. [0.95·pickup

threshold]

ANSI with Disk Emulation approx. [0.90 · Ip setting value]Dropout/Pickup (ratio)

Tolerances Pickup-, Dropout Thresholds Ip, IEp 2 % of setting value or 50 mA1)

Trip Time for 2 ≤ I/Ip ≤ 20 5 % of reference (calculated) value + 2 %current tolerance, respectively 30 ms

Dropout Time for 0.05≤ I/Ip ≤ 0.90 5 % of reference (calculated) value + 2 %current tolerance, respectively 30 ms

Influencing Vari-ables

Power Supply Direct Voltage in Range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1 %

Temperature in Range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in Range0.95 ≤ f/fN ≤ 1.05 1 %, referring to reference time

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

1) For IN = 1 A, divide all limits and increments by 5.

tReset8.8

I Ip⁄( )2.09381–

---------------------------------------

D⋅=ANSI INVERSE

tReset0.97

I Ip⁄( )21–

---------------------------

D⋅=ANSI MODERATELY INV.

tReset5.82

I Ip⁄( )21–

---------------------------

D⋅=ANSI EXTREMELY INV.

For all Characteristics

tRESET = Reset time in secondsD = Setting value of the time multiplierI = Fault CurrentIp = Setting value of the pickup current

for 0.05 < (I/Ip) ≤ 0.90

tReset4.32

I Ip⁄( )21–

---------------------------

D⋅=ANSI VERY INVERSE

tReset1.03940

I Ip⁄( )1.56251–

---------------------------------------

D⋅=ANSI DEFINITE INV.

tReset0.831

I Ip⁄( )1.29691–

---------------------------------------

D⋅=ANSI SHORT INVERSE

tReset12.9

I Ip⁄( )11–

---------------------------

D⋅=ANSI LONG INVERSE

[s]

[s]

[s]

[s]

[s]

[s]

[s]

3657SJ62/63/64 ManualC53000–G1140–C147–1

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Technical Data

Figure 4-3 Reset Time and Trip Time Characteristics Of The Inverse-time Overcurrent Protection, As Per ANSI/IEEE

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

15

10

5

2

1

0.5

0.3

200

3

50

D [s]

RESET SHORT INVERSE [s]t0.831

I I⁄( )1.29691–

-------------------------------------------

D⋅= t0.2663

I Ip⁄( )1.29691–

------------------------------------------- 0.03393+

D⋅=SHORT INVERSE

I/Ip

D [s]

1 2

5

10

15

0.5

2 3 5 10 20

[s]

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

5

2

1

0.5

10

D [s]

15

I/Ip

1 2 3 5 10 20

t8.9341

I Ip⁄( )2.0938

1–------------------------------------------- 0.17966+

D⋅=INVERSE [s]

Operate Time

RESET INVERSE t8.8

I Ip⁄( )2.0938

1–-------------------------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

0.3

200

3

50 5

2

1

0.5

10

D [s]

15

Reset Time

[s]

366 7SJ62/63/64 ManualC53000–G1140–C147–1

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Inverse-Time Overcurrent Protection (51 and 51N Elements)

Figure 4-4 Reset Time and Trip Time Characteristics Of The Inverse-time Overcurrent Protection, As Per ANSI/IEEE

LONG INVERSE

D [s]

I/Ip

1

2

5

10

15

0.5

1 2 3 5 10 20

[s]t5.6143I Ip⁄( ) 1–

------------------------- 2.18592+

D⋅=RESET LONG INVERSE t12.9

I Ip⁄( )1 1–----------------------------

D⋅= [s]

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

0.3

200

3

50

5

2

1

0.5

10

D [s]15

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

RESET MODERATELY INVERSE [s]t0.97

I Ip⁄( )2

1–----------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

10

5

2

1

0.5

0.3

200

3

50D [s]

MODERATELY INVERSE t0.0103

I Ip⁄( )0.02

1–------------------------------------- 0.0228+

D⋅=

D [s]

I/Ip

1

2

5

10

15

0.5

2 3 5 10 20

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

[s]

15

Operate TimeReset Time

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Technical Data

Figure 4-5 Reset Time and Trip Time Characteristics Of The Inverse-time Overcurrent Protection, As Per ANSI/IEEE

RESET VERY INVERSE [s]t4.32

I Ip⁄( )2 1–----------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

10

5

2

1

0.5

0.3

200

3

50

15

D [s]

D [s]

I/Ip

1

2

5

10

15

0.52 3 5 10 20

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

VERY INVERSE [s]t3.922

I Ip⁄( )2 1–---------------------------- 0.0982+

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

10010

5

2

1

0.5

0.3

RESET EXTREMELY INVERSE [s]t5.82

I Ip⁄( )2

1–----------------------------

D⋅=

200

3

50

D [s]

D [s]

I/Ip

12

5

10

15

0,5

2 3 5 10 20

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

EXTREMELY INVERSE t5.64

I Ip⁄( )2

1–---------------------------- 0.02434+

D⋅= [s]

15

Operate TimeReset Time

368 7SJ62/63/64 ManualC53000–G1140–C147–1

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Inverse-Time Overcurrent Protection (51 and 51N Elements)

Figure 4-6 Reset Time and Trip Time Characteristics Of The Inverse-time Overcurrent Protection, As Per ANSI/IEEE

RESET DEFINITE INVERSE [s]t1.0394

I Ip⁄( )1.56251–

-------------------------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

15

10

5

2

1

0.5

0.3

200

3

50D [s]

D [s]

I/Ip

1

2

5

15

0.5

1 2 3 5 10 20

DEFINITE INVERSE [s]t0.4797

I Ip⁄( )1.56251–

------------------------------------------- 0.21359+

D⋅=

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

10

Operate TimeReset Time

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Technical Data

4.4 Directional Time Overcurrent Protection (67 and 67N Elements)

Overcurrent Ele-ments

The same specifications and characteristics apply as for non-directional time overcur-rent protection (see Sub-sections 4.2 and 4.3).

Determining Direc-tion

Moreover, the following data apply for determining fault direction:

For Phase Faults Polarization With short-circuit free voltages, withvoltage memory (memory duration is 2cycles) for measurement voltages that aretoo low.

Forward Range Can be set in 3 stages (3 protection areas):Inductive 45° ± 86°Resistive 0° ± 86°Capacitive –45° ± 86°

(if short-circuit free voltage vertical toshort circuit voltage)

Directional Sensitivity Unlimited for one and two phase faults.For three phase faults, dynamically unlimit-ed, steady-state approx. 7V phase-to-phase.

For Ground Faults Polarization With zero sequence quantities

Forward Range Can be set in 3 stages (3 protection areas)Inductive 45° ± 84°Resistive 0° ± 84°Capacitive –45° ± 84°

Directional Sensitivity approx. 5 V displacement voltage, mea-sured

approx. 12 V displacement voltage, cal-culated

Inherent OperatingTimes

Pickup times without intentional delay or inrush stabilization. With inrush stabilization,add 10 ms.

67-1, 67-2, 67N-1, 67N-2

– Current = [2 x pickup] approx. 45 ms– Current = [10 x pickkup] approx. 40 ms

Dropout Times

67-1, 67-2, 67N-1, 67N-2 approx. 40 ms

Tolerances Phase angle errors under reference conditions

– For phase faults and for ground faults ± 3° electrical

Influencing Vari-ables

Frequency Influence

– With no memory voltage approx. 1° in range 0.95 < f/fN < 1.05

– Function is blocked in frequency range f < 55 Hz or f > 65 Hz

370 7SJ62/63/64 ManualC53000–G1140–C147–1

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Inrush Restraint

4.5 Inrush Restraint

Controlled Elements All 50, 50N, 51, 51N, 67, and 67N Elements

Adjustment Rang-es/ Resolution

Stabilization Factor I2f/I 10 % to 45 % (Increments 1 %)Second Harmonic

Function LimitsCrossblock

Lower Function Limit at least one phase current ≥ 1.25 A1) Upper Function Limit, Adjustable 1.50 A to 125.00 A1)(Increments 0.05 A)1)

Crossblock Ia, Ib, Ic ON/OFF

1) For IN = 1 A, divide all limits and increments by 5.

4.6 Dynamic Cold Load Pick-up Function (50c, 50Nc, 51Nc, 67c, 67Nc)

Timed Changeoverof Settings

Controlled Elements Directional and non-directional time over-current protective elements (separatephase andground settings)

Initiation Criteria • Current Criteria“BkrClosed I MIN”• Interrogation on the

circuit breaker position• Automatic reclosing function ready• Binary input

Timing 3 time levels (TCB Open, TActive, TStop)

Current Control Current threshold “BkrClosed I MIN”(reset on current falling below threshold:monitoring with timer)

Adjustment Rang-es/ Resolution

Current Control“BkrClosed I MIN” 0.20 A to 5.00 A1) (Increments 0.05 A)1 )

Time Until Changeover TCB Open 0 s to 21600 s (= 6 h) (Increments 1 s)To Dynamic Settings

Period Dynamic TActive 4 s to 21600 s (= 6 h) (Increments 1 s)Settings are EffectiveAfter a Reclosure

Fast Reset Time TStop 1 s to 600 s (= 10 min) (Increments 1 s)or ∞ (fast reset inactive)

Dynamic Settings of Pickup Adjustable within the same ranges 1)Currents and Time Delays and with the same increments 1) asor Time Multipliers the directional and non-directional time

overcurrent protection

1) For IN = 1 A, divide all limits and increments by 5.

3717SJ62/63/64 ManualC53000–G1140–C147–1

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Technical Data

4.7 Voltage Protection (27 and 59)

Setting Ranges /Resolution

Undervoltage 27-1, 27-2 Measurement Quantities:PositiveSequence Voltages

- Pickup Voltage,(phase-ground volt.) 10 V to 210 V (Increments 1 V)- Pickup Voltage, (phase-phase volt.) 10 V to 120 V (Increments 1 V)

Dropout Ratio for 27-1 r = 1.05 to 3.00 (Increments 0.01)

Dropout Ratio for 27-1 r · pickup max. 130 V for phase-phase voltagesmax. 225 V for phase-ground voltage

Time Delays 27-Delay 0.00 s to 100.00 s (Increments 0.01 s)or ∞ (does not expire)

Current Supervision ON/OFFby 50 Element “BkrClosed I MIN” 0.20 A to 5.00 A1) (Increments 0.05 A)1)

Overvoltage 59-1, 59-2

- Pickup Voltage, (phase-ground volt.) 40 V to 225 V (Increments 1 V)- Pickup Voltage, (phase-phase volt.) 40 V to 130 V (Increments 1 V)

Time Delays 59-Delay 0.00 s to 100.00 s (Increments 0.01 s)or ∞ (does not expire)

The set time are pure delay times.

Inherent OperatingTimes

Pickup Times– Undervoltage 27-1, 27-2 approx. 50 ms– Overvoltage 59-1, 59-2 approx. 50 ms

Dropout Times– Undervoltage 27-1, 27-2 approx. 50 ms– Overvoltage 59-1, 59-2 approx. 50 ms

Dropout Ratios – Dropout / Pickup (Voltage ratio) 27-2 1.05– Dropout / Pickup (Voltage ratio) 59 0.95

Tolerances – Pickup Voltages 3% of set value, or 1V– Time Delays T 1% of set value, or 10 ms

Influencing Vari-ables

Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.3 % /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1%

Frequency in rangef < 55 Hz or f > 65 Hz27-1, 27-2 increased tolerances; overfunction possible59-1, 59-2 function is blocked

Harmonics- Up to 10% 3rd harmonic 1%- Up to 10% 5th harmonic 1%

1) For IN = 1A, divide the limits by 5.

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Negative Sequence Protection (46)

4.8 Negative Sequence Protection (46)

4.8.1 Definite–Time Elements (46-1 and 46-2)

Pickup and TimeDelay Ranges/Resolutions

Pickup Current 46-1 0.50 A to 15.00 A 1)(Increments 0.05 A) 1)or ∞ (ineffective, no pickup)

Pickup Current 46-2 0.50 A to 15.00 A 1)(Increments 0.05 A) 1)or ∞ (ineffective, no pickup)

Time Delays 46-1, 46-2 0.00 s to 60.00 s (Increments 0.01 s)or ∞ (does not expire)

Functional Limits Lower Functional Limit at least one phase current > 0.5 A1)

Upper Functional Limit all phase currents ≤ 20 A1)

Inherent OperatingTimes

Pickup Time approx. 35 ms

Dropout Time approx. 35 ms

Dropout Dropout/Pickup (ratio) 46-1, 46-2 approx. 0.95 for I2/IN > 0.3

Tolerances Pickup Currents 46-1, 46-2 3% of set value or 50 mA1)Time Delays 1% or 10 ms

Influencing Vari-ables for Pickup-Pickup Currents

Power Supply DC voltage in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1%

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonic currents– Up to 10 % 3rd Harmonic 1 %– Up to 10 % 5th Harmonic 1 %

4.8.2 Inverse–Time Elements (46-TOC)

Pickup and TimeMultiplier

Pickup Current 46–TOC 0.50 A to 10.00 A1)(Increments 0.05 A)1)

Time Multiplier TI2p 0.05 s to 3.20 s (Increments 0.01 s)(IEC) or ∞ (does not trip)

Time Multiplier DI2p 0.50 s to 15.00 s (Increments 0.01 s)(ANSI) or ∞ (does not trip)

Functional Limits Lower Functional Limit at least one phase current > 0.5 A1)Upper Functional Limit all phase currents ≤ 20 A1)

1) For IN = 1 A, divide all limits and increments by 5.

3737SJ62/63/64 ManualC53000–G1140–C147–1

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Technical Data

Trip Time Charac-teristics as perIEC 60255–3

See also Figure4-7

Trip Time Charac-teristics as perANSI

See also Figures4-8 and 4-9

The trip times for I2/I2p ≥ 20 are identical to those for I2/I2p= 20.

Pickup Threshold approx. 1.10 · I2p

Tolerances Pickup Current I2p 3% of set value or 50 mA1)

Time for 2 ≤ I2/I2p ≤ 20 5% of reference (calculated) value + 2 %current tolerance, or 30 ms

1) For IN = 1 A, divide all limits and increments by 5.

t 0.14

I2 I2p⁄( )0.021–

---------------------------------------- TI2p⋅=IEC NORMAL INVERSE

t13.5

I2 I2p⁄( )11–

--------------------------------- TI2p⋅=IEC VERY INVERSE

t80

I2 I2p⁄( )21–

--------------------------------- TI2p⋅=IEC EXTREMELY INVERSE

Where:

t trip time in secondsTI2p setting value of the time multiplierI2 negative sequence currentsI2p setting value of the pickup current

for 1.1 < (I2/I2p) ≤ 20

[s]

[s]

[s]

t 8.9341

I2 I2p⁄( )2.09381–

--------------------------------------------- 0.17966+

DI2p⋅=ANSI INVERSE

t 0.0103

I2 I2p⁄( )0.021–

---------------------------------------- 0.0228+

DI2p⋅=ANSI MODERATELY

t 5.64

I2 I2p⁄( )21–

--------------------------------- 0.02434+

DI2p⋅=ANSI EXTREMELY

Where:

t trip time in secondsDI2p setting value of the time multiplierI2 negative sequence currentsI2p setting value of the pickup current

for 1.1 < (I2/I2p) ≤ 20

t 3.922

I2 I2p⁄( )21–

--------------------------------- 0.0982+

DI2p⋅=ANSI VERY INVERSE

INVERSE

INVERSE

[s]

[s]

[s]

[s]

374 7SJ62/63/64 ManualC53000–G1140–C147–1

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Negative Sequence Protection (46)

Reset Time Charac-teristics as perANSI

See Also Figures 4-8 and 4-9

Dropout IEC and ANSI (without Disk Emulation) approx. 1.05 · I2p Setting Value, whichis approx. [0.95 · pickup threshold]

ANSI with Disk–Emulation approx. 0.90 · I2p Setting Value

Tolerances Reset Current I2p 2% of set value or 50 mA1)

Time for 0.05≤ I2/I2p ≤ 0.90 5% of reference (calculated) value + 2 %current tolerance, minimum 30 ms

Influencing Vari-ables for PickupCurrents

Power supply DC voltage in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1%

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonic currents– Up to 10 % 3rd Harmonic 1 %– Up to 10 % 5th Harmonic 1 %

1) For IN = 1 A, divide all limits and increments by 5.

tReset8.8

I2 I2p⁄( )2.09381–

---------------------------------------------

DI2p⋅=ANSI INVERSE

tReset0.97

I2 I2p⁄( )21–

---------------------------------

DI2p⋅=ANSI MODERATELY

tReset5.82

I2 I2p⁄( )21–

---------------------------------

DI2p⋅=ANSI EXTREMELY

Where:

tReset trip time in secondsDI2p setting value of the time multiplierI2 negative sequence currentsI2p setting value of the pickup current

for 0.05 < (I2/I2p) ≤ 0.90

tReset4.32

I2 I2p⁄( )21–

---------------------------------

DI2p⋅=ANSI VERY INVERSE

INVERSE

INVERSE

[s]

[s]

[s]

[s]

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Technical Data

Figure 4-7 Trip Time Characteristic Curves Of The Inverse-time Negative Sequence Element 46-TOC, per IEC 60255–3

0.1

0.2

0.4

1.6

3.2

0.05

IEC EXTREMELY INVERSE:

1

0.3

0.1

1 2 3 5 10 20

100

20

10

5

2

0.5

0.2

0.05

IEC NORMAL INVERSE: IEC VERY INVERSE:

TI2p

t [s] t [s]

I2/I2p

1

0.3

0.1

1 2 3 5 10 20

100

20

10

5

2

0.5

0.2

0.05

[s] [s]

1 2 3 5 10 20

0.3

0.1

100

20

10

2

0.05

5

[s]

0.2

0.5

1

t [s]

3

3

30 30

3

0.8

0.1

0.2

0.4

1.6

3.2

0.05

0.8

7

0.1 0.2

0.4

1.6

3.2

0.8

0.05

t = Trip time in seconds

TI2p= Setting value of the time multiplier

I2 = Negative Sequence Current

I2p = Setting value of the pickup current

t0.14

I2 I2p⁄( )0.021–

--------------------------------------------- TI2p⋅= t13.5

I2 I2p⁄( )1 1–------------------------------------ TI2p⋅=

I2/I2p

TI2p

I2/I2p

TI2p

t 80

I2 I2p⁄( )2

1–------------------------------------ TI2p⋅=

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Negative Sequence Protection (46)

Figure 4-8 Reset Time and Trip Time Characteristics Of The Inverse-time Negative Sequence Element, 46-TOC, ANSI

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

5

2

1

0.5

10

D [s]

15

I/Ip

1 2 3 5 10 20

t8 9341,

I Ip⁄( )2 0938,1–

--------------------------------------------- 0 17966,+

D⋅=INVERSE [s]

Operate Time

RESET INVERSE t8 8,

I Ip⁄( )2 0938,1–

---------------------------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

0.3

200

3

50 5

2

1

0.5

10

D [s]

15

Reset Time

[s]

RESET MODERATELY INVERSE [s]t 0 97,

I Ip⁄( )2

1–----------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

10

5

2

1

0.5

0.3

200

3

50D [s]

MODERATELY INVERSE t 0 0103,

I Ip⁄( )0 02,

1–-------------------------------------- 0 0228,+

D⋅=

D [s]

I/Ip

1

2

5

10

15

0.5

2 3 5 10 20

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

[s]

15

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Technical Data

Figure 4-9 Reset Time and Trip Time Characteristics Of The Inverse-time Negative Sequence Element, 46-TOC, ANSI

RESET VERY INVERSE [s]t4,32

I Ip⁄( )2

1–----------------------------

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

10

5

2

1

0.5

0.3

200

3

50

15

D [s]

D [s]

I/Ip

1

2

5

10

15

0.52 3 5 10 20

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

VERY INVERSE [s]t3 922,

I Ip⁄( )2

1–---------------------------- 0 0982,+

D⋅=

I/Ip

0.05 0.1 0.2 0.5 1.0

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

10010

5

2

1

0.5

0.3

RESET EXTREMELY INVERSE [s]t 5 82,

I Ip⁄( )2

1–----------------------------

D⋅=

200

3

50

D [s]

D [s]

I/Ip

12

5

10

15

0.5

2 3 5 10 20

0.3

0.1

500

20

10

2

0.05

5

0.2

0.5

1

t [s]

30

100

200

3

50

1

EXTREMELY INVERSE t 5 64,

I Ip⁄( )2

1–---------------------------- 0 02434,+

D⋅= [s]

15

Operate TimeReset Time

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Motor Starting Protection (48)

3797SJ62/63/64 ManualC53000–G1140–C147–1

4.9 Motor Starting Protection (48)

Setting Ranges/In-crements

Motor Starting Current ISTARTUP 5.00 A to 80.00 A1) (Increments 0.05 A)1)

Pickup Threshold IMOTOR START 3.00 A to 50.00 A1)(Increments 0.05 A)1)

Permissible Starting Time TSTARTUP 1.0 to 180.0 s (Increments 0.1 s)

Permissible Locked Rotor Time TLOCKED-ROTOR 0.5 s to 120.0 s (Increments 0.1 s)or ∞ (step is ineffective)

Trip Time Charac-teristic

Dropout Ratio Irms/IMOTOR START approx. 0.95

Tolerance Pickup Threshold 2 % of set value, or 50 mA1)

Time Delay 5 % or 30 ms

Influencing Valuesfor Pickup Thresh-old

Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.3% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1%

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonics- Up to 10% 3rd harmonic 1%- Up to 10% 5th harmonic 1%

1) for IN= 1 A, divide all limits by 5.

tISTARTUP

Irms------------------------

2TSTARTUP⋅=

Trip Time Characteristics

ISTARTUP Motor starting current setting.Irms Actual current flowing.IMOTOR START Pickup threshold setting,

used to detect motor startup.t Trip time in seconds.

for Irms > IMOTOR START

Where:

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Technical Data

4.10 Start Inhibit for Motors (66/68)

Setting Ranges /Resolutions

Starting Current IStart/IMotor nom 3.0 to 10.0 (Increments 0.1)Relative to Nominal Motor Current

Nominal Motor Current IMotor nom 1.0 A to 6.0 A1) (Increments 0.5 A)1)

Maximum Permissible TStart Max 3 s to 320 s (Increments 1 s)Starting Time

Temperature TEqual 0.0 min to 320.0 min (Increments 0.1 min)Equalization Time

Minimum inhibit time TMIN. INHIBIT TIME0.2 min to 120.0 min (Increments 0.1 min)

Maximum Permissible nwarm 1 to 4 (Increments 1)Number of Warm Starts

Difference between ncold - nwarm 1 to 2 (Increments 1)Cold and Warm Starts

Extension K-Factor for kτat STOP 0.2 to 100.0 (Increments 0.1)Cooling Simulations ofRotor at Rest

Extension K-Factor for kτat RUNNING 0.2 to 100.0 (Increments 0.1)Cooling Simulations ofRotor in operation

Restarting Limit

Where:

Influencing Values Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.3% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1%

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

1) For IN = 1 A, divide all limits by 5.

ΘRESTART ΘRot.max.perm

nCOLD 1–

nCOLD---------------------------⋅=

ΘRestart Temperature limit belowwhich restarting is possible

ΘRot.max.permmaximum permissible motorover-temperature (= 100 % inoperating measured valueΘRot/ΘRot trip)

nCold Number of permissiblerestarts from cold state

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Frequency Protection (81 Over-Frequency and Under-Frequency)

4.11 Frequency Protection (81 Over-Frequency and Under-Frequency)

Setting Ranges/Resolutions

Number of Frequency Elements 4: each can be 81/O or 81/U

Pickup Frequency 81–1 to 81–4 45.50 Hz to 54.50 Hz (Increments 0.01 Hz)@ fN = 50 Hz

81–1 to 81–4 55.50 Hz to 64.50 Hz(Increments 0.01 Hz)@ fN = 60 Hz

Time Delay 81–1 to 81–4 0.00 s to 100.00 s (Increments 0.01 s)or ∞ (does not expire)

Undervoltage Blocking Vmin 10 V to 150 V (Increments 1 V)(V1 positive sequence voltage)

The set times are pure delay times.

Inherent OperatingTimes

Pickup Times 81/O or 81/U approx. 150 ms

Dropout Times 81/O or 81/U approx. 150 ms

Dropout Frequency ∆f = | Pickup Value – Dropout Value | approx. 20 mHz

Dropout Voltage Dropout Ratio forUndervoltage Blocking(V / Vmin) approx. 1.05

Tolerances – Pickup Frequencies 81/O or 81U 10 mHz

– Undervoltage Blocking 3% of set value or 1 V

– Time Delays 81/O or 81/U 1% of set value or 10 ms

Influencing Vari-ables

Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 0.1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonics- Up to 10% 3rd harmonic 1%- Up to 10% 5th harmonic 1%

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Technical Data

4.12 Thermal Overload Protection (49)

Setting Ranges/Resolutions

K-Factor per IEC 60255-8 0.10 to 4.00 (Increments 0.01)

Time Constant τ 1.0 min to 999.9 min (Increments 0.1 min)

Thermal Alarm ΘAlarm/ΘTrip 50% to 100% of the trip temperature rise(Θ ALARM) (Increments 1%)

Current Overload IAlarm 0.50 A to 20.00 A1) (Increments 0.05 A)1)Alarm (I ALARM)

Extension K-Factor kt - Factor 1.0 to 10.0 relative to the time constantwhen Machine Stopped for the machine running(Increments 0.1)

Emergency Time TEMERGENCY 10 s to 15000 s (Increments 1 s)

Rated overtemperature (for IN) 40 °C to 200 °C (Increments 1 °C)104 °F to 392 °F (Increments 1 °F)

Trip CharacteristicCurve

See also Figure 4-10

Dropout Relations Θ/Θtrip Drops out with ΘAlarm

Θ/ΘAlarm approx. 0.99

I/IAlarm approx. 0.97

Tolerances Referring to k · IN 2 % or 50 mA1);2 % class per IEC 60 255–8

Thermal trip and alarm times 3 % or 1 s for I/(k ·IN) > 1.25;

3 % class per IEC 60 255–8

Influencing Vari-ables Referring to[k · IN]

Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1 %

Temperature in range23 °F≤ ϑamb ≤ 131 °F 0.3% /10º F

requency in range0.95 ≤ f/fN ≤ 1.05 1 %

Frequency in rangef < 55 Hz or f > 65 Hz increased tolerances

1) For IN = 1 A, divide all limits and increments by 5.

t τ

Ik IN⋅------------- 2 Ipre

k IN⋅-------------

2–

Ik IN⋅------------- 2

1–-------------------------------------------------ln⋅=

Trip Characteristic Curve

t trip time in minutesτ Temperature rise time constantI Load currentIpre Pre-load currentk Setting factor per VDE 0435

Part 3011 and IEC 60255–8,(see also Figure 4-10)

IN Nominal current of the device

Where:

for (I/ k · IN) ≤ 8[min]

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Thermal Overload Protection (49)

Figure 4-10 Trip Time Characteristic Curves For The Thermal Overload Protection (49)

1

0.3

0.1

1 2 3 5 10 12

100

20

10

5

2

0.5

0.2

0.05

t [min] t [min]

I/k · IN

1000

1

0.3

0.1

100

20

10

5

2

0.5

0.2

0.05

[min]

3

30 30

3

Parameter:Setting Valueof Time Con-stant

20

200

500

100

50

10

5

21

4 6 7 8

50

t τ

Ik IN⋅--------------

2

Ik IN⋅--------------

21–

--------------------------------ln⋅=

without pre-load:

I/k · IN 1 2 3 5 10 124 6 7 8

with 90 % pre-load:

t τ

Ik IN⋅--------------

2 Iprek IN⋅-------------- 2

Ik IN⋅--------------

21–

---------------------------------------------------ln⋅=

50

Parameter:Setting Valueof Time Con-stant

1000

500

200

100

50

2010521

τ [min]

τ [min]

[min]

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Technical Data

4.13 Sensitive Ground Fault Detection (64, 50Ns, 67Ns)

Displacement Volt-age Element Char-acteristics - For allTypes of GroundFaults

Displacement Voltage, Measured Ve> 1.8 V to 130.0 V (increments 0.1V)

Displacement Voltage, Calculated 3VO>10.0 V to 225.0 V (increments 0.1V)

Pickup Delay Time TDelay Pickup 0.04 s to 320.00 s (increments 0.01 s)or ∞ (does not pickup)

Additional Trip Delay TDelay 0.10 s to 40000.00 s (increments 0.01 s)or ∞ (ineffective)

Measuring time (Inherent Pickup Delay) approx. 60 ms

Dropout Value [0.95 · pickup value] or[Pickup value – 0.6 V]

Measurement ToleranceVe> (measured): 3% of setting value, or 0.3 V3V0> (calculated): 3% of setting value, or 3 V

Operating Time Tolerances 1 % of setting value, or 10 ms

The set times are pure delay times

Phase Detectionfor Ground Faults onan Ungrounded Sys-tem

Measuring Principle Voltage measurement (phase to ground)

VPHASE MIN (ground fault phase) 10 V to 100 V (increments 1 V)

VPHASE MAX (healthy phases) 10 V to 100 V (increments 1 V)

Measurement Tolerance 3% of setting value, or 1 Vas per VDE 0435, Part 303

Ground Fault Pick-upfor All Types ofGround Faults

Definite Time Characteristic

Pickup Current 50-Ns-1for sensitive transformer 0.001 A to 1.500 A (increments 0.001 A)for normal 1-A transformer 0.05 A to 35.00 A (increments 0.01 A)for normal 5-A transformer 0.25 A to 175.00 A (increments 0.05 A)

Delay Time 50-Ns-1 0.00 s to 320.00 s (increments 0.01 s)or ∞ (ineffective)

Pickup Current 50-Ns-2for sensitive transformer 0.001 A to 1.500 A (increments 0.001 A)for normal 1-A transformer 0.05 A to 35.00 A (increments 0.01 A)for normal 5-A transformer 0.25 A to 175.00 A (increments 0.05 A)

Delay Time 50-Ns-2 0.00 s to 320.00 s (increments 0.01 s)or ∞ (ineffective)

Inherent Pickup Time ≤ 60 ms (non-directional)≤ 80 ms (directional)

Dropout/Pickup (ratio) approx. 0.95 for INs ≥ 50 mA

Measurement Tolerance 2 % of setting value or 1 mAOperating Time Tolerance 1 % of setting value or 20 ms

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Sensitive Ground Fault Detection (64, 50Ns, 67Ns)

User-defined Characteristic user-specified characteristic (definedby maximum of 20 pairs of current–trip time values)

Pickup Current 51 Nsfor sensitive transformer 0.001 A to 1.400 A (increments 0.001 A)for normal 1-A transformer 0.05 A to 35.00 A (increments 0.01 A)for normal 5-A transformer 0.25 A to 175.00 A (increments 0.05 A)

Time multiplier 51 Ns 0.10 to 4.00 (increments 0.01)or ∞ (ineffective)

Pickup Threshold approx. 1.10 · INsp

Dropout Threshold approx. 1.05 · INsp for INsp > 50 mA

Measurement Tolerance 2 % of setting value or 1 mA

Operating Time Tolerance in the 7% of reference value for 2 ≤ I/INsp ≤ 20Linear Range + 2% current tolerance, or 70 ms

Influencing Vari-ables

Power supply direct voltage in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1 %

Temperatur in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1 %

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonic currents– Up to 10 % 3rd Harmonic 1 %– Up to 10 % 5th Harmonic 1 %

Note: When using the sensitive transformer, the linear range of the measuring inputfor the sensitive ground fault acquisition is from 0.001 A to 1.6 A. The function is how-ever still preserved for greater currents.

The set times are pure delay times for the definite time characteristic.

Direction Determi-nation for All Typesof Ground Faults

Direction Measurement

– IG and VG measured (ground quantities)– 3I0 and 3V0 calculated

Measuring Principle Real/reactive power measurement

Measuring Enable IRelease direct. element(Current componentperpendicular (90º) toDirection Phasor)for sensitive transformer 0.001 A to 1.200 A (increments 0.001A)for normal 1-A transformer 0.05 A to 30.00 A (increments 0.01A)for normal 5-A transformer 0.25 A to 150.00 A (increments 0.05 A)

Dropout/Pickup (ratio) approx. 0.80

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Technical Data

Measuring Method cosϕ and sinϕ

Direction Phasor –45.0° to +45.0° (increments 0.1°)

Dropout Delay TReset Delay 1 s to 60 s (increments 1 s)

Angle correction for cable converter in 2 operating points F1/I1 and F2/I2:(for resonant-grounded system)

Angle correction F1, F2 0.0° to 5.0° (increments 0.1°)

Currents I1, I2for sensitive transformer 0.001 A to 1.600 A (increments 0.001A)for normal 1-A transformer 0.05 A to 35.00 A (increments 0.01A)for normal 5-A transformer 0.25 A to 175.00 A (increments 0.01A)

Measurement Tolerance 2 % of setting value or 1 mA

Angle Tolerance 3°

Note: Due to the high sensitivity the linear range of the measuring input IN with inte-grated sensitive input transformer is from 0.001 A to 1.6 A. For currents greater than1.6 A, correct directionality can no longer be guaranteed.

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Intermittent Ground Fault Protection

4.14 Intermittent Ground Fault Protection

Setting Ranges/Resolutions

Pick-up value for IE IIE> 0.25 A to 175.00 A1) (increments 0.05 A)1)for 3I0 IIE> 0.25 A to 175.00 A1) (increments 0.05 A)1)for IEE IIE> 0.050 A to 1.500 A (increments 0.001 A)

Pick-up prolongation time TV 0.00 s to 10.00 s (increments 0.01 s)

Earth fault accumulation time Tsum 0.00 s to 100.00 s (increments 0.01 s)

Reset time for accumulation Tres 1 s to 600 s (increments 1 s)

Number of pick-ups for intermittent 2 to 10 (increments 1)earth fault

Inherent OperatingTimes

Pickup Times

– Current = 1.25 x Pickup Value approx. 30 ms– Current ≥ 2 x Pickup Value approx. 22 ms

Drop-off Time (without prolongation time) approx. 22 ms

Tolerances Pickup Value IE> 3 % of setting value e.g. 50 mA1)

Times TV, Tsum, Tres 1 % of setting value or 10 ms

Influencing Vari-ables

Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 0.1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in rangef/fN < 55 Hz or > 65 Hz 1%

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

1) For IN = 1 A, divide all limits and increments by 5.

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Technical Data

4.15 Automatic Reclosing System (79M)

Number of Reclosures 0 to 9 (for both phase and ground)Shots 1 to 4 individually adjustable

For Phase Faults-Processing79 Initiates: Selectable 50-1, 50-2, 51, 67-1, 67-2, 67-TOC,

46-1, 46-2, 46-TOC, Binary Inputs

For Ground Faults-Processing 50-1, 50-2, 51, 67-1, 67-2, 67-TOC,79 Initiates: Selectable 50N-1, 50N-2, 51N, 67N-1, 67N-2,

67N-TOC, Sensitive Ground FaultProtection, Binary Inputs

Blocking of 79 – Trip of protective elements for which79 blocking is set.

– phase fault detected by aprotective element.

– binary input

Last trip command after the reclosing cycleis complete (unsuccessful reclosing).

Trip command from the breaker failureprotection.

Opening the circuit breaker without 79initiation.

External CLOSE Command

Dead Time 0.01 s to 320.00 s (Increments 0.01 s)(Separate for phase and ground and individual for shots 1 to 4)

Extension of Dead Time Using binary input with time monitoring

Blocking duration after manual close 0.50 s to 320.00 s (Increments 0.01 s

Auto reclosing reset time 0.50 s to 320.00 s (Increments 0.01 s)

Safety time until 79 is ready 0.01 s to 320.00 s (Increments 0.01 s)

Start-signal monitoring time 0.01 s to 320.00 s (Increments 0.01 s)or ∞

Circuit Breaker supervision time 0.10 s to 320.00 s (Increments 0.01 s)

Maximum dead time extension 0.50 s to 320.00 s (Increments 0.01 s)or ∞

Action time 0.01 s to 320.00 s (Increments 0.01 s)or ∞

The following protection functions can be influenced by the automatic reclosing func-tion individually for the cycles 1 to 4 (setting value T=T/ instantaneous T=0/ blockedT=infinite): 50-1, 50-2, 51, 67-1, 67-2, 67-TOC,

50N-1, 50N-2, 51N, 67N-1, 67N-2,67N-TOC

Additional Functions Definitive TripCircuit breaker monitoring using, breakerauxiliary contactsSynchronous closing (optionally withintegrated or external synchrocheck)

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Fault Location

4.16 Fault Location

Units of Distance Measurement Secondary Ω,Miles or km of line length 2)

Trigger Trip command, Pickup of an Element,Dropout of an Element, orExternal command via binary input

Reactance Setting (secondary)1) 0.001 to 1.243 Ω/km1) (Incr. 0.001 Ω/km)

Reactance Setting (secondary) 0.002 to 2.000 Ω/mile1)(Incr. 0.001 Ω/mile)

Measurement Tolerance per ≤ 2.5% line length (without infeed) orVDE 0435 part 303 for 0.005 Ω1),Sinusoidal Measurement Quantities 30º ≤ ϕk ≤ 90º and Vk / VN ≥ 0.1 and

Ik/IN≥ 0.11) For IN = 1 A, multiply all values by 5; the increment is always 0.001.2) Homogeneous lines are assumed when the fault distance is given in miles or km.

4.17 Breaker Failure Protection (50BF)

Pickup and TimeDelay Ranges/Resolutions

Pickup of 50 Element BkrClosed I MIN 0.20 A to 5.00 A 1) (Increments 0.05 A)1)

Time Delay TRIP-Timer 0.06 s to 60.00 s (Increments 0.01 s)or ∞ (no trip)

Initiating Time Pickup Times (protection initiates)

- For Internal Start included in time delay- Using Controls included in time delay- For External Start included in time delay

Reset Time approx. 25 ms 2)

Tolerances Pickup Current BkrClosed I MIN 2% of set value, or 50 mA1)Time Delay TRIP-Timer 1% or 20 ms

Influencing Vari-ables

Power supply DC voltage (VDC) in range0.8 ≤ VPS/ VPS nominal ≤ 1.15 1%

Temperature in range23º F ≤ ϑamb ≤ 131º F 0.06% /10º F

Frequency in range0.95 ≤ f/fN ≤ 1.05 1%

Frequency in rangef < 55 Hz or f > 65 Hz function is blocked

Harmonics- Up to 10% 3rd harmonic 1%- Up to 10% 5th harmonic 1%

1) For IN = 1A, divide all limits by 5.2) A further delay for the current may be caused by compensation in the CT secondary

circuit.

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Technical Data

4.18 Synchronism and Voltage Check (25) (7SJ64 only)

Operating Modes – Synchrocheck– Asynchron/Synchron

Additional ReleaseConditions

• live-bus / dead line• dead-bus / live-line• dead-bus and dead-line• bypassing

Voltages Maximum operating voltage Umax 20 V to 140 V (phase-to-phase)(Incr. 1 V)

Minimum operating voltage Umin 20 V to 125 V (phase-to-phase)(Incr. 1 V)

U< for dead-line / dead-bus check 1 V to 60 V (phase-to-phase) (Incr. 1 V)U> for live-line/ live-bus check 20 V to 140 V (phase-to-phase)(Incr. 1 V)

Primary transformer rated voltage U2N 0.10 kV to 800.00 kV (Incr. 0.01 kV)

Tolerances 2 % of pick-up value or 2 VDrop-off to pick-up ratios approx. 0.9 (U>) or 1.1 (U<)

∆U-Measurement Voltage difference 0.5 V to 40 V (phase-to-phase) (Incr. 1 V)Tolerance 1 V

∆f-Measurement ∆f-measurement (f2>f1; f2<f1) 0.01 Hz to 2.00 Hz (Incr. 0.01 Hz)Tolerance 15 mHz

∆α−Measurement ∆α−measurement (α2>α1; α2<α1) 2° to 80° (Increments 1°)Tolerance 2°

Maximum error angle 5° for ∆f ≤ 1 Hz10° for ∆f > 1 Hz

Circuit-breakeroperating time

Circuit-breaker operating time 0.01 s to 0.60 s (Incr. 0.01 s)

ThresholdASYN ↔ SYN

Threshold synchronous / 0.01 Hz to 0.04 Hz (Incr. 0,01 Hz)non-synchronous

Matching Vector group matching via angle 0° to 360° (Increments 1°)Diff. voltage transformers U1/U2 0.50 to 2.00 (Incr. 0,01)

Times Minimum measuring time approx. 80 msMaximum duration TSYN DURATION 0.01 s to 1200.00 s; ∞ (Incr. 0.01 s)of synchronization

Supervision time TSUP VOLTAGE 0.0 s to 60.0 s (Incr. 0,1 s)

Closing time of CB TCB close 0.00 s to 60.00 s (Incr. 0,01 s)

Tolerance of all timers 1 % of set value or 10 ms

Measured Values ofthe SynchronizingFunction

Reference voltage U1in kV primary, in V secondary or in % VNom

- Range 10 % to 120 % VNom- Tolerance*) ≤1 % of measured value or 0.5 % of VNom

*) for rated frequency

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RTD-Boxes for Temperature Detection

Voltage to be synchronized U2in kV primary, in V secondary or in % VNom

- Range 10 % to 120 % VNom- Tolerance*) ≤1 % of measured value or 0.5 % of VNom

Frequency of U1 f1 in Hz- Range fN ± 5 Hz- Tolerance*) 20 mHz

Frequency of U2 f1 in Hz- Range fN ± 5 Hz- Tolerance*) 20 mHz

Voltage difference (U2 – U1)in kV primary, in V secondary or in % VNom

- Range 10 % to 120 % VNom- Tolerance*) ≤1 % of measured value or 0.5 % of VNom

Frequency difference (f2 – f1) in mHz- Range fN ± 5 Hz- Tolerance*) 20 mHz

Angle difference (α2 – α1) in °- Range 0 ° to 180 °- Tolerance*) 0.5 °

*) for rated frequency

4.19 RTD-Boxes for Temperature Detection

TemperatureDetectors

Connectable RTD-boxes 1 or 2

Number of temperature detectorsper RTD-box max. 6

Type of measurement Pt 100 Ω or Ni 100 Ω or Ni 120 Ω

Mounting identification “Oil” or “Ambient” or “Winding” or“Bearing” or “Other”

Thresholds forIndications

for each measuring point:

Stage 1 –50 °C to 250 °C (in increments of 1 °C)–58 °F to 482 °F (in increments of 1 °F)or ∞ (no indication)

Stage 2 –50 °C to 250 °C (in increments of 1 °C)–58 °F to 482 °F (in increments of 1 °F)or ∞ (no indication)

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Technical Data

4.20 User Defined Functions with CFC

Function Modules Function Modules and Task Levels:

Function Modules DescriptionTask Level

MW_BEARBMeter

processing

PLC1_BEARBSlow PLC

PLC_BEARBFast PLC

SFS_BEARBInterlocking

ABSVALUE MagnitudeCalculation

X – – –

ADD Addition X X X X

AND AND-Gate – X X X

BOOL_TO_CO Boolean toControl(Conversion)

– X X –

BOOL_TO_DI Boolean toDouble Point(Conversion)

– X X X

BOOL_TO_IC Boolean toInternal SinglePoint Indication(Conversion)

– X X X

BUILD_DI Create DoublePoint Indication

– X X X

CMD_CHAIN SwitchingSequence

– X X –

CMD_INF Commandinformation

– – – X

CONNECT Connection – X X X

D_FF D-Flipflop – X X X

D_FF_MEMO Status Memoryfor Restart

X X X X

DI_TO_BOOL Double PointIndication toBoolean(Conversion)

– X X X

DIV Division X X X X

DM_DECODE Decode DoublePoint Indication

X X X X

DYN_OR Dynamic Or X X X X

LIVE_ZERO Live-zero, nonlinear Curve

X – – –

LONG_TIMER Timer(max. 1193 h)

X X X X

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User Defined Functions with CFC

Limits Maximum number of TICKS in the task levels

TICKS required by the individual elements

LOOP Feedback Loop – X – –

LOWER_SETPOINT Lower limit X – – –

MUL Multiplication X X X X

NAND NAND-Gate – X X X

NEG Negator – X X X

NOR NOR-Gate – X X X

OR OR-Gate – X X X

RS_FF RS-Flipflop – X X X

SQUARE_ROOT Root Extractor X X X X

SR_FF SR-Flipflop – X X X

SUB Subtraction X X X X

TIMER Timer – X X –

UPPER_SETPOINT Upper limit X – – –

X_OR XOR-Gate – X X X

ZERO_POINT Zero suppression X – – –

Function Modules DescriptionTask Level

MW_BEARBMeter

processing

PLC1_BEARBSlow PLC

PLC_BEARBFast PLC

SFS_BEARBInterlocking

Run-Time Level Limits in TICKS7SJ62 7SJ63 7SJ64

MW_BEARB (Measured value processing) 2536 2536 10000

PLC1_BEARB (Slow PLC processing) 255 300 2000

PLC_BEARB (Fast PLC processing) 130 130 400

SFS_BEARB (Interlocking) 2173 2173 10000

Individual Element Amount of TICKS

Module, basic requirement 5

each input more than 3 inputs for generic modules 1

Connection to an input 6

Connection to an output signal 7

Additional for each configuration sheet 1

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Technical Data

Additonal limits for the following 4 CFC–blocks

Run-Time Level Maximum Number of Blocks in theSequence Levels Already Mentioned

LONG_TIMER TIMER CMD_CHAIN D_FF_MEMO

MW_BEARB

18

---- ----

50PLC1_BEARB9 20

PLC_BEARB

SFS_BEARB ---- -----

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Additional Functions

4.21 Additional Functions

Operational Mea-sured Values

Operating Measured Values for Currents in A or kA primary; in A secondary,– Ia, Ib, Ic or in % of INom

- Range 10% to 200% INom- Tolerance*) 1% of measure value or 0.5 % of INom

– IG and 3I0 in A or kA primary; in A secondary andor in % of INom

– Positive sequence current I1 in A or kA primary; in A secondary,or in % of INom

– Negative sequence current I2 in A or kA primary; in A secondary andor in % of INom

Operating Measured Values in kV primary; in V secondaryfor Voltages (phase-ground) or in % of VNom– Va, Vb, Vc

- Range 10% to 120% VNom- Tolerance*) 1% of measured value or 0.5 % of VNom

Operating Measured Values in kV primary; in V secondaryfor Voltages (phase-phase) or in % of VNom– Va-b, Vb-c, Vc-a, Vsyn

- Range 10% to 120% VNom- Tolerance*) 1% of measured value or 0.5 % of VNom

– VGND and V0 in kV primary; in V secondaryor in % of VNom

– Positive sequence voltage V1 in kV primary; in V– Negative sequence voltage V2 secondary or in % of VNom

Operating Measured Valuesfor Power in kVA (MVA or GVA) primary, and in– S, Apparent Power % SNom

- Range 0% to 120% SNom- Tolerance*) ≤ 2% SNom

for V/VNom and I/INom = 50% to 120%with SNom = √3 · VNom

· INom

– P, Real power (with sign, in kW (MW or GW) primary, andtotal and phase-segregated) in % SNom- Range 0% to 120% SNom- Tolerance*) ≤ 3% SNom

for V/VNom and I/INom = 50% to 120%and |cos ϕ| = 0.707 to 1with SNom = √3 · VNom

· INom

– Q, Reactive power (with sign, in kVAr (MVAr or GVAr) primary andtotal and phase-segregated) in % SNom

*) at f = fN

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Technical Data

- Range 0% to 120% SNom- Tolerance*) ≤ 3% SNom

for V/VNom and I/INom = 50% to 120%and |sin ϕ| = 0.707 to 1with SNom = √3 · VNom

· INom

Operating Measured Valuesfor Power Factor total and phase-segregated)– cos ϕ

- Range -1 to 1- Tolerance*) 5% for |cos ϕ| ≥ 0.707

Operating Measured Valuesfor Frequency– f in Hz (displayed with primary values)

- Range fN ± 5 Hz- Tolerance*) 20 mHz

Thermal Overload Protection Θ/Θ Trip

- Range 0% to 400%- Tolerance*) 5% class accuracy per IEC 60255-8

Motor Restart Blocking ΘL/ΘL Trip

- Range 0% to 400%- Tolerance*) 5% class accuracy per IEC 60255-8

Temperature limit ΘRESTART/ΘL aus in %

Time until release of reclose blockingTreclose in min

Operating Measured Values for INs, INsa, INsr (total, active, andSensitive Ground Fault Protection reactive current)

in A or kA primary and in mA secondary- Range 0 mA to 1600 mA- Tolerance*) 2% of measure value or 1 mA

Operating Measured Values forthe Measurement Transducer (7SJ63 only)

- Operating Range 0 mA to 24 mA- Accuracy Range 1 mA to 20 mA- Tolerance 1.5% relative to nominal value of 20 mA

For Standard Usage of the Measurement Transducer for Pressure and TemperatureMonitoring:Operating Measured Value Pressure in hPafor Pressure

- Operating Range (pre-set) 0 hPa to 1200 hPa

Operating Measured Value Temperature in ºCfor Temperature

- Operating Range (pre-set) 0º C to 240º C

Measured values of the synchronizingfunction (7SJ64) see Section 4.18

Measured values of the RTD-Box see Section 4.19 (RTD-Boxes)

*) at f = fN

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Additional Functions

Long-Term MeanValue

Time Window 5, 15, 30 or 60 minutes

Frequency of Updates adjustable

Long-Term Means of– Currents Ia dmd, Ib dmd, Ic dmd, I1 dmd in A (kA)– Real Power Pdmd in W (kW, MW)– Reactive Power Qdmd in VAr, (kVAr, MVAr)– Apparent Power Sdmd in VA, (kVA, MVA)

Min/Max Report Report of Measured Values with date and time

Reset – Automatic Time of day adjustable (in minutes, 0 to1439 min).Time frame and starting timeadjustable (in days, 1 to 365 days, and ∞).

Reset – Manual Using binary inputUsing keypadUsing communication

Min/Max Values for Current Ia, Ib, Ic, I1 (positive sequence)

Min/Max Values for Voltages Va-n, Vb-n, Vc-n, V1 (positive sequence)Va-b, Vb-c, Vc-a, Vn

Min/Max Values forThermal Overload Protection Θ/ΘTrip

Min/Max Values for Power/ Other S, P, Q, cos ϕ, Frequency

Min/Max Values for Averages IAdmd, IBdmd, ICdmd, I1dmd(positive sequence)

(LOG of Primary Values) Sdmd, Pdmd, Qdmd

Measured ValuesSupervision

Current Asymmetry Imax/Imin > I - balance factor, for I > I - bal-ance limit. Factor and limit are adjustable.

Voltage Asymmetry Vmax/Vmin > V - balance factor,for V > V -balance limit. Factor and limit areadjustable.

Current Sum | ia+ib+ic+[kn · in] | > I - sum

threshold value, adjustable.kn = CTn ratio / CTphase ratio

Current Phase Sequence Clockwise (ABC)/ counter-clockwise (ACB)

Voltage Phase Sequence Clockwise (ABC)/ counter-clockwise (ACB)

Limit Value Monitor Ia > Limit value IA dmd>Ib > Limit value IB dmd>Ic > Limit value IC dmd>I1 > Limit value I1 dmd>IL < Limit value 37-1cos ϕ < Lower limit value |cos ϕ|<P > Limit value |Pdmd|>Q > Limit value |Qdmd|>S > Limit value Sdmd>

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Technical Data

Pressure < Lower limit value Press<Temperature > Limit value Temp>

Trip Log Recording of indication of the last 8 power system faultsRecording of indication of the last 3 power system ground faults

Time Stamping Resolution for Event Log 1 ms(Operational Messages)

Resolution for Trip Log (Fault Records) 1 ms

Time Deviation (Internal Clock) Maximum 0.01%

Buffer Battery Lithium Battery, 3 V / 1 Ah, type CR 1/2 AASelf-discharging time > 5 yearsMessage “Fail Battery” ifbattery charge is low

Waveform Capture Maximum 8 fault records savedMemory maintained by bufferbattery in case of loss of power supply

Recording Time Total of 5 sPre-event and post-event recordingand memory time adjustable

Sampling Rate for 50 Hz 1 sample/1.25 ms (16 sam/cyc)Sampling Rate for 60 Hz 1 sample/1.04 ms (16 sam/cyc)

Energy Counter Values for Energy Wp, Wq (real and reactive energy)in kWh (MWh or GWh) and in kVARh(MVARh or GVARh)

- Range 28 bit or 0 to 268435455 decimal forIEC 60870-5-103 (VDEW protocol)31 bit or 0 to 2147483647 decimal forother protocols (other than VDEW)

- Tolerance*) 5% for I > 0.5 INom, V> 0.5 VNom and|cos ϕ| ≥ 0.707

Statistics (CircuitBreaker)

Saved Number of Trips Up to 9 digits

Number of closing commandsof the automatic reclosing function Up to 9 decimal places separated

according to 1st and ≥ 2nd cycle

Accumulated Interrupted Current Up to 4 digits (kA) per pole

Operating HoursCounter

Operating Hours Range Up to 7 digitsCriterion to Count Current exceeds an adjustable current

threshold (BkrClosed I MIN)

Trip Circuit Monitor(74TC)

With one or two binary inputs.

CommissioningStart-up Aids

Phase Rotation Field CheckOperating Measured ValuesCircuit Breaker / Switching Device TestCreation of a Test Measurement Report

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Breaker Control

Clock Time Synchronization IRIG-B/DCF77-signalBinary signalCommunication

Operating Modes for Time Tracking

Setting GroupSwitchover of the-Function Parame-ters

Number of Available Setting Groups 4 (parameter group A, B, C and D)

Switchover Performed Using the keypadDIGSI® 4 using the front PC portwith protocol via system (SCADA) interfaceusing binary input

4.22 Breaker Control

Number of Controlled Switching Depends on the number of binary DevicesDevice (e.g. Circuit Breakers) inputs and outputs available

Interlocking Freely programmable interlocking

Messages (Feedback) Feedback messages; closed, open,intermediate position

Control Commands Single command, double command

Operating Command to 1, 1 plus 1 common, or 2 contactsSwitching Device

Programmable Logic Controller PLC logic, graphic input tool

Local Control Control via menu control, assignment offunction keys

Remote Control Using communication interfacesSCADADIGSI® 4 (e.g. via modem)

# Operating Mode Explanations

1 Internal Internal synchronization using RTC (pre-set)

2 IEC 608705103 External synchronization using SCADA interface(IEC 60870–5–103)

3 PROFIBUS FMS External synchronization using PROFIBUS interface

4 IRIG B Time signal External synchronization using IRIG B

5 DCF77 Time signal External synchronization using DCF 77

6 SIMEAS Time signal Sync. Box

External synchronization using SIMEAS Sync. Box

7 Pulse via binary input External synchronization with pulse via binary input

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Technical Data

4.23 Dimensions

Housing for PanelFlush Mounting orCubicle Installation(Size 1/3 x 19”)

Figure 4-11 Dimensions 7SJ62 or 7SJ64 for panel flush mounting or cubicle installation (size 1/3 x 19”)

7SJ64

2

29.5

34

Mounting plate

Side View (with screwed terminals)

244

(9.6

1)

266

(10.

47)

2

29.5 34

Mounting plate

29 30

Side View (with plug-in terminals)

Dimensions in mm

(1.16)

172 (6.77)

(1.34)

(0.08)

(1.16)

(1.18)(1.14)172 (6.77)

266

(10.

47)

244

(9.6

1)

(0.08)

(1.34)

Values in brackets in inches

146 + 2 (5.75 + 0.07)

255.

0.3

(10.

07±

0.01

)

245

+1

(9.6

4+

0.03

)

5 (0.19)

6 (0.24)

Panel Cut-Out

150 (5.91)145 (5.71)

or M4

105 ± 0.5 (4.13 ± 0.01)

131.5 ± 0.3 (5.17 ± 0.01)7.3 (0.28)

13.2 (0.51)

5.4 (0.21)

R

Q

F

D

B A

C

Rear View

7SJ62

150 (5.91)145 (5.71)

R

Q

F

C

B A

Rear View

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Dimensions

Housing for PanelFlush Mounting orCubicle Installation(Size 1/2 x 19”)

Figure 4-12 Dimensions 7SJ63 or 7SJ64 for panel flush mounting or cubicle installation (size 1/2 x 19”)

221 +2 (8.70 +0.08 )

5 (0.20) or M4

6 (0.24)

Panel cut-out

255.

0.3

(10.

07+

0.01

)

206.5 ± 0.3 (8.13 ± 0.01 )13.2

7.3

5.4

2

29.5

34

Mounting plate

Side view (with screwed terminals)

244

(9.6

1)

266

(10.

47)

2

29.5 34

Mounting plate

29 30

Side view (with plug-in terminals)

Dimensions in mm

(1.16)

172 (6.77)

(1.34)

(0.08)

(1.16)

(1.18)(1.14)172 (6.77)

266

(10.

47)

244

(9.6

1)

(0.08)

(1.34)

Values in brackets in inches245

+1

(9.6

4+

0.04

)

180 ± 0.5 (7.09 ± 0.02 )

(0.29)

(0.52)

(0.2

1)

225 (8.86)220 (8.66)

7SJ64Rear view

KR

Q J

F

D

B A

C

225 (8.86)220 (8.66)

7SJ63Rear view

KR

Q J

F

C

B A

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Technical Data

Housing for PanelFlush Mounting orCubicle Installation(Size 1/1 x 19”)

Figure 4-13 Dimensions 7SJ63 or 7SJ64 for panel flush mounting or cubicle installation (size 1/1 x 19”)

panel cut -out

255.

0.3

(10.

07±

0.01

)

216.1 ± 0.3 (8.51 ± 0.01)13.2

425.5 ± 0.3 (16.75 ± 0.01)

6 (0.24) 5 (0.20)

(view from the device front)

Dimensions in mm

Values in brackets in inches

Side view (with screwed terminals)

244

(9.6

1)

266

(10.

47)

2

29.5 34

Mounting plate(1.16)

172 (6.77)

(1.34)

(0.08)

2

29.5

34

Mounting plate

29 30

Side view (with plug-in terminals)

(1.16)

(1.18)(1.14)172 (6.77)

266

(10.

47)

244

(9.6

1)

(0.08)

(1.34)

446 +2 (17.56 +0.08)

245

+1

(9.6

4+

0.03

) or M4

6 (0.24) 6 (0.24)5 (0.20)or M4

5 (0.20)or M4

6 (0.24)5 (0.20)or M4

13.2

7.3(0.29)

(0.52)

(0.2

1)5.

4

(0.52)

13.2(0.52)450 (17.72)

445 (17.52)

KR

Q J

F

C

B A

L

M

450 (17.72)445 (17.52)

KR

Q J

F

D

B A

P

N

C

Rear view7SJ64

Rear view7SJ63

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Dimensions

Housing for PanelSurface Mounting(Size 1/3 x 19”)

Figure 4-14 Dimensions 7SJ62 or 7SJ63 for panel surface mounting (size 1/3 x 19”)

Housing for PanelSurface Mounting(Size 1/2 x 19”)

Figure 4-15 Dimensions 7SJ63 or 7SJ64 for panel surface mounting (size 1/2 x 19”)

280

(11.

02)

165 (6.50)144 (5.76)

150 (5.91)

320

(12.

60)

344

(13.

54)

260 (10.24)

29.5 (1.16)

71 (2.80)72(2.83)

25

266

(10.

47)

Front view Side view

31 45

6046

1 15

16 30

Dimensions in mmValues in brackets in inches

10.5 (0.41)

52 (2.05)9

(0.35)

(0.98)

280

(11.

02)

240 (9.45)219 (8.62)

225 (8.86)

320

(12.

60)

344

(13.

54)

10.5 260 (10.24)

29.5

7172 52

25

266

(10.

47)

Front view Side view

91 25

26 50

51 75

76 100

Dimensions in mm

Values in brackets in inches

(0.35)

(0.41)

(1.16)

(2.80)(2.83) 2.05)

(0.9

8)

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Technical Data

Housing for PanelSurface Mounting(Size 1/1)

Figure 4-16 Dimensions 7SJ63 or 7SJ64 for panel surface mounting (size 1/1 x 19”)

280

(11.

02)

465 (18.31)444 (17.48)

450 (17.72)

320

(12.

60)

344

(13.

54)

10.5

Front view

1 50

51 100

200

101

151

150

Dimensions in mm

Values in brackets in inches

260 (10.24)

29.5

7172 52

25

266

(10.

47)

Side view

(1.16)

(2.80)(2.83) 2.05)

(0.9

8)

9(0.35)

(0.41)

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Dimensions

Housing forMounting withDetachedOperator Panel(Size 1/2 x 19”)

Figure 4-17 Dimensions 7SJ63 or 7SJ64 for mounting with detached operator panel (size 1/2 x 19”)

244

(9.6

1)

266

(10.

47)

209.5 (8.25)Mounting plate 225 (8.86)

220 (8.66)

Side view (with screw terminals)

12.5 (0.49)

4.5 (0.18)

312.

8(1

2.31

)

Mounting Holes of

300

±0.

3(1

1.81

±0.

01)

200 ± 0.3 (7.87 ± 0.11)

34 (1.34)

Dimensions in mm

244

(9.6

1)

266

(10.

47)

209.5 (8.25) 29Mounting plate

Side view (with plug-in terminals)

30

312.

8(1

2.31

)34

Values in brackets in inches

Mounting Plate

(1.14) (1.18)

(1.34)

100 ± 0.3 (3.93 ± 0.11)

6.4 (0.25)

KR

Q J

F

D

B A

C

Rear view7SJ64

225 (8.86)220 (8.66)

KR

Q J

F

C

B A

Rear view7SJ63

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Technical Data

Housing for Mount-ing with DetachedOperator Panel(Size 1/1 x 19”)

Figure 4-18 Dimensions 7SJ63 or 7SJ64 for mounting with detached operator panel (size 1/1 x 19”)

7SJ64 Rear View

25

4.5 (0.18)

Mounting Holes of Mounting Plate

300

±0.

3(1

1.81

±0.

01)

200 ± 0.3 (7.87 ± 0.01)

300 ± 0.3 (11.81 ± 0.01)

400 ± 0.3 (15.75 ± 0.01)

244

(9.6

1)

266

(10.

47)

209.5 ( 8.25)Mounting Plate

Side View (with Screw Terminals)

312.

8(1

2.31

)34 (1.34)

Dimensions in mm

244

(9.6

1)

266

(10.

47)

209.5 (8.25) 29Mounting Plate

Side View (with Screw Terminals)

30

312.

8(1

2.31

)

34 (1.34)

Values in brackets in inches

(1.14) (1.18)

6.4 (0.25)100 ± 0.3 (3.94 ± 0.01)

445 (17.52)

KR

Q J

F

D

B A

P

N

C

KR

Q J

F

B A

C

L

M

450 (17.72)

7SJ63 Rear View

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Dimensions

DetachedOperator Panel

Figure 4-19 Dimensions of a detached operator panel for a 7SJ63 or a 7SJ64 device

246.

2(9

.69)

266

(10.

47)

2 (0.08)

29.5 27 Mounting Plate

225 (8.86)220 (8.66)

Side View Rear View

Panel Cut-Out

68-pin Connection Cableto DeviceLength 2.2 m (0.09)

221 + 2 (8.70 + 0.08)

5 (0.20)

6 (0.24)

255.

0.3

(10.

07±

0.01

)

180 ± 0.5 (7.07 ± 0.02)

206.5 ± 0.3 (8.13 ± 0.01)

247.

2+

1(9

.73

+0.

04)

(1.16) (1.06)

or M4

4.3 (0.17)

13.2 (0.52)

7.3 (0.29)

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Technical Data

D-SubminiatureConnector of theDongle Cable(Panel or CubicleDoor Cutout)

Figure 4-20 Dimensioned drawing for the panel cutout or cubicle door cutout of the D-sub-miniature connector of the dongle cable for 7SJ63 or 7SJ64 without integratedoperator panel

Dimensions in mm

34±

1

40±

0,2

20 ± 1 4,5 oder M4

Panel cutout or cubicle door cutout

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Appendix AThis appendix is primarily a reference for the experienced user. This section providesordering information for the models of 7SJ62/63/64. General diagrams indicating theterminal connections of the 7SJ62/63/64 models are included. Following the generaldiagrams are diagrams that show the proper connections of the devices to primaryequipment in many typical power system configurations. Tables with all settings andall information available in a 7SJ62/63/64 equipped with all options are provided. De-fault settings are also given.

A.1 Ordering Information and Accessories 410

A.2 Elementary Diagrams 426

A.3 Connection Examples 470

A.4 Default Settings 494

A.5 Interoperability List 503

A.6 Protocol-dependent functions 505

A.7 Functions Overview 506

A.8 Settings 508

A.9 Overview of the masking features of the user defined information 541

A.10 Information List 545

A.11 Measured Values 582

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A Appendix 7SJ62

A.1 Ordering Information and Accessories

A.1.1 Ordering Information 7SJ62 V4.4 (present release .../EE and higher)

Number of Binary Inputs and Outputs8 Binary Inputs, 8 Binary Outputs, 1 Live Status Contact 111 Binary Inputs, 6 Binary Outputs, 1 Live Status Contact 2

Measuring Inputs (3 x V, 4 x I)Iph = 1 A, Ie = 1 A (min. = 0.05 A); 15th position only with: C, E, G 1Iph = 1 A, Ie = sensitive (min. = 0.001 A); 15th position only with: B, D, F, H 2Iph = 5 A, Ie = 5 A (min. = 0.25 A); 15th position only with: C, E, G 5Iph = 5 A, Ie = sensitive (min. = 0.001 A); 15th position only with: B, D, F, H 6Iph = 5 A, Ie = 1 A (min. = 0.05 A); 15th position only with: C, E, G 7

Power Supply, Binary Input Pickup Threshold Setting24 to 48 VDC, Binary Input Threshold 19 VDC 260 to 125 VDC, Binary Input Threshold 19 VDC 4110 to 250 VDC, 115/230 VAC, Binary Input Threshold 88 VDC 5

ConstructionSurface-mounting case for panel, 2 tier terminals top/ bottom BFlush-mounting case for panel/ cubicle, plug-in terminals (2/3 pin connector) DFlush-mounting case for panel/ cubicle, screw-type terminals (direct connection/ ring lugs) E

Region-specific Default/ Language Settings and Function VersionsRegion DE, 50 Hz, IEC, Language German (Language can be changed) ARegion World, 50/60 Hz, IEC/ANSI, Language English (Language can be changed) BRegion US, 60 Hz, ANSI, Language American English (Language can be changed) CRegion FR, 50/60 Hz, IEC/ANSI, Language French (Language can be changed) DRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language can be changed) E

System interfaces (Port B)No system interface 0IEC Protocol, RS232 1IEC Protocol, RS485 2IEC Protocol, Optical 820 nm, ST-Connector 3Profibus FMS Slave, RS485 4Profibus FMS Slave, Optical, Single Ring, ST-Connector) 51)

Profibus FMS Slave, Optical, Double Ring, ST-Connector) 61)

For further interface options see Additional Information L 9

see Page 411

Additional Information L +

System Interfaces (Device Rear)Profibus DP Slave, RS485 0 AProfibus DP Slave, 820 nm, Optical Double Ring, ST–Connector1) 0 B1)

Modbus RS485) 0 DModbus, 820 nm, Optical, ST–Connector2) 0 E2)

DNP3.0, RS485 0 GDNP3.0, 820 nm, Optical, ST–Connector2) 0 H2)

1) not available if “B“ is in position 9; if the optical interface is required, see the comment on page 422.2) not available if “B“ is in position 9.

(

L

_7SJ626 7 8 13 15 1614

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A.1 Ordering Information and Accessories7SJ62

DIGSI 4/Modem Interface (Device Rear, Port C)No rear DIGSI 4 Interface 0DIGSI 4/Modem, RS232 1DIGSI 4/Modem/RTD-Box 3), RS485 2DIGSI 4/Modem/RTD-Box 3), Optical 820 nm, ST-Connector 3

Measuring/Fault recordingwith Fault recording 1with Fault recording, with Average values, with Min/Max values 3

FunctionsDesignation ANSI no. Description

Basic Elements: Control(included in all versions) 50/51 Time-overcurrent protection phase

50-1, 50-2, 5150N/51N Time-overcurrent protection ground

50N-1, 50N-2, 51N50N/51N Time-overcurrent protection ground via insensitive IEE-function:

50N-1, 50N-2, 51 N5)49 Overload protection (with 2 time constants)46 Negative sequence protection 46-1, 46-2, 46-TOC50BF Circuit breaker failure protection74TC Trip circuit monitoring

Cold-load pickup (Dynamic setting changes)50c-1, 50c-2, 50Nc-1, 50Nc-2, 51NcInrush blocking

86 Lock out

V/f 27/59 Under/Overvoltage 59-1,59-2, 27-1, 27-2 F E81O/U Under/Over frequency

Dir 67/67N Directional overcurrent protection for phase and ground F C47 Phase Sequence Voltage

Dir V/f 67/67N Directional overcurrent protection for phase and ground F G47 Phase Sequence Voltage27/59 Under/Overvoltage 59-1, 59-2, 27-1, 27-281O/U Under/Over frequency

Dir IEF 67/67N Directional overcurrent protection for phase and ground P C47 Phase Sequence Voltage

Intermittent earth fault

Dir.earth-f. Dir IEF 67/67N Directional overcurrent protection for phase and ground F D4)det. 47 Phase Sequence Voltage

67Ns Directional sensitive ground fault protection4)64 Displacement voltage

Dir.earth-f. Dir 67/67N Directional overcurrent protection for phase and ground P D4)det. 47 Phase Sequence Voltage

67Ns Directional sensitive ground fault direction recording4)64 Displacement voltage

Intermittent earth fault

Dir.earth-f. 67Ns Directional sensitive ground fault protection4) F B4)det. 64 Displacement voltage

Dir.earth-f. Motor V/f 67Ns Directional sensitive ground fault protection4) H F4)det. 64 Displacement voltage

37 Undercurrent monitoring48 Motor starting time supervision66/86 Motor start inhibit (66/68)27/59 Under/Overvoltage 59-1, 59-2, 27-1, 27-281O/U Under/Over frequency

Dir.earth-f. Motor V/f 67/67N Directional overcurrent protection for phase and ground H H4)det. 47 Phase Sequence Voltage

67Ns Directional sensitive ground fault protection4)64 Displacement voltage37 Undercurrent monitoring48 Motor starting time supervision66/86 Motor start inhibit (66/68)27/59 Under/Overvoltage 59-1, 59-2, 27-1, 27-281O/U Under/Over frequency

see Page 412

Dir = Directional overcurrent protectionV/f = Voltage-/frequency protectionIEF = Intermittent earth fault protection

3) RTD-Box 7XV5662–*AD10 (see also the comment on page 422 and Section A.1.6, Accessories)4) for isolated/compensated networks, only for sensitive ground current transformer if 7th digit = 2, 6.5) only for non-sensitive ground current transformer if 7th digit = 1, 5, 7.

_6 7 8 13 15 1614

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SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ62

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A Appendix 7SJ62

Automatic Reclosing (79), Fault LocatorNo 79, no Fault Locator 0With 79 1With Fault Locator 2With 79 and Fault Locator 3

with ATEX 100 approval (for the protection of explosion-protected motorsof the protection type increased safety “e”) 9 9

Dir = Directional overcurrent protectionV/f = Voltage-/frequency protectionIEF = Intermittent earth fault protection

Notes:4) for isolated/compensated networks, only for sensitive ground current transformer if 7th digit = 2, 6.5) only for non-sensitive ground current transformer if 7th digit = 1, 5, 7.

SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ62 _6 7 8 13 15 1614

_9 10 11 12

_

Functionscontinued from page 411

Designation ANSI no. Description

Basic Elements: Control(included in all versions) 50/51 Time-overcurrent protection phase

50-1, 50-2, 5150N/51N Time-overcurrent protection ground

50N-1, 50N-2, 51N50N/51N Time-overcurrent protection ground via insensitive IEE-function:

50N-1, 50N-2, 51 N5)49 Overload protection (with 2 time constants)46 Negative sequence protection 46-1, 46-2, 46-TOC50BF Circuit breaker failure protection74TC Trip circuit monitoring

Cold-load pickup (Dynamic setting changes:50c-1, 50c-2, 50Nc-1, 50Nc-2, 51NcInrush blocking

86 Lock out

Dir.earth-f. Motor Dir IEF V/f 67/67N Direction determination for overcurrent, phase and ground R H4)det. 47 Phase sequence

67Ns Directional sensitive ground fault detection4)37 Undercurrent monitoring64 Displacement voltage48 Motor starting time supervision66/86 Motor start inhibit27/59 Under-/overvoltage81O/U Under-/overfrequency

Intermittent earth fault

Motor Dir V/f 67/67N Direction determination for overcurrent, phase and ground H G47 Phase sequence37 Undercurrent monitoring48 Motor starting time supervision66/86 Motor start inhibit27/59 Under-/overvoltage81O/U Under-/overfrequency

+ XZ

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A.1 Ordering Information and Accessories7SJ62

A.1.2 Ordering Information 7SJ62 V4.2 (releases to date until .../DD)

Number of Binary Inputs and Outputs8 Binary Inputs, 8 Binary Outputs, 1 Live Status Contact 111 Binary Inputs, 6 Binary Outputs, 1 Live Status Contact 2

Nominal CurrentIN = 1 A 1IN = 5 A 5

Power Supply, Binary Input Pickup Threshold Setting24 to 48 VDC, Binary Input Threshold 19 VDC 260 to 125 VDC, Binary Input Threshold 19 VDC 4110 to 250 VDC, 115 VAC, Binary Input Threshold 88 VDC 5220 to 250 VDC, 230 VAC, Binary Input Threshold 88 VDC 6

ConstructionSurface-mounting case for panel, 2 tier terminals top/ bottom BFlush-mounting case for panel/ cubicle, plug-in terminals (2/3 pin connector) DFlush-mounting case for panel/ cubicle, screw-type terminals (direct connection/ ring lugs) E

Region-specific Default/ Language Settings and Function VersionsRegion DE, 50 Hz, IEC, Language German (Language can be changed) ARegion World, 50/60 Hz, IEC/ANSI, Language English (Language can be changed) BRegion US, 60 Hz, ANSI, Language American English (Language can be changed) CRegion FR, 50/60Hz, IEC/ANSI, Language French (Language can be changed) DRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language can be changed) ERegion DE, 50 Hz, IEC, Language German (Language cannot be changed) MRegion World, 50/60 Hz, IEC/ANSI, Language English (Language cannot be changed) NRegion US, 60 Hz, ANSI, Language American English (Language cannot be changed) PRegion FR, 50/60 Hz, IEC/ANSI, Language French (Language cannot be changed) QRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language canot be changed) R

System interfaces (Rear ports)No system interface 0IEC Protocol, RS232 1IEC Protocol, RS485 2IEC Protocol, Optical 820 nm, ST-Connector 3Profibus FMS Slave, RS485 4Profibus FMS Slave, Optical, Single Ring, ST-Connector1)) 51)

Profibus FMS Slave, Optical, Double Ring, ST-Connector1) 61)

For further interface options see Additional Information L 9

DIGSI 4/Modem Interface (Rear Ports)No rear DIGSI 4 Interface 0DIGSI 4, RS232 1DIGSI 4, RS485 2DIGSI 4, Optical 820 nm, ST-Connector 3

See Page 414

Additional Information L +

System Interfaces (Device Rear)Profibus DP Slave, RS485 0 AProfibus DP Slave, 820 nm, Optical Double Ring, ST–Connector1) 0 B1)

Modbus RS485) 0 DModbus, 820 nm, Optical, ST–Connector2) 0 E2)

DNP3.0, RS485 0 GDNP3.0, 820 nm, Optical, ST–Connector2) 0 H2)

1) not available if “B“ is in position 9; if the optical interface is required, see the comment on page 4222) not available if “B“ is in position 9.

L

_7SJ626 7 8 13 15 1614

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SIPROTEC 4 Multifunction Protection with Controls Order No.

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A Appendix 7SJ62

DIGSI 4/Modem Interface (Device Rear)No rear DIGSI 4 Interface 0DIGSI 4, RS232 1DIGSI 4, RS485 2DIGSI 4, Optical 820 nm, ST-Connector 3

Measuring/Fault recordingwith Fault recording 1with Fault recording, with Average values, with Min/Max values 3

FunctionsBasic Elements: Controls(included in all versions) Time-overcurrent protection phase 50-1, 50-2, 51 and

Time-overcurrent protection ground 50N-1, 50N-2, 51NOverload protection (with 2 time constants) 49Negative sequence protection 46-1, 46-2, 46-TOCCircuit breaker failure protectionTrip circuit monitoringInrush stabilizationDynamic setting changesLock out 86

Basic Elements Plus: Under/Overvoltage 59-1, 27-1, 27-2 F EUnder/Over frequency 81

Basic Elements Plus: Directional overcurrent protection for phase and ground F C67-1, 67-2, 67-TOC, 67-N-1, 67N-2, 67N-TOC

Basic Elements Plus: Directional overcurrent protection for phase and ground F G67-1, 67-2, 67-TOC, 67-N-1, 67N-2, 67N-TOCUnder/Overvoltage 59-1, 27-1, 27-2Under/Over frequency 81

Basic Elements Plus: Directional overcurrent protection for phase and ground F D*)

67-1, 67-2, 67-TOC, 67-N-1, 67N-2, 67N-TOCGround fault direction recordingDisplacement voltage

Basic Elements Plus: Sensitive ground fault protection 64, 50Ns, 67Ns-1, 67Ns-2 F B*)

Ground fault direction recordingDisplacement voltage

Basic Elements Plus: Ground fault direction recording H F*)

Displacement voltageUndercurrent monitoringMotor starting time supervisionMotor start inhibit (66/68)Under/Overvoltage 59-1, 27-1, 27-2Under/Over frequency 81

Basic Elements Plus: Directional overcurrent protection for phase and ground H H*)

67-1, 67-2, 67-TOC, 67-N-1, 67N-2, 67N-TOCGround fault direction recordingDisplacement voltageUndercurrent monitoringMotor starting time supervisionMotor start inhibit (66/68)Under/Overvoltage 59-1, 27-1, 27-2Under/Over frequency 81

Basic Elements Plus: Directional overcurrent protection for phase and ground H G67-1, 67-2, 67-TOC, 67-N-1, 67N-2, 67N-TOCUndercurrent monitoringMotor starting time supervisionMotor start inhibit (66/68)Under/Overvoltage 59-1, 27-1, 27-2Under/Over frequency 81

Automatic Reclosing (79), Fault LocatorNo 79, no Fault Locator 0With 79 1With Fault Locator 2With 79 and Fault Locator 3

*) Device is equipped with sensitive current transformer input in ground circuit

_6 7 8 13 15 1614

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SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ62

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A.1 Ordering Information and Accessories7SJ63

A.1.3 Ordering Information 7SJ63 V4.4 (present release .../EE and higher)

Housing, Number of Binary Inputs and Outputs, Measuring Transducer InputsHousing 1/2 19”, 11 BI, 8 BO, 1 Live Status Contact 1Housing 1/2 19”, 24 BI, 11 BO, 2 High-duty relays (4 Contacts), 1 Live Status Contact 2Housing 1/2 19”, 20 BI, 11 BO, 2 MT, 2 High-duty relays (4 Contacts) 1 Live Status Contact 3Housing 1/1 19”, 37 BI, 14 BO, 4 High-duty relays (8 Contacts), 1 Live Status Contact 5Housing 1/1 19”, 33 BI, 14 BO, 2 MT, 4 High-duty relays (8 Contacts), 1 Live Status Contact 6

Measuring Inputs (3 x U, 4 x I)Iph = 1 A, Ie = 1 A (min. = 0.05 A); 15th position only with: A, C, E, G 1Iph = 1 A, Ie = sensitive (min. = 0.001 A); 15th position only with: B, D, F, H 2Iph = 5 A, Ie = 5 A (min. = 0.25 A); 15th position only with: A, C, E, G 5Iph = 5 A, Ie = sensitive (min. = 0.001 A); 15th position only with: B, D, F, H 6Iph = 5 A, Ie = 1 A (min. = 0.05 A); 15th position only with: A, C, E, G 7

Power Supply, Binary Input Pickup Threshold Setting24 to 48 VDC, Binary Input Threshold 19 VDC 260 to 125 VDC, Binary Input Threshold 19 VDC 4110 to 250 VDC, 115/230 VAC, Binary Input Threshold 88 VDC 5

ConstructionSurface-mounting case, plug-in terminals, detached operator panel AInstallation in a low-voltage compartmentSurface-mounting case for panel, 2 tier terminals top/bottom BSurface-mounting case, screw-type terminals (ring lugs), detached operator panel CInstallation in a low-voltage compartmentFlush-mounting case for panel/cubicle, plug-in terminals (2/3 pin connector) DFlush-mounting case for panel/cubicle, screw-type terminals (ring lugs) ESurface-mounting case, screw-type terminals (ring lugs), without operator panel FInstallation in a low-voltage compartmentSurface-mounting case, plug-in terminals, without operator panel GInstallation in a low-voltage compartment

Region-specific Default/ Language Settings and Function VersionsRegion DE, 50 Hz, IEC, Language German (Language can be changed) ARegion World, 50/60 Hz, IEC/ANSI, Language English (Language can be changed) BRegion US, 60 Hz, ANSI, Language American English (Language can be changed) CRegion FR, 50/60 Hz, IEC/ANSI, Language French (Language can be changed) DRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language can be changed) E

System Interface - Rear Port BNo system interface 0IEC-Protocol, RS232 1IEC-Protocol, RS485 2IEC-Protocol, Optical, 820 nm, ST-Connector 3Profibus FMS Slave, RS485 4Profibus FMS Slave, Optical, Single Ring, ST-Connector1) 51)

Profibus FMS Slave, Optical, Double Ring, ST-Connector 1) 61)

For further interface options see Additional Information L 9

siehe Seite 416

Additional Information L +

System Interfaces (Device Rear)Profibus DP Slave, RS485 0 AProfibus DP Slave, 820 nm, Optical Double Ring, ST–Connector1) 0 B1)

Modbus RS485) 0 DModbus, 820 nm, Optical, ST–Connector2) 0 E2)

DNP3.0, RS485 0 GDNP3.0, 820 nm, Optical, ST–Connector2) 0 H2))

1) not for “B“ at position 9; if the optical interface is required, see the comment on page 422.2) not for “B“ at position 9.

L

SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ63 _6 7 8 13 15 1614

_9 10 11 12

11

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A Appendix 7SJ63

DIGSI 4/Modem Interface (Device rear, Port C)No DIGSI 4 Interface at the back 0DIGSI 4, Modem, Electrical RS232 1DIGSI 4, Modem, RTD-Box3), Electrical RS458 2DIGSI 4, Modem, RTD-Box3), Optical 820 nm, ST-Connector 3

Measuring/Fault recordingSlave pointer, Average values, Min/Max values, Fault recording 3

FunctionsDesignation ANSI no. Description

Basic Elements ControlsIncluded in all versions 50/51 Time-overcurrent protection phase 50-1, 50-2, 51 F A

50N/51N Time-overcurrent protection ground 50N-1, 50N-2, 51N50N/51N Time-overcurrent protection ground via insensitive IEE-function:

50N-1, 50N-2, 51 N5)49 Overload protection (with 2 time constants) 4946 Negative sequence protection 46-1, 46-2, 46-TOC50BF Circuit breaker failure protection74TC Trip circuit monitoring

Cold-load pickup (Dynamic setting changes)50c-1, 50c-2, 50Nc-1, 50Nc-2, 51NcInrush stabilization

86 Lock out

V/f 27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-2 F E81O/U Over/Under frequency

Dir 67/67N Directional overcurrent time protection for phase and ground F C47 Phase sequence

Dir V/f 67/67N Directional overcurrent time protection for phase and ground F G47 Phase sequence27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency

Dir IEF 67/67N Directional overcurrent time protection for phase and ground P C47 Phase sequence

Intermittent earth fault

Dir.earth.-f. Dir 67/67N Directional overcurrent time protection for phase and ground F D4)det. 67Ns Directional sensitive ground fault detection4)

64 Displacement Voltage

Dir.earth.-f. Dir IEF 67/67N Directional overcurrent time protection for phase and ground P D4)det. 47 Phase sequence

67Ns Directional sensitive ground fault detection4)64 Displacement Voltage

Intermittent earth fault

Dir.earth.-f. 67Ns Directional sensitive ground fault detection4) F B4)det. 64 Displacement Voltage

Dir.earth.-f. Motor V/f 67Ns Directional sensitive ground fault detection4) H F4)det. 64 Displacement Voltage

37 Undercurrent monitoring48 Motor starting time supervision66/86 Motor start inhibit27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency

Dir.earth.-f. Motor V/f 67/67N Directional overcurrent time protection for phase and ground H H4)det. 47 Phase sequence

67Ns Directional sensitive ground fault detection4)64 Displacement Voltage37 Undercurrent monitoring

Motor 48 Motor starting time supervision66/86 Motor start inhibit27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency

see page 417

Dir = Directional overcurrent protectionV/f = Voltage-/frequency protectionIEF = Intermittent earth fault protection

3) RTD-Box 7XV5662–*AD10 (see also comment on page 422 and Section A.1.6 Accessories).4) for isolated/compensated networks, only for sensitive ground current transformer if 7th digit = 2, 6.5) only for non-sensitive ground current transformer if 7th digit = 1, 5, 7.

IPROTEC 4 Multifunction Protection with Controls Order No. 7SJ63 _6 7 8 13 15 1614

_9 10 11 12

416 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.1 Ordering Information and Accessories7SJ63

Functionscontinued from page 416Designation ANSI no. Description

Basic Elements ControlsIncluded in all versions 50/51 Time-overcurrent protection phase 50-1, 50-2, 51

50N/51N Time-overcurrent protection ground 50N-1, 50N-2, 51N50N/51N Time-overcurrent protection ground via insensitive IEE-function:

50N-1, 50N-2, 51 N5)49 Overload protection (with 2 time constants) 4946 Negative sequence protection 46-1, 46-2, 46-TOC50BF Circuit breaker failure protection74TC Trip circuit monitoring

Cold-load pickup (Dynamic setting changes):50c-1, 50c-2, 50Nc-1, 50Nc-2, 51NcInrush stabilization

86 Lock out

Dir.earth-f. Dir 67/67N Directional overcurrent time protection for phase and ground R H4)det. 67Ns Directional sensitive ground fault detection4)

64 Displacement VoltageMotor 48 Motor starting time supervision

66/86 Motor start inhibit27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency

Intermittent earth fault

Automatic Reclosing (79), Fault LocatorNo 79, no Fault Locator 0With 79 1Fault Locator 1) 2With 79 and Fault Locator 1) 3

with ATEX 100 approval (for the protection of explosion-protected motorsof the protection type increased safety “e”) 9 9

Dir = Directional overcurrent protectionV/f = Voltage-/frequency protectionIEF = Intermittent earth fault protection

Notes:4) for isolated/compensated networks, only for sensitive ground current transformer if the 7th digit = 2, 6.5) only for non-sensitive ground current transformer if the 7th digit = 1, 5, 7.

SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ63 _6 7 8 13 15 1614

_9 10 11 12

_

+ XZ

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A Appendix 7SJ63

A.1.4 Ordering Information 7SJ63 V4.2 (releases to date until .../DD)

Housing, Number of Binary Inputs and Outputs, Measuring Transducer InputsHousing 1/2 19”, 11 BI, 8 BO, 1 Live Status Contact 1Housing 1/2 19”, 24 BI, 11 BO, 2 High-duty relays (4 Contacts), 1 Live Status Contact 2Housing 1/2 19”, 20 BI, 11 BO, 2 MT, 2 High-duty relays (4 Contacts) 1 Live Status Contact 3Housing 1/1 19”, 37 BI, 14 BO, 4 High-duty relays (8 Contacts), 1 Live Status Contact 5Housing 1/1 19”, 33 BI, 14 BO, 2 MT, 4 High-duty relays (8 Contacts), 1 Live Status Contact 6

Nominal CurrentIN = 1 A 1IN = 5 A 5

Power Supply, Binary Input Pickup Threshold Setting24 to 48 VDC, Binary Input Threshold 19 VDC 260 to 125 VDC, Binary Input Threshold 19 VDC 4110 to 250 VDC, 115 VAC, Binary Input Threshold 88 VDC 5

ConstructionSurface-mounting case, plug-in terminals, detached operator panel AInstallation in a low-voltage compartmentSurface-mounting case for panel, 2 tier terminals top/bottom BSurface-mounting case, screw-type terminals (ring lugs), detached operator panel CInstallation in a low-voltage compartmentFlush-mounting case for panel/cubicle, plug-in terminals (2/3 pin connector) DFlush-mounting case for panel/cubicle, screw-type terminals (ring lugs) E

Region-Specific Default/Language Settings and Function VersionsRegion DE, 50 Hz, IEC, Language German (Language can be changed) ARegion World, 50/60 Hz, IEC/ANSI, Language English (Language can be changed) BRegion US, 60 Hz, ANSI, Language Americal English (Language can be changed) CRegion FR, 50/60 Hz, IEC/ANSI, Language French (Language can be changed) DRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language can be changed ERegion DE, 50 Hz, IEC, Language German (Language cannot be changed) MRegion World, 50/60 Hz, IEC/ANSI, Language English (Language cannot be changed) NRegion US, 60 Hz, ANSI, Language Americal English (Language cannot be changed) PRegion FR, 50/60 Hz, IEC/ANSI, Language French (Language cannot be changed) QRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language cannot be changed) R

System Interface - Rear PortsNo system interface 0IEC-Protocol, RS232 1IEC-Protocol, RS485 2IEC-Protocol, Optical, 820 nm, ST-Connector 3Profibus FMS Slave, RS485 4Profibus FMS Slave, Optical, Single Ring, ST-Connector1) 51)

Profibus FMS Slave, Optical, Double Ring, ST-Connector 1) 61)

For further interface options see Additional Information L 9

See page 419

Additional Information L +

System Interfaces (device rear)Profibus DP Slave, RS485 0 AProfibus DP Slave, 820 nm, Optical Double Ring, ST–Connector1) 0 B1)

Modbus RS485) 0 DModbus, 820 nm, Optical, ST–Connector2) 0 E2)

DNP3.0, RS485 0 GDNP3.0, 820 nm, Optical, ST–Connector2) 0 H2)

1) not for “B“ at position 9; if the optical interface is required, see the comment on page 4222) cannot be delivered in connection with 9th digit “B“.

L

_7SJ636 7 8 13 15 1614

_9 10 11 12

SIPROTEC 4 Multifunction Protection with Controls Order No.

11

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A.1 Ordering Information and Accessories7SJ63

DIGSI 4/Modem Interface (Device rear)No DIGSI 4 Interface at the back 0DIGSI 4, Electrical RS232 1DIGSI 4, Electrical RS458 2DIGSI 4, Optical 820 nm, ST-Connector 3

Measuring/Fault recordingSlave pointer, Average values, Min/Max values, Fault recording 3

FunctionsDesignation ANSI no. Description

Basic Elements ControlsIncluded in all versions 50/51 Time-overcurrent protection phase 50-1, 50-2, 51 and F A

50N/51N Time-overcurrent protection ground 50N-1, 50N-2, 51N,49 Overload protection (with 2 time constants),46 Negative sequence protection 46-1, 46-2, 46-TOC,50BF Circuit breaker failure protection,74 Trip circuit monitoring

Inrush stabilizationCold-load pickup (Dynamic setting changes) 50c-1, 50c-2, 50Nc-1, 50Nc-2, 51Nc

86 Lockout37 Undercurrent monitoring47 Phase Sequence Voltage

V/f Over/Undervoltage 59-1, 27-1, 27-2 F EOver/Under frequency 81

Dir 67/67N Directional overcurrent time protection for phase and ground F C67-1,67-2,67-TOC, 67N-1, 67N-2, 67N-TOC

Dir V/f 67/67N Directional overcurrent time protection for phase and ground F G67-1,67-2,67-TOC, 67N-1, 67N-2, 67N-TOCOver/Under frequency 81Over/Undervoltage 59-1, 27-1, 27-2

Dir.earth-f. Dir 67/67N Directional overcurrent time protection for phase and ground F D*)

det. 67-1,67-2,67-TOC, 67N-1, 67N-2, 67N-TOC64 Displacement Voltage67Ns Directional sensitive ground fault protection 64, 50Ns, 67Ns-1, 67Ns-2

Dir.earth-f. 67Ns Directional sensitive ground fault protection 64, 50Ns, 67Ns-1, 67Ns-2 F B*)

det. 64 Displacement Voltage

Dir.earth-f. Motor V/f 67Ns Directional sensitive ground fault protection 64, 50Ns, 67Ns-1, 67Ns-2 H F*)

det. 64 Displacement Voltage48 Motor starting time supervision66/86 Motor start inhibit27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency

Dir.earth-f. Motor Dir V/f 67/67N Directional overcurrent time protection for phase and ground H H*)

det. 67-1,67-2,67-TOC, 67N-1, 67N-2, 67N-TOC64 Displacement Voltage48 Motor starting time supervision66/86 Motor start inhibit27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency67Ns Directional sensitive ground fault protection 64, 50Ns, 67Ns-1, 67Ns-2

Motor Dir V/f 67/67N Directional overcurrent time protection for phase and ground H G67-1,67-2,67-TOC, 67N-1, 67N-2, 67N-TOC

48 Motor starting time supervision66/86 Motor start inhibit27/59 Over/Undervoltage 59-1, 59-2, 27-1, 27-281O/U Over/Under frequency

Motor 48 Motor starting time supervision H A66/86 Motor start inhibit

Automatic Reclosing (79), Fault LocatorNo 79, no Fault Locator 0With 79 1Fault Locator 2With 79 and Fault Locator 3

*) Device is equipped with sensitive current transformer input in ground circuit.

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SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ63

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A Appendix 7SJ64

A.1.5 Ordering Information 7SJ64 V4.4

SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ64

Housing, Number of Binary Inputs and OutputsHousing 1/3 19”, 7 BI, 5 BO, 1 Live Status Contact; 9th position only with: B, D, E 0Housing 1/2 19”, 15 BI, 13 BO, 1 Lifekontakt 1Housing 1/2 19”, 20 BI, 8 BO, 2 High-duty relays (4 Contacts), 1 Live Status Contact 2Housing 1/1 19”, 33 BI, 11BO, 4 High-duty relays (8 Contacts), 1 Live Status Contact 5

Measuring Inputs (4 x U, 4 x I)Iph = 1 A, Ie = 1 A (min. = 0.05 A); 15th position only with: A, C, E, G 1Iph = 1 A, Ie = sensitive (min. = 0,001 A); 15th position only with: B, D, F, H 2Iph = 5 A, Ie = 5 A (min. = 0,25 A); 15th position only with: A, C, E, G 5Iph = 5 A, Ie = sensitive (min. = 0,001 A); 15th position only with: B, D, F, H 6Iph = 5 A, Ie = 1 A (min. = 0,05 A); 15th position only with: A, C, E, G 7

Power Supply, Binary Input Pickup Threshold Setting24 to 48 VDC, Binary Input Threshold 19 V DC 260 to 125 VDC, Binary Input Threshold 19 V DC 4110 to 250 VDC, 115 VAC, Binary Input Threshold 88 V DC 5

ConstructionSurface-mounting case, plug-in terminals, detached operator panel AInstallation in a low-voltage compartmentSurface-mounting case for panel, 2 tier terminals top/bottom BSurface-mounting case, screw-type terminals (ring lugs), detached operator panel CInstallation in a low-voltage compartmentFlush-mounting case for panel/cubicle, plug-in terminals (2/3 pin connector) DFlush-mounting case for panel/cubicle, screw-type terminals (ring lugs) ESurface-mounting case, screw-type terminals (ring lugs), without operator panel FInstallation in a low-voltage compartmentSurface-mounting case, plug-in terminals, without operator panel GInstallation in a low-voltage compartment

Region-specific Default/ Language Settings and Function VersionsRegion DE, 50 Hz, IEC, Language German (Language can be changed) ARegion World, 50/60 Hz, IEC/ANSI, Language English (Language can be changed) BRegion US, 60 Hz, ANSI, Language American English (Language can be changed) CRegion FR, 50/60 Hz, IEC/ANSI, Language French (Language can be changed) DRegion World, 50/60 Hz, IEC/ANSI, Language Spanish (Language can be changed) E

System Interface - Rear Port BNo system interface 0IEC-Protocol, RS232 1IEC-Protocol, RS485 2IEC-Protocol, Optical, 820 nm, ST-Connector 3Profibus FMS Slave, RS485 4Profibus FMS Slave, Optical, Single Ring, ST-Connector 1) 51)

Profibus FMS Slave, Optical, Double Ring, ST-Connector 1) 61)

For further interface options see Additional Information L 9

see Page 421 bis 422

Additional Information LProfibus DP Slave, RS485 AProfibus DP Slave, 820 nm, Optical Double Ring, ST–Connector1) B1)

Modbus RS485) DModbus, 820 nm, Optical, ST–Connector2) E2)

DNP3.0, RS485 GDNP3.0, 820 nm, Optical, ST–Connector2) H2)

1) cannot be delivered in connection with 9th digit “B“; if the optical interface is required, see the comment on page 4222) cannot be delivered in connection with 9th digit “B“

_6 7 8 13 15 1614

_9 10 11 12

_

+ L 011

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A.1 Ordering Information and Accessories7SJ64

SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ64

DIGSI 4/Modem Interface (Port C)DIGSI 4/Modem, electrical RS232 1DIGSI 4/Modem, RTD-Box3), electrical RS485 2For further interface options see Additional Information M 9

Additional Information M (Port C and Port D)Port C: not installed 0Port C: DIGSI 4/Modem, electrical RS232 1Port C: DIGSI 4/Modem, RTD-Box3), electrical RS485 2Port D: RTD-Box3), Optical 820 nm, ST–Connector APort D: RTD-Box3), electrical RS485 F

Measuring/Fault recordingSlave pointer, Average values, Min/Max values, Fault recording 3

FunctionsDesignation ANSI no. Description

Basic Elements: Control F A(included in all versions) 50/51 Time-overcurrent protection phase

50-1, 50-2, 5150N/51N Time-overcurrent protection ground

50N-1, 50N-2, 51N50N/51N Time-overcurrent protection ground via insensitive IEE-function:

50N-1, 50N-2, 51 N5)49 Overload protection (with 2 time constants)46 Negative sequence protection 46-1, 46-2, 46-TOC50BF Circuit breaker failure protection74TC Trip circuit monitoring

Cold-load pickup (Dynamic setting changes:50c-1, 50c-2, 50Nc-1, 50Nc-2, 51NcInrush blocking

86 Lock out

V/f 27/59 Under/Overvoltage 59-1,59-2, 27-1, 27-2 F E81O/U Under/Over frequency

Dir 67/67N Directional overcurrent protection for phase and ground F C47 Phase Sequence Voltage

Dir V/f 67/67N Directional overcurrent protection for phase and ground F G47 Phase Sequence Voltage27/59 Under/Overvoltage 59-1, 59-2, 27-1, 27-281O/U Under/Over frequency

Dir IEF 67/67N Directional overcurrent protection for phase and ground P C47 Phase Sequence Voltage

Intermittent earth fault

Dir.earth-f. Dir 67/67N Directional overcurrent protection for phase and ground F D4)det. 47 Phase Sequence Voltage

67Ns Directional sensitive ground fault protection4)64 Displacement voltage

Dir.earth-f. Dir IEF 67/67N Directional overcurrent protection for phase and ground P D4)det. 47 Phase Sequence Voltage

67Ns Directional sensitive ground fault direction recording4)64 Displacement voltage

Intermittent earth fault

Dir.earth-f. 67Ns Directional sensitive ground fault protection4) F B4)det. 64 Displacement voltage

Dir.earth-f. Motor V/f 67Ns Directional sensitive ground fault protection4) H F4)det. 64 Displacement voltage

37 Undercurrent monitoring48 Motor starting time supervision66/86 Motor start inhibit27/59 Under/Overvoltage 59-1, 59-2, 27-1, 27-281O/U Under/Over frequency

see page 422

Dir = Directional overcurrent protectionV/f = Voltage-/frequency protectionIEF = Intermittent earth fault protection

3) RTD-Box 7XV5662–*AD10 (see also comment on page 422 and Section A.1.6 Accessories).4) for isolated/compensated networks, only for sensitive ground current transformer if 7th digit = 2, 6.5) only for non-sensitive ground current transformer if 7th digit = 1, 5, 7.

+ M

_6 7 8 13 15 1614

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A Appendix 7SJ64

SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ64

Functionscontinued from page 421

Designation ANSI no.Description

Basic Elements: Control(included in all versions) 50/51Time-overcurrent protection phase

50-1, 50-2, 5150N/51NTime-overcurrent protection ground

50N-1, 50N-2, 51N50N/51NTime-overcurrent protection ground via insensitive IEE-function:

50N-1, 50N-2, 51N5)49 Overload protection (with 2 time constants)46 Negative sequence protection 46-1, 46-2, 46-TOC50BF Circuit breaker failure protection74TC Trip circuit monitoring

Cold-load pickup (Dynamic setting changes:50c-1, 50c-2, 50Nc-1, 50Nc-2, 51NcInrush blocking

86 Lock out

Dir.earth-f. Dir Motor V/f 67/67N Directional overcurrent protection for phase and ground H H4)det. 47 Phase Sequence Voltage

67Ns Directional sensitive ground fault protection4)64 Displacement voltage37 Undercurrent monitoring48 Motor starting time supervision66/86 Motor start inhibit (66/68)27/59 Under/Overvoltage 59-1, 59-2, 27-1, 27-281O/U Under/Over frequency

Dir.earth-f. Motor Dir IEF V/f 67/67N Direction determination for overcurrent, phase and ground R H4)det. 47 Phase sequence

67Ns Directional sensitive ground fault detection4)37 Undercurrent monitoring64 Displacement voltage48 Motor starting time supervision66/86 Motor start inhibit27/59 Under-/overvoltage81O/U Under-/overfrequency

Intermittent earth fault

Automatic Reclosing (79), Fault Locator, SynchronizationWithout 0With 79 1With Fault Locator 2With 79 and Fault Locator 3With Synchronization 4With Synchronization, 79 and Fault Locator 7

Notes:4) for isolated/compensated networks, only for sensitive ground current transformer if 7th digit = 2, 6.5) only for non-sensitive ground current transformer if 7th digit = 1, 5, 7.

Comment (applies for all device versions 7SJ62/63/64)1) if the optical interface is required you must order the following: 11th digit = 4 (RS485)

and in addition:

for single ring: SIEMENS OLM 6GK1502–3AB10for double ring: SIEMENS OLM 6GK1502–4AB10

The converter requires an operating voltage of 24 V DC. If the available operating voltage is> 24 V DC the additional power supply 7XV5810–0BA00 is required.

3) if you want to run the RTD-Box at an optical interface, you need also theRS485–FO–converter 7XV5650–0*A00 (see Accessories at A.1.6).

_6 7 8 13 15 1614

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A.1 Ordering Information and Accessories

A.1.6 Accessories

InterfaceModules

Exchange interface modules

RTD-Box For up to 6 temperature measuring points (at most 2 devices can be connected to7SJ62/63/64)

RS485/Fibre OpticConverter

Terminal BlockCovering Caps

Short Circuit Links

Name Order No.

RS232 C53207–A351–D641–1

RS485 C53207–A351–D642–1

Optical 820 nm C53207–A351–D643–1

Profibus FMS RS485 C53207–A351–D603–1

Profibus FMS double ring C53207–A351–D606–1

Profibus FMS single ring C53207–A351–D609–1

Profibus DP RS485 C53207–A351–D611–1

Profibus DP double ring C53207–A351–D613–1

Modbus RS485 C53207–A351–D621–1

Modbus 820 nm C53207–A351–D623–1

DNP 3.0 RS485 C53207–A351–D631–1

DNP 3.0 820 nm C53207–A351–D633–1

Name Order No.

RTD-Box, UN = 24 to 60 V AC/DC 7XV5662–2AD10–0000

RTD-Box, UN = 90 to 240 V AC/DC 7XV5662–5AD10–0000

RS485/Fibre Optic Converter Order No.

820 nm; FC–Connector 7XV5650–0AA00–

820 nm; ST–Connector 7XV5650–0BA00–

Covering cap for terminal block type Order No.

18-terminal voltage, 12-terminal current block C73334-A1-C31-1

12-terminal voltage, 8-terminal current block C73334-A1-C32-1

Short circuit links for terminal type Order No.

Voltage terminal, 18-terminal, or 12-terminal C73334-A1-C34-1

Current terminal,12-terminal, or 8-terminal C73334-A1-C33-1

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A Appendix

Female Plugs

Mounting Rail for19"-Racks

Battery

Interface Cable An interface cable is necessary for communication between the SIPROTEC deviceand a PC. Requirements for the computer are Windows 95 or Windows NT4 and theoperating software DIGSI® 4.

Operating SoftwareDIGSI® 4

Software for setting and operating SIPROTEC® 4 devices

Graphical AnalysisProgram SIGRA

Software for graphical visualization, analysis, and evaluation of fault data. Optionpackage of the complete version of DIGSI® 4

Display Editor Software for creating basic and power system control pictures. Option packageof the complete version of DIGSI® 4

Connector Type Order No.

2-pin C73334-A1-C35-1

3-pin C73334-A1-C36-1

Name Order No.

Angle Strip (Mounting Rail) C73165-A63-C200-3

Lithium-Battery 3 V/1 Ah, Type CR 1/2 AA Order No

VARTA 6127 101 501

Interface cable between PC or SIPROTEC device Order No.

Cable with 9-pin male/female connections 7XV5100-4

Operating Software DIGSI® 4 Order No.

DIGSI® 4, basic version with license for 10computers

7XS5400-0AA00

DIGSI® 4, complete version with all option packages 7XS5402-0AA0

Graphical analysis program SIGRA® Order No.

Full version with license for 10 PCs 7XS5410-0AA0

Display Editor 4 Order No.

Full version with license for 10 PCs 7XS5420-0AA0

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A.1 Ordering Information and Accessories

Graphic Tools Graphical Software to aid in the setting of characteristic curves and provide zone dia-grams for overcurrent and distance protective devices. Option package of the com-plete version of DIGSI® 4.

DIGSI REMOTE 4 Software for remotely operating protective devices via a modem (and possibly a starconnector) using DIGSI® 4. (Option package of the complete version of DIGSI® 4.

SIMATIC CFC 4 Graphical software for configuration of control interlocking conditions or creating addi-tional logic functions in SIPROTEC 4 devices. Option package for the complete ver-sion of DIGSI® 4.

Graphic Tools 4 Order No.

Full version with license for 10 PCs 7XS5430-0AA0

DIGSI REMOTE 4 Order No.

Full version with license for 10 PCs 7XS5440-2AA0

SIMATIC CFC 4 Order No.

Full version with license for 10 PCs 7XS5450-0AA0

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A Appendix 7SJ62

A.2 Elementary Diagrams

A.2.1 Elementary Diagrams for 7SJ62

A.2.1.1 Housing for panel flush mounting or cubicle installation

7SJ621∗ −∗ D/E

Figure A-1 Connection Diagram For 7SJ621∗ –∗ D/E (Panel Flush Mounted or Cubicle Mounted)

IaQ1Q2

IbQ3Q4

IcQ5Q6

I4Q7Q8

VaR14

R16

R15

Vc/VGR17R18

F14

F15

F16

R9

R10

R8

R7

R12

R13

R11

Vb

F6F7

F8F9F10F11F12F13

R1R2

R3

F3F4F5

F1F2

( )~+

Live Status

Power

Rear SCADAPort

Rear ServicePort

B

C

A

Ground at Back

Supply

Wall of Housing

R4R6R5

Front PC Port

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

Contact

BI1

BI2

F17F18

BI3

BI4

BI5

BI8

BI6

BI7

BO1

BO2

BO3

BO4

BO5BO6

BO7BO8

TimeSynchronization

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

beginning withrelease .../EE

F6F7

BO1

Jumper: 1–2 NO2–3 NC

F8F9

BO2

426 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.2 Elementary Diagrams7SJ62

7SJ622∗ −∗ D/E

Figure A-2 Connection Diagram For 7SJ622∗ –∗ D/E (Panel Flush Mounted or Cubicle Mounted)

Rear SCADAPort

Rear ServicePort

Front PC Port

TimeSynchronization

Q1Q2Q3Q4Q5Q6Q7Q8

R14

R16

R15

R17R18

F14

F15

F16

R9

R10

R11

R12

R8

R7

R13

R2

R6

F6F7

F8F9F10F11F12F13

R1R3

R4R5

F3F4F5

F1F2

( )~+

Live Status

Power

B

C

A

Ground at Back

Supply

Wall of Housing

Contact

Ia

Ib

Ic

I4

Va

Vc/VG

Vb

BI1

BI2

F17F18

BI3

BI4

BI5

BI11

BI10

BI6

BI7

BI9

BI8

BO1

BO2

BO3

BO4

BO5

BO7

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

beginning withrelease .../EE

F6F7

BO1

Jumper: 1–2 NO2–3 NC

F8F9

BO2

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A Appendix 7SJ62

A.2.1.2 Panel Surface Mounting

7SJ621∗ −∗ B

Figure A-3 Connection Diagram For 7SJ621∗ –∗ B (Panel Surface Mounted)

The connections for additional serial interfaces are taken from Figures A-5 or A-6.

1530142913281227

45

60

44

4359

58

42

57

40

55

3954

53

37

38

4156

2625

92435503449

334832

523651

10 L+ (V+)11 L– (V–)

( )~+

Live Status

Power

Ground at Side

Supply

Wall of Housing

314647

Front PC Port

Contact

Ia

Ib

Ic

I4

Va

Vc/VG

Vb

BI1

BI2

BI3

BI4

BI5

BI8

BI6

BI7

BO1

BO2

BO3

BO4

BO5BO6

BO7BO8

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

beginning withrelease .../EE

F6F7

BO1

Jumper: 1–2 NO2–3 NC

F8F9

BO2

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A.2 Elementary Diagrams7SJ62

7SJ622∗ −∗ B

Figure A-4 Connection Diagram For 7SJ622∗ –∗ B (Panel Surface Mounted)

The connections for additional serial interfaces are taken from Figures A-5 or A-6.

1530142913281227

456044

4359

58

42

57

40

55

39

5438

52

36

53

37

4156

2625

92434493348

3247

3146

513550

10 L+ (V+)11 L– (V–)

( )~+

Live Status

Power

Ground at Side

Supply

Wall of Housing

Front PC Port

Contact

Ia

Ib

Ic

I4

Va

Vc/VG

Vb

BI1

BI2

BI3

BI4

BI5

BI11

BI10

BI6

BI7

BI9

BI8

BO1

BO2

BO3

BO4

BO5

BO7

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

beginning withrelease .../EE

F6F7

BO1

Jumper: 1–2 NO2–3 NC

F8F9

BO2

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A Appendix 7SJ62

7SJ62∗∗ −∗ B(up to developmentstate ... /CC)

Figure A-5 Connection Diagram For 7SJ62∗∗ –∗ B up to release ... /CC (Panel Surface Mounted)

Time

Rear ServicePort

172183

1

1920212223

Optical

Electricalor

Channel C

Synchronization

CTS

RS232 RS485

RTS

GNDTxDRxD

B–GNDA–

IN 12 VCOMMONIN 5 VIN 24 VShield

Rear SCADAPort

Channel B

45678

Optical

Electricalor

CTS

RS232 RS485

RTS

GNDTxDRxD

B–GNDA–

Profibus

430 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.2 Elementary Diagrams7SJ62

7SJ621/2∗ −∗ B(beginning withrelease.../DD)

Figure A-6 Connection Diagram For 7SJ621/2∗ –∗ B beginning with release .. /DD(Panel Surface Mounted)

Time

172183

1

Synchronization

IN 12 VCOMMONIN 5 VIN 24 VShield

RearService Port

Rear SCADAPort Channel B

elektrical RS232/RS485

Channel C

elektrical RS232/RS485

Optical

Electricalor

Optical

Electricalor

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

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A Appendix 7SJ63

A.2.2 Elementary Diagrams for 7SJ63

A.2.2.1 Housing for panel flush mounting or cubicle installation

7SJ631∗ –∗ D/E

Figure A-7 General diagram 7SJ631∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADA

Time

Rear Service

B

C

A

Ground at Back

supply

Wall of Housing

Front PC Port

F1

F2( )~

+

-

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

R9R10

R12R13

R11

BI21BI22

BI24BI23

F9F7

BO3

F6F8

BO1

F5BO2

R1R2BO11

R3BO12

R4BO13

R5R6R7R8

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Port

Ass

ignm

ento

fPin

sof

Inte

r-fa

ces,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

Port

1) Jumper: 1–2 NO2–3 NC

432 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.2 Elementary Diagrams7SJ63

7SJ632∗ –∗ D/E

Figure A-8 General diagram 7SJ632∗ –∗ D/E (panel flush mounting or cubicle installation)

B

C

A

F1

F2( )~

+

-

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

Power

Rear SCADAPort

Time

Rear Service

Ground at Back

supply

Wall of Housing

Front PC Port

Synchronization

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

R9R10

R12R13

R11

BI20

BI21BI22

BI24BI23

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2BO11

R3BO12

R4BO13

R5R6R7R8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Port/RTD-Box

Ass

ignm

ento

fPin

sof

Inte

r-fa

ces,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

1) Jumper: 1–2 NO2–3 NC

4337SJ62/63/64 ManualC53000-G1140-C147–1

Page 448: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ633∗ –∗ D/E

Figure A-9 General diagram 7SJ633∗ –∗ D/E (panel flush mounting or cubicle installation)

B

C

A

F1

F2( )~

+

-

R9R10R11R12

Power

Rear SCADAPort

Time

Rear Service

Ground at Back

supply

Wall of Housing

Front PC Port

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Transducer 1

Transducer 2

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

BI20

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Port

Ass

ignm

ento

fPin

sof

Inte

r-fa

ces,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

(+)(–)(+)(–)

1) Jumper: 1–2 NO2–3 NC

434 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 449: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ635∗ –∗ D/E

Figure A-10 General diagram 7SJ635∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADAPort

Time

Rear Service

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

R9R10

R12R13

R11

M1M2

M4M6M7M8

M3

M9M5

M10M11

M13M14

M12

M15M16

BI20

BI21BI22

BI24BI23

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2BO11

R3BO12

R4BO13

R5R6R7R8

L11L12

L7L9L8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

Live status F3F4contact

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

L1 (–)L2 (+)L3

L4

M18

M17

BO20BO21

BO22

Jumper1) (NO, NC)

*)

Port

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

1) Jumper: 1–2 NO2–3 NC

4357SJ62/63/64 ManualC53000-G1140-C147–1

Page 450: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ636∗ –∗ D/E

Figure A-11 General diagram 7SJ636∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADA

Time

Rear ServicePort

B

C

A

Ground at Back

supply

Wall of Housing

Front PC Port

F1

F2( )~

+

-

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

BI20

R9R10R11R12

Transducer 1

Transducer 2

M2

M4M6M7M8

M3

M9M5

M10M11

M13M14

M12

M15M16

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

L11L12

L7L9L8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

Live status F3F4contact

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

L1 (–)L2 (+)L3

L4

M18

M17

BO20BO21

BO22

Jumper1) (NO, NC)

*)

M1

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

(+)(–)(+)(–)

Port

1) Jumper: 1–2 NO2–3 NC

436 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 451: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

A.2.2.2 Housing for panel surface mounting

7SJ631∗ –∗ B

Figure A-12 General diagram 7SJ631∗ –∗ B (panel surface mounting)

For connections of the further interfaces, see figures A-15 or A-16.

2550

2247

24492348

1944

21

2046

8359

5580

81825857

56

9671

7094

95

5352

767751

15 L+ (V+)

16 L– (V–)( )~

+

-

10075997498739772

5479

Power

Ground at Side

supply

Wall of Housing

Front PC Port

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

IA

I4

IB

IC

Vc/VG

Va

BI7

Vb

BI1BI2

BI4BI5BI6

BI3

BI21BI22

BI24BI23

BO3

BO1BO2

BO11BO12BO13

BO14

BO15

Live statuscontactJumper1) (NO, NC)

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

1) Jumper: 1–2 NO2–3 NC

4377SJ62/63/64 ManualC53000-G1140-C147–1

Page 452: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ632∗ –∗ B

Figure A-13 General diagram 7SJ632∗ –∗ B (panel surface mounting)

For connections of the further interfaces see figures or A-16 .

2550

2247

24492348

1944

21

2046

8359

5580

81825857

56

8460

61628763

85

8886

6489

9066

65

9167

9671

7094

95

5352

767751

15 L+ (V+)

16 L– (V–)( )~

+

-

1338

143940

10075997498739772

11 (–)36 (+)10

35

12

37

5479

Power

Ground at Side

supply

Wall of Housing

Front PC Port

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

IA

I4

IB

IC

Vc/VG

Va

BI7

Vb

BI1BI2

BI4BI5BI6

BI3

BI8BI9

BI11BI12BI13BI14

BI10

BI15

BI16BI17

BI19BI18

BI20

BI21BI22

BI24BI23

BO3

BO1BO2

BO11BO12BO13

BO4

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live statuscontactJumper1) (NO, NC)

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

1) Jumper: 1–2 NO2–3 NC

438 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 453: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ633∗ –∗ B

Figure A-14 General diagram 7SJ633∗ –∗ B (panel surface mounting)

For connections of the further interfaces see figures A-15 or A-16.

2550

2247

24492348

1944

21

2046

8359

5580

81825857

56

8460

61628763

85

8886

6489

9066

65

9167

5352

767751

15 L+ (V+)

16 L– (V–)( )~

+

-

1338

143940

10075997498739772

96719570

11 (–)36 (+)10

35

12

37

5479

Power

Ground at Side

supply

Wall of Housing

Front PC Port

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Transducer 1

Transducer 2

IA

I4

IB

IC

Vc/VG

Va

BI7

Vb

BI1BI2

BI4BI5BI6

BI3

BI8BI9

BI11BI12BI13BI14

BI10

BI15

BI16BI17

BI19BI18

BI20

BO3

BO1BO2

BO11BO12BO13

BO4

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live statuscontactJumper1) (NO, NC)

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1(+)

(–)(+)(–)

1) Jumper: 1–2 NO2–3 NC

4397SJ62/63/64 ManualC53000-G1140-C147–1

Page 454: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ631/2/3∗ –∗ B(up to release ... /DD)

Figure A-15 General diagram 7SJ631/2/3∗ –∗ B up to release .../DD (panel surface mounting)

Time

Rear ServicePort

272283

1

2930313233

Optical

Electricalor

Channel C

34

CTS

RS232 RS485

RTS

GNDTxDRxD

B–GNDA–

Shield

Synchronization

IN 12 VCOMMONIN 5 VIN 24 V

Shield

Rear SCADAPort

45678

Optical

Electricalor

9

Channel B

CTS

RS232 RS485

RTS

GNDTxDRxD

B–GNDA–

Shield

Profibus

440 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 455: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ631/2/3∗ −∗ B(beginning withrelease ... /EE)

Figure A-16 Connection Diagram For 7SJ631/2/3∗ –∗ B beginning with release /EE(Panel Surface Mounted)

Time

272283

1

Synchronization

IN 12 VCOMMONIN 5 VIN 24 VShield

RearService Port

Rear SCADAPort Channel B

elektrical RS232/RS485

Channel C

elektrical RS232/RS485

Optical

Electricalor

Optical

Electricalor

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

4417SJ62/63/64 ManualC53000-G1140-C147–1

Page 456: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ635∗ –∗ B

Figure A-17 General diagram 7SJ635∗ –∗ B (panel surface mounting)

For connections of the further interfaces see figures A-19 or A-20.

Power

Ground at Side

supply

Wall of Housing

Front PC Port

50100

4797

49994898

4494

46

4596

158109

105155

156157108107

106

169120

121122172123

170

173171

124174

175126

125

176127

196146

145194

195

103102

151152101

37 L+ (V+)

38 L– (V–)( )~

+

-

2272

237374

200150199149198148197147

177128

129130180131

178

181179132182

183134

133

184135

2979

318130

19 (–)69 (+)18

68

20

70

27 (–)77 (+)26

76

28

78

104154

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

IA

I4

IB

IC

Vc/VG

Va

BI7

Vb

BI1BI2

BI4BI5BI6

BI3

BI8BI9

BI11BI12BI13BI14

BI10

BI15

BI16BI17

BI19BI18

BI20

BI21BI22

BI24BI23

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

BO3

BO1BO2

BO11BO12BO13

BO4

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

BO20BO21

BO22

*)

Live statuscontactJumper1) (NO, NC)

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

1) Jumper: 1–2 NO2–3 NC

442 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 457: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ636∗ –∗ B

Figure A-18 General diagram 7SJ636∗ –∗ B (panel surface mounting)

For connections of the further interfaces see figures A-19 or A-20.

196146

195145

Power

Ground at Side

supply

Wall of Housing

Front PC Port

50100

4797

49994898

4494

464596

158109

105155

156157108107

106

169120

121122172123

170

173171

124174

175126

125

176127

103102

151152101

37 L+ (V+)

38 L– (V–)( )~

+

-

2272

237374

200150199149198148197147

177128

129130180131

178

181179132182

183134

133

184135

2979

318130

19 (–)69 (+)18

68

20

70

27 (–)77 (+)26

76

28

78

104154

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

IA

I4

IB

IC

Vc/VG

Va

BI7

Vb

BI1BI2

BI4BI5BI6

BI3

BI8BI9

BI11BI12BI13BI14

BI10

BI15

BI16BI17

BI19BI18

BI20

Transducer 1

Transducer 2

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

BO3

BO1BO2

BO11BO12BO13

BO4

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

BO20BO21

BO22

*)

Live statuscontactJumper1) (NO, NC)

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

(+)(–)(+)(–)

1) Jumper: 1–2 NO2–3 NC

4437SJ62/63/64 ManualC53000-G1140-C147–1

Page 458: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ635/6∗ –∗ B(up to release ... /DD)

Figure A-19 General diagram 7SJ635/6∗ –∗ B up to release .../DD (panel surface mounting)

Time

Rear ServicePort

522533

1

5455565758

Optical

Electricalor

Channel C

59

CTS

RS232 RS485

RTS

GNDTxDRxD

B–GNDA–

Shield

Synchronization

IN 12 VCOMMONIN 5 VIN 24 V

Shield

Rear SCADAPort

45678

Optical

Electricalor

9

Channel B

CTS

RS232 RS485

RTS

GNDTxDRxD

B–GNDA–

Shield

Profibus

444 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 459: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ635/6∗ −∗ B(beginning withrelease .../EE)

Figure A-20 Connection Diagram For 7SJ635/6∗ –∗ B beginning with release /EE(Panel Surface Mounted)

Time

522533

1

Synchronization

IN 12 VCOMMONIN 5 VIN 24 VShield

RearService Port

Rear SCADAPort Channel B

elektrical RS232/RS485

Channel C

elektrical RS232/RS485

Optical

Electricalor

Optical

Electricalor

Assignment of Pinsof Interface, refer toTable 3-35 in Sub-section 3.2.1

4457SJ62/63/64 ManualC53000-G1140-C147–1

Page 460: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

A.2.2.3 Devices With Detached Operation Unit

7SJ631∗ –∗ A/C

Figure A-21 General diagram 7SJ631∗ –∗ A/C (devices with separate operation unit)

Power

Rear SCADAPort

Time

Rear Servicei

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,Front PC Port Operation

unitGround at BackWall of Housing

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

R9R10

R12R13

R11

BI21BI22

BI24BI23

F9F7

BO3

F6F8

BO1

F5BO2

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Port

Syncronization Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

1) Jumper: 1–2 NO2–3 NC

446 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 461: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ632∗ –∗ A/C

Figure A-22 General diagram 7SJ632∗ –∗ A/C (devices with separate operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADA

Time

Rear ServicePort

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Front PC Port Operationunit

Ground at BackWall of Housing

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

R9R10

R12R13

R11

BI20

BI21BI22

BI24BI23

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

Port

1) Jumper: 1–2 NO2–3 NC

4477SJ62/63/64 ManualC53000-G1140-C147–1

Page 462: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ633∗ –∗ A/C

Figure A-23 General diagram 7SJ633∗ –∗ A/C (devices with separate operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADAPort

Time

Rear ServicePort

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Front PC Port Operationunit

Ground at BackWall of Housing

R9R10R11R12

Transducer 1

Transducer 2

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

BI20

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)A

ssig

nmen

tofP

ins

ofIn

terf

aces

,ref

erto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

(+)(–)(+)(–)

1) Jumper: 1–2 NO2–3 NC

448 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 463: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ635∗ –∗ A/C

Figure A-24 General diagram 7SJ635∗ –∗ A/C (devices with separate operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADA

Time

Rear Service

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Front PC Port Operationunit

Ground at BackWall of Housing

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

R9R10

R12R13

R11

M1M2

M4M6M7M8

M3

M9M5

M10M11

M13M14

M12

M15M16

BI20

BI21BI22

BI24BI23

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

L11L12

L7L9L8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

Live status F3F4contact

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

L1 (–)L2 (+)L3

L4

M18

M17

BO20BO21

BO22

Jumper1) (NO, NC)

*)

Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

Port

1) Jumper: 1–2 NO2–3 NC

4497SJ62/63/64 ManualC53000-G1140-C147–1

Page 464: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ636∗ –∗ A/C

Figure A-25 General diagram 7SJ636∗ –∗ A/C (devices with separate operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADA

Time

Rear Service

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

BI20

R9R10R11R12

Transducer 1

Transducer 2

M2

M4M6M7M8

M3

M9M5

M10M11

M13M14

M12

M15M16

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

M1

Front PC Port Operationunit

Ground at BackWall of Housing

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2BO11

R3BO12

R4BO13

R5R6R7R8

L11L12

L7L9L8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

Live status F3F4contact

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

L1 (–)L2 (+)L3

L4

M18

M17

BO20BO21

BO22

Jumper1) (NO, NC)

*)

Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

(+)(–)(+)(–)

Port

1) Jumper: 1–2 NO2–3 NC

450 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 465: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

A.2.2.4 Devices for panel surface mounting without Operation Unit

7SJ631∗ –∗ F/G

Figure A-26 General diagram 7SJ631∗ –∗ F/G (devices for panel surface mounting without operation unit)

Power

Rear SCADAPort

Time

Rear Servicei

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 Vrelay contacts,

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

R9R10

R12R13

R11

BI21BI22

BI24BI23

F9F7

BO3

F6F8

BO1

F5BO2

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Port

Syncronization Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

PC Port(to Panel or Door)

1) Jumper: 1–2 NO2–3 NC

4517SJ62/63/64 ManualC53000-G1140-C147–1

Page 466: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ632∗ –∗ F/G

Figure A-27 General diagram 7SJ632∗ –∗ F/G (devices for panel surface mounting without operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADA

Time

Rear ServicePort

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

R9R10

R12R13

R11

BI20

BI21BI22

BI24BI23

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)A

ssig

nmen

tofP

ins

ofIn

terf

aces

,ref

erto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

Port

PC Port(to Panel or Door)

1) Jumper: 1–2 NO2–3 NC

452 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 467: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ633∗ –∗ F/G

Figure A-28 General diagram 7SJ633∗ –∗ F/G (devices for panel surface mounting without operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADAPort

Time

Rear ServicePort

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

R9R10R11R12

Transducer 1

Transducer 2

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

BI20

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

*)

BO8BO9

BO10

BO14

BO15

Live status F3F4contact

Jumper1) (NO, NC)

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

(+)(–)(+)(–)

PC Port(to Panel or Door)

1) Jumper: 1–2 NO2–3 NC

4537SJ62/63/64 ManualC53000-G1140-C147–1

Page 468: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

7SJ635∗ –∗ F/G

Figure A-29 General diagram 7SJ635∗ –∗ F/G (devices for panel surface mounting without operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADA

Time

Rear Service

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

R9R10

R12R13

R11

M1M2

M4M6M7M8

M3

M9M5

M10M11

M13M14

M12

M15M16

BI20

BI21BI22

BI24BI23

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2

BO11

R3BO12

R4BO13

R5R6R7R8

L11L12

L7L9L8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

Live status F3F4contact

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

L1 (–)L2 (+)L3

L4

M18

M17

BO20BO21

BO22

Jumper1)(NO, NC)

*)

Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

Port

PC Port(to Panel or Door)

1) Jumper: 1–2 NO2–3 NC

454 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 469: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ63

7SJ636∗ –∗ F/G

Figure A-30 General diagram 7SJ636∗ –∗ F/G (devices for panel surface mounting without operation unit)

B

C

A

F1

F2( )~

+

-Power

Rear SCADA

Time

Rear Service

Ground at Back

supply

Wall of Housing

Synchronization

Interference suppressioncapacitors at the

Ceramic, 4.7 nF, 250 V

*)

relay contacts,

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R17R18

Vc/VG

R14

R16Va

R15

F17F18

BI7

Vb

F10F11

BI1

F13F15F16F14

F12BI2

BI4BI5BI6

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

BI20

R9R10R11R12

Transducer 1

Transducer 2

M2

M4M6M7M8

M3

M9M5

M10M11

M13M14

M12

M15M16

BI25BI26

BI28BI29BI30BI31

BI27

BI32

BI33BI34

BI36BI35

BI37

M1

F9F7

BO3

F6F8

BO1

F5BO2

J11J12

J7J9J8

R1R2BO11

R3BO12

R4BO13

R5R6R7R8

L11L12

L7L9L8

J1 (–)J2 (+)

BO4 J3

J4

K18

K17

BO5

BO6

BO7

Live status F3F4contact

*)

BO8BO9

BO10

BO14

BO15

BO16

BO17

BO18

BO19

L1 (–)L2 (+)L3

L4

M18

M17

BO20BO21

BO22

Jumper1) (NO, NC)

*)

Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ubse

ctio

n3.

2.1

(+)(–)(+)(–)

Port

PC Port(to Panel or Door)

1) Jumper: 1–2 NO2–3 NC

4557SJ62/63/64 ManualC53000-G1140-C147–1

Page 470: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

A.2.3 Elementary Diagrams for 7SJ64

A.2.3.1 Housing for panel flush mounting or cubicle installation

7SJ640∗ –∗ D/E

Figure A-31 General diagram 7SJ640∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADA Port

Rear Service Port

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Time Synchronization

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

R11R12

BI7

R5R6

BO4

R1R2

BO1

R3BO2

Live status F3F4contact

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

1) Jumper: 1–2 NO2–3 NC

456 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 471: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

7SJ641∗ –∗ D/E

Figure A-32 General diagram 7SJ641∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADA Port

Rear Service Port

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Time Synchronization

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

J3J4

BI10

J5J6

BI11BI12

K17K18

J11J12

B8

BI15

R5R6

BO4

R1R2

BO1

R3BO2

K3K4

K9K10

F3F4

BO6

BO10

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

R11R12

BI7

J9J10

BI14

J7J8

BI13

J1J2

BI9

K6K7

BO7

K8BO8

K5BO9

K11K12BO11

K13K14BO12

K15K16BO13

Live statuscontactJumper1) (NO, NC)

1) Jumper: 1–2 NO2–3 NC

4577SJ62/63/64 ManualC53000-G1140-C147–1

Page 472: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

7SJ642∗ –∗ D/E

Figure A-33 General diagram 7SJ642∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADA Port

Rear Service Port

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Time Synchronization

*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

R11R12

K15K16

BI7

BI20

R5R6

BO4

R1R2

BO1

R3BO2

J7J9J8

J11J12

J1 (–)J2 (+)

BO6 J3

J4

K18

K17

BO7

BO8

BO9

Live status F3F4contact

*)

B10B11

BO12

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

1) Jumper: 1–2 NO2–3 NC

458 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 473: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

7SJ645∗ –∗ D/E

Figure A-34 General diagram 7SJ645∗ –∗ D/E (panel flush mounting or cubicle installation)

Power

Rear SCADA Port

Rear Service Port

B

C

A

Ground at Back

supply

Wall of Housing

F1

F2( )~

+

-

Time Synchronization*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

P1P2

P4P6

P3

P7

P9

P10P11P12

P8

P13P14

P15P16

BI20

BI21BI22

BI24BI23

BI25BI26

BI28

BI29BI30BI31

BI27

BI32

BI33

R5R6

BO4

R1R2

BO1

R3BO2

J7J9J8

J11J12

N11N12

N7N9N8

J1 (–)J2 (+)

BO6 J3

J4

K18

K17

BO7

BO8

BO9

Live status F3F4contact

*)

B10B11

BO12

BO13

BO14

BO15

BO16

N1 (–)N2 (+)N3

N4

P18

P17

BO17BO18

BO19

Jumper1) (NO, NC)

*)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

P5

Additional Port D

R7R8

BO5

R4BO3

R11R12

BI7

1) Jumper: 1–2 NO2–3 NC

4597SJ62/63/64 ManualC53000-G1140-C147–1

Page 474: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

A.2.3.2 Housing for panel surface mounting

7SJ640∗ –∗ B

Figure A-35 General diagram 7SJ640∗ –∗ B (panel surface mounting)

Power

Rear SCADA Port

Rear Service Port

B

C

Ground at Back

supply

Wall of Housing

( )~+

-

IA

I4

IB

IC

Vc

Va

BI6

Vb

BI1BI2

BI4BI5

BI3

BI7

BO4

BO1BO2

Live statuscontactJumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,r

efer

toT

able

3-35

and

3-36

inS

ub-

sect

ion

3.2.

1

V4

Additional Port D

BO5

BO3

1530142913

2625

45446059

3736

343352

35

5338

1228

27

5439

31

43584257

5641

5540

32

10 L+ (V+)

11 L– (V–)

EarthingTerminal (16)

2173

19

184

1

TimeSynchronisation

IN 12 VIN SYNC

COM SYNCCOMMON

IN 24 VScreen

IN 5 V

1) Jumper: 1–2 NO2–3 NC

460 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 475: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

7SJ641∗ –∗ B

Figure A-36 General diagram 7SJ641∗ –∗ B (panel surface mounting)

Power

Rear SCADA Port

Rear Service Port

B

C

Ground at Back

supply

Wall of Housing

15 L+ (V+)

16 L– (V–)( )~

+

-

2550

IA

2247

I4

2449

IB

2348

IC

4521

Vc

20

19

Va

44

9570

BI6

Vb

5857

BI1

555483

56BI2

BI4BI5

BI3

4140

BI10

3914

BI11BI12

4318

3611

B8

BI15

9772

BO4

7499

BO1

73BO2

9065

8762

Live status 5152contact

BO10

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

r-fa

ces,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

46V4

Additional Port D

9671

BO5

98BO3

9469

BI7

3712

BI14

3813

BI13

4217

BI9

6488

BO7

63BO8

89BO9

8661BO11

8560BO12

8459BO13

EarthingTerminal (26)

2273

29

284

1

TimeSynchronisation

IN 12 VIN SYNC

COM SYNCCOMMON

IN 24 VScreen

IN 5 V

BO6Jumper1) (NO, NC)

1) Jumper: 1–2 NO2–3 NC

4617SJ62/63/64 ManualC53000-G1140-C147–1

Page 476: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

7SJ642∗ –∗ B

Figure A-37 General diagram 7SJ642∗ –∗ B (panel surface mounting)

Power

Rear SCADA Port

Rear Service Port

B

C

Ground at Back

supply

Wall of Housing

15 L+ (V+)

16 L– (V–)( )~

+

-

*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

2550

IA

2247

I4

2449

IB

2348

IC

4521

Vc

20

19

Va

44

9570

BI6

Vb

5857

BI1

555483

56BI2

BI4BI5

BI3

6665

BI8

63919089

64BI9

BI11BI12BI13BI14

BI10

8887

BI15

6261

BI16

8685

60BI17

BI19BI18

9469

8459

BI7

BI20

9772

BO4

7499

BO1

73BO2

181742

1439

12 (–)37 (+)

BO6 11

36

38

13

BO7

BO8

BO9

Live status 5152contact

*)

B10B11

BO12

Jumper1) (NO, NC)

Front PC Port Ass

ignm

ento

fPin

sof

In-

terf

aces

,ref

erto

Tab

le3-

35an

d3-

36in

Sub

-se

ctio

n3.

2.1

46V4

Additional Port D

9671

BO5

98BO3

EarthingTerminalTerminal (26)

2273

29

284

1

TimeSynchronisation

IN 12 VIN SYNC

COM SYNCCOMMON

IN 24 VScreen

IN 5 V

1) Jumper: 1–2 NO2–3 NC

462 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 477: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

7SJ645∗ –∗ B

Figure A-38 General diagram 7SJ645∗ –∗ B (panel surface mounting)

Power

Rear SCADA Port

Rear Service Port

B

C

Ground at Back

supply

Wall of Housing

37 L+ (V+)

38 L– (V–)( )~

+

-

*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

50100

IA

4797

I4

4999

IB

4898

IC

9546

Vc

45

44

Va

94

195145

BI6

Vb

108107

BI1

105104158

106BI2

BI4BI5

BI3

125124

BI8

122175174173

123BI9

BI11BI12BI13BI14

BI10

172171

BI15

121120

BI16

170169

119BI17

BI19BI18

168118

140139

137190

138

189

187

136135134

188

185184

183133

BI20

BI21BI22

BI24BI23

BI25BI26

BI28

BI29BI30BI31

BI27

BI32

BI33

197147

BO4

149199

BO1

148BO2

2322722171

3686

403989

19 (–)69 (+)

BO6 18

68

70

20

BO7

BO8

BO9

Live status 101102contact

*)

BO10BO11

BO12

BO13

BO14

BO15

BO16

34 (–)84 (+)33

83

85

35

BO17BO18

BO19

Jumper1) (NO, NC)

*)

Front PC Port

Ass

ignm

ento

fPin

sof

In-

terf

aces

,ref

erto

Tab

le3-

35an

d3-

36in

Sub

-se

ctio

n3.

2.1

96V4

186

Additional Port D

196146

BO5

198BO3

194144

BI7

2523

54

534

1

TimeSynchronisation

IN 12 VIN SYNC

COM SYNCCOMMON

IN 24 VSchirm

IN 5 V

EarthingTerminalTerminal (51)

1) Jumper: 1–2 NO2–3 NC

4637SJ62/63/64 ManualC53000-G1140-C147–1

Page 478: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

A.2.3.3 Housing for Mounting with Detached Operator Panel

7SJ641∗ –∗ A/C

Figure A-39 General diagram 7SJ641∗ –∗ A/C (panel surface mounting with detached operator panel)

Power

Rear SCADA Port

Rear Service Port

B

C

A

Earthing at the

supply

Rear Wall

F1

F2( )~

+

-

Time Synchronization

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

J3J4

BI10

J5J6

BI11BI12

K17K18

J11J12

B8

BI15

R5R6

BO4

R1R2

BO1

R3BO2

K3K4

K9K10

Live status F3F4contact

BO10

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

R11R12

BI7

J9J10

BI14

J7J8

BI13

J1J2

BI9

K6K7

BO7

K8BO8

K5BO9

K11K12BO11

K13K14BO12

K15K16BO13

Earthing at theRear Wall

Front SerialOperating Interface

OperatorPanel

BO6Jumper1) (NO, NC)

1) Jumper: 1–2 NO2–3 NC

464 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 479: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

7SJ642∗ –∗ A/C

Figure A-40 General diagram 7SJ642∗ –∗ A/C (panel surface mounting with detached operator panel)

Power

Rear SCADA Port

Rear Service Port

B

C

A

supplyF1

F2( )~

+

-

Time Synchronization

*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

R11R12

K15K16

BI7

BI20

R5R6

BO4

R1R2

BO1

R3BO2

J7J9J8

J11J12

J1 (–)J2 (+)

BO6 J3

J4

K18

K17

BO7

BO8

BO9

Live status F3F4contact

*)

B10B11

BO12

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

Earthing at theRear Wall

Earthing at theRear Wall

Front SerialOperating Interface

OperatorPanel

1) Jumper: 1–2 NO2–3 NC

4657SJ62/63/64 ManualC53000-G1140-C147–1

Page 480: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

7SJ645∗ –∗ A/C

Figure A-41 General diagram 7SJ645∗ –∗ A/C (panel surface mounting with detached operator panel)

Power

Rear SCADA Port

Rear Service Port

B

C

A

supplyF1

F2( )~

+

-

Time Synchronization*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

P1P2

P4P6

P3

P7

P9

P10P11P12

P8

P13P14

P15P16

BI20

BI21BI22

BI24BI23

BI25BI26

BI28

BI29BI30BI31

BI27

BI32

BI33

R5R6

BO4

R1R2

BO1

R3BO2

J7J9J8J11J12

N11N12

N7N9N8

J1 (–)J2 (+)

BO6 J3

J4

K18

K17

BO7

BO8

BO9

Live status F3F4contact

*)

B10B11

BO12

BO13

BO14

BO15

BO16

N1 (–)N2 (+)N3

N4

P18

P17

BO17BO18

BO19

Jumper1) (NO, NC)

*)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

P5

Additional Port D

R7R8

BO5

R4BO3

R11R12

BI7

Earthing at theRear Wall

Earthing at theRear Wall

Front SerialOperating Interface

OperatorPanel

1) Jumper: 1–2 NO2–3 NC

466 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 481: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

A.2.3.4 Devices for panel surface mounting without Operator Panel

7SJ641∗ –∗ F/G

Figure A-42 General diagram 7SJ641∗ –∗ F/G (panel surface mounting without operator panel)

Power

Rear SCADA Port

Rear Service Port

B

C

A

Earthing at the

supply

Rear Wall

F1

F2( )~

+

-

Time Synchronization

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

J3J4

BI10

J5J6

BI11BI12

K17K18

J11J12

B8

BI15

R5R6

BO4

R1R2

BO1

R3BO2

K3K4

K9K10

Live status F3F4contact

BO10

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

R11R12

BI7

J9J10

BI14

J7J8

BI13

J1J2

BI9

K6K7

BO7

K8BO8

K5BO9

K11K12BO11

K13K14BO12

K15K16BO13

Serial Operating Interface(to panel or door)

BO6Jumper1) (NO, NC)

1) Jumper: 1–2 NO2–3 NC

4677SJ62/63/64 ManualC53000-G1140-C147–1

Page 482: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

7SJ642∗ –∗ F/G

Figure A-43 General diagram 7SJ642∗ –∗ F/G (panel surface mounting without operator panel)

Power

Rear SCADA Port

Rear Service Port

B

C

A

supplyF1

F2( )~

+

-

Time Synchronization

*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

R11R12

K15K16

BI7

BI20

R5R6

BO4

R1R2

BO1

R3BO2

J7J9J8

J11J12

J1 (–)J2 (+)

BO6 J3

J4

K18

K17

BO7

BO8

BO9

Live status F3F4contact

*)

B10B11

BO12

Jumper1) (NO, NC)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

Additional Port D

R7R8

BO5

R4BO3

Earthing at theRear Wall

Serial Operating Interface(to panel or door)

1) Jumper: 1–2 NO2–3 NC

468 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 483: Manual 7SJ62-63-64 v44

A.2 Elementary Diagrams7SJ64

7SJ645∗ –∗ F/G

Figure A-44 General diagram 7SJ645∗ –∗ F/G (panel surface mounting without operator panel)

Power

Rear SCADA Port

Rear Service Port

B

C

A

supplyF1

F2( )~

+

-

Time Synchronization*)

Interference suppressioncapacitorsMP, 22 nF, 250 V

High-duty relays

Q1Q2

IA

Q7Q8

I4

Q3Q4

IB

Q5Q6

IC

R16R13

Vc

R15

R17

Va

R18

R9R10

BI6

Vb

F5F6

BI1

F8F9

F10

F7BI2

BI4BI5

BI3

K1K2

BI8

K4K6K7K8

K3BI9

BI11BI12BI13BI14

BI10

K9K5

BI15

K10K11

BI16

K13K14

K12BI17

BI19BI18

K15K16

P1P2

P4P6

P3

P7

P9

P10P11P12

P8

P13P14

P15P16

BI20

BI21BI22

BI24BI23

BI25BI26

BI28

BI29BI30BI31

BI27

BI32

BI33

R5R6

BO4

R1R2

BO1

R3BO2

J7J9J8J11J12

N11N12

N7N9N8

J1 (–)J2 (+)

BO6 J3

J4

K18

K17

BO7

BO8

BO9

Live status F3F4contact

*)

B10B11

BO12

BO13

BO14

BO15

BO16

N1 (–)N2 (+)N3

N4

P18

P17

BO17BO18

BO19

Jumper1) (NO, NC)

*)

Front PC Port

Ass

ignm

ento

fPin

sof

Inte

rfac

es,

refe

rto

Tab

le3-

35an

d3-

36in

Sub

sect

ion

3.2.

1

R14V4

P5

Additional Port D

R7R8

BO5

R4BO3

R11R12

BI7

Earthing at theRear Wall

Serial Operating Interface(to panel or door)

1) Jumper: 1–2 NO2–3 NC

4697SJ62/63/64 ManualC53000-G1140-C147–1

Page 484: Manual 7SJ62-63-64 v44

A Appendix 7SJ62

A.3 Connection Examples

A.3.1 Connection Examples for 7SJ62

Figure A-45 Current connections to three current transformers with a starpoint connection forground current (Grounded-Wye Connection with residual 3I0 Neutral Current),normal circuit layout – appropriate for all networks.

Figure A-46 Current connections to two current transformers –- only for ungrounded orcompensated networks.

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

15

14

13

12

30

29

28

27

7SJ62

l

k

L

K

l

k

L

K

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

15

14

13

12

30

29

28

27

7SJ62

470 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 485: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ62

Figure A-47 Current connections to three current transformers and a core balance neutralcurrent transformer for ground current - preferred for effectively or low-resistancegrounded networks

Figure A-48 Current connections to two current transformers and core balance neutral currenttransformer for sensitive ground fault detection - only for ungrounded orcompensated networks

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

15

14

13

27

30

29

28

12

7SJ62

I4

Ia

Ib

Icl

k

L

K

l

k

L

K

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

15

14

13

27

30

29

28

12

7SJ62

I4

Ia

Ib

Icl

k

L

K

l

k

L

K

4717SJ62/63/64 ManualC53000-G1140-C147–1

Page 486: Manual 7SJ62-63-64 v44

A Appendix 7SJ62

Figure A-49 Current connections to three current transformers – core balance neutral currenttransformers for sensitive ground fault detection.

Figure A-50 Current and voltage connections to three current transformers and three voltagetransformers (phase-ground), normal circuit layout – appropriate for all networks.

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

15

14

13

27

30

29

28

12

7SJ62

I4

Ia

Ib

Ic

l

k

L

K

l

k

L

K

Panel Surface MountedFlush-mounted/Cubicle

A B C

A

B

C

Busbar

Q1

Q3

Q5

Q7

Q2

Q4

Q6

Q8

R14

R15

R17

R16

R18

Va

Vb

Vc

45

44

43

60

59

15

14

13

12

30

29

28

27I4

Ia

Ib

Ic

7SJ62

l

k

L

K

ABab

472 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 487: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ62

Figure A-51 Current and voltage connections to three current transformers, two voltagetransformers (phase-phase) and open delta VT for V4, appropriate for allnetworks.

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

Busbar

Q1

Q3

Q5

Q7

Q2

Q4

Q6

Q8

R14

R15

R18

R16

R17

45

44

59

15

14

13

12

60

43

30

29

28

27

A B C

Va-b

Vc-b

VG

I4

Ia

Ib

Ic

7SJ62

l

k

L

K

AB

ab

dadn

4737SJ62/63/64 ManualC53000-G1140-C147–1

Page 488: Manual 7SJ62-63-64 v44

A Appendix 7SJ62

Figure A-52 Current and voltage connections to two current transformers and two voltagetransformers, for ungrounded or compensated networks, if no directional groundprotections is needed.

Figure A-53 Current and voltage connections to three current transformers with starpointconnection (Grounded-Wye Connection with residual 3I0 Neutral Current), twovoltage transformers, for ungrounded or compensated networks; no directionalground protection, since displacement voltage cannot be calculated

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

R14

R15

R17

R16

R18

45

44

43

15

14

13

12

60

59

30

29

28

27

Busbar

Va-b

Vc-b

I4

Ia

Ib

Ic

7SJ62

l

k

L

K

A A BB

a a bb

If only 2 VTs are presenton system side, deviceshould be connected inopen delta, short unusedvoltage input.

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

R14

R15

R17

R16

R18

45

44

43

15

14

13

12

60

59

30

29

28

27

Busbar

Va-b

Vc-b

I4

Ia

Ib

Ic

7SJ62

l

k

L

K

A A BB

a a bb

474 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 489: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ62

Figure A-54 Current and voltage connections to three current transformers, core balance neu-tral current transformers and open delta voltage transformers, maximum preci-sion for sensitive ground fault detection.

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

Busbar

R14

R15

R18

R16

R17

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on thecable side!

Note: Change of Address 0201 setting changes po-larity of I4 Current Input !

45

44

59

15

14

13

27

60

43

30

29

28

12

Va-b

Vc-b

VG

I4

Ia

Ib

Ic

7SJ62

l

k

L

K

l

k

L

K

AB

dadn

4757SJ62/63/64 ManualC53000-G1140-C147–1

Page 490: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

A.3.2 Connection Examples for 7SJ63

Figure A-55 Current connections to three current transformers with a starpoint connection forground current(Grounded-Wye Connection with residual 3I0 Neutral Current), nor-mal circuit layout – appropriate for all networks.

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

25

24

23

22

50

49

48

47

7SJ631/2/3

Size 1/2

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

50

49

48

47

100

99

98

97

7SJ635/6

Size 1/1

l

k

L

K

l

k

L

K

476 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 491: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ63

Figure A-56 Current connections to two current transformers - only for ungrounded or com-pensated networks.

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

25

24

23

22

50

49

48

47

7SJ631/2/3

Size 1/2

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

50

49

48

47

100

99

98

97

7SJ635/6

Size 1/1

l

k

L

K

l

k

L

K

4777SJ62/63/64 ManualC53000-G1140-C147–1

Page 492: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

Figure A-57 Current connections to three current transformers and a core balance neutralcurrent transformer for ground current – preferred for effectively or low-resistancegrounded networks

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of 3I0 CurrentInput !

25

24

23

47

50

49

48

22

7SJ631/2/3

I4

Ia

Ib

Ic

Size 1/2

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of 3I0 CurrentInput !

50

49

48

97

100

99

98

47

7SJ635/6

I4

Ia

Ib

Ic

Size 1/1

l

k

L

K

l

k

L

K

l

k

L

K

l

k

L

K

478 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 493: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ63

Figure A-58 Current connections to two current transformers and a core balance neutral cur-rent transformer for sensitive ground fault detection – only for ungrounded orcompensated networks

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

25

24

23

47

50

49

48

22

7SJ631/2/3

I4

Ia

Ib

Ic

Size 1/2

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

50

49

48

97

100

99

98

47

7SJ635/6

I4

Ia

Ib

Ic

Size 1/1

l

k

L

K

l

k

L

K

l

k

L

K

l

k

L

K

4797SJ62/63/64 ManualC53000-G1140-C147–1

Page 494: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

Figure A-59 Current and voltage connections to three current transformers and three voltagetransformers (phase-ground), normal circuit layout – appropriate for all networks.

Panel Surface MountedFlush-mounted/Cubicle

A B C

A

B

C

Busbar

Q1

Q3

Q5

Q7

Q2

Q4

Q6

Q8

R14

R15

R17

R16

R18

Va

Vb

Vc

21

46

19

20

44

25

24

23

22

50

49

48

47I4

Ia

Ib

Ic

Size 1/2

Panel Surface MountedFlush-mounted/Cubicle

A B C

A

B

C

Busbar

Q1

Q3

Q5

Q7

Q2

Q4

Q6

Q8

R14

R15

R17

R16

R18

Va

Vb

Vc

46

96

44

45

94

50

49

48

47

100

99

98

97I4

Ia

Ib

Ic

Size 1/1

7SJ631/2/3

7SJ635/6

l

k

L

K

l

k

L

K

ABab

ABab

480 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 495: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ63

Figure A-60 Current and voltage connections to three current transformers, two voltage trans-formers (phase-phase) and open delta VT for V4, appropriate for all networks.

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

Busbar

Q1

Q3

Q5

Q7

Q2

Q4

Q6

Q8

R14

R15

R18

R16

R17

21

46

44

25

24

23

22

20

19

50

49

48

47

A B C

Va-b

Vc-b

VG

I4

Ia

Ib

Ic

Size 1/2

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

Busbar

Q1

Q3

Q5

Q7

Q2

Q4

Q6

Q8

R14

R15

R18

R16

R17

46

96

94

50

49

48

47

45

44

100

99

98

97

A B C

Va-b

Vc-b

VG

I4

Ia

Ib

Ic

Size 1/1

7SJ631/2/3

7SJ635/6

l

k

L

K

l

k

L

K

AB

ab

dadn

AB

ab

dadn

4817SJ62/63/64 ManualC53000-G1140-C147–1

Page 496: Manual 7SJ62-63-64 v44

A Appendix 7SJ63

Figure A-61 Current and voltage connections to two current transformers and two voltagetransformers, for ungrounded or compensated networks, if no directional groundprotections is needed.

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

R14

R15

R17

R16

R18

21

46

19

25

24

23

22

20

44

50

49

48

47

Busbar

Va-b

Vc-b

I4

Ia

Ib

Ic

Size 1/2

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

R14

R15

R17

R16

R18

46

96

44

50

49

48

47

45

94

100

99

98

97

Busbar

Va-b

Vc-b

I4

Ia

Ib

Ic

Size 1/1

7SJ631/2/3

7SJ635/6

l

k

L

K

l

k

L

K

A A BB

a a bb

A A BB

a a bb

482 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 497: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ63

Figure A-62 Current and voltage connections to three current transformers, core balance neu-tral current transformers and open delta voltage transformers, maximum preci-sion for sensitive ground fault detection.

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

Busbar

R14

R15

R18

R16

R17

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Imp

ort

ant!

Cab

lesh

ield

grou

ndin

gm

ustb

edo

neon

the

cabl

esi

de!

Not

e:C

hang

eof

Add

ress

0201

setti

ngch

ange

spo

larit

yof

I NS

Cur

rent

Inpu

t!

21

46

44

25

24

23

47

20

19

50

49

48

22

Va-b

Vc-b

VG

I4

Ia

Ib

Ic

Size 1/2

Panel Surface Mounted

Flush-mounted/Cubicle

A

B

C

Busbar

R14

R15

R18

R16

R17

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

46

96

94

50

49

48

97

45

44

100

99

98

47

Va-b

Vc-b

VG

I4

Ia

Ib

Ic

Size 1/1

7SJ631/2/3

7SJ635/6

l

k

L

K

l

k

L

K

l

k

L

K

l

k

L

K

AB

dadn

AB

dadn

4837SJ62/63/64 ManualC53000-G1140-C147–1

Page 498: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

A.3.3 Connection Examples for 7SJ64

CurrentTransformerConnectionExamples

Figure A-63 Current connections to three current transformers with a star-point connection forearth current (residual 3I0 neutral current), normal circuit layout — appropriate forall networks

Housing Size 1/3

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

15

14

13

12

30

29

28

27

7SJ640

Flush-mounted/Cubicle

Panel Surface Mounted

A B C

I4

Ia

Ib

Ic

Q1

Q3

Q5

Q2

Q4

Q6

Q7 Q8

7SJ641/2/(5)

(50) 25

(49) 24

(48) 23

(47) 22

50 (100)

49 (99)

48 (98)

47 (97)

S2

S1

P2

P1

S2

S1

P2

P1

484 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 499: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ64

Figure A-64 Current connections to three current transformers with separate earth current transformer(summation current transformer or cable core balance current transformer)

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

15

14

13

27

30

29

28

12

7SJ640

I4

Ia

Ib

Ic

Housing Size 1/3

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

7SJ641/2/(5)

I4

Ia

Ib

Ic

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

(50) 25

(49) 24

(48) 23

(97) 47

50 (100)

49 (99)

48 (98)

22 (47)

S2

S1

P2

P1

S2

S1

P2

P1

S2

S1

P2

P1

S2

S1

P2

P1

4857SJ62/63/64 ManualC53000-G1140-C147–1

Page 500: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

Figure A-65 Current connections to two current transformers with separate earth currenttransformer (summation current transformer or cable core balance currenttransformer)

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

15

14

13

27

30

29

28

12

7SJ640

I4

Ia

Ib

Ic

Housing Size 1/3

Panel Surface Mounted

Flush-mounted/Cubicle

A B C

Q1

Q3

Q5

Q2

Q4

Q6

Q7Q8

Important! Cable shield grounding must be done on the cable side!

Note: Change of Address 0201 setting changes polarity of I4 CurrentInput !

7SJ641/2/(5)

I4

Ia

Ib

Ic

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

(50) 25

(49) 24

(48) 23

(97) 47

50 (100)

49 (99)

48 (98)

22 (47)

S2

S1

P2

P1

S2

S1

P2

P1

S2

S1

P2

P1

S2

S1

P2

P1

486 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 501: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ64

VoltageTransformerConnectionExamples

Figure A-66 Voltage connections to three Wye-connected voltage transformers(normal circuit layout)

Housing Size 1/3

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

45

44

60 Vc

7SJ640

R1659

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

(45) 20

(44) 19

(94) 44Vc

7SJ641/2/(5)

R16(95) 45

a b

A B

a b

A B

R1326

R1425

U4

R13(46) 21

R14(96) 46

U4

4877SJ62/63/64 ManualC53000-G1140-C147–1

Page 502: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

Figure A-67 Voltage connections to three Wye-connected voltage transformers withadditional open-delta windings (da–dn–winding)

Housing Size 1/3

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Ua

Ub

45

44

60Uc

7SJ640

R1659

R13U4

26

R1425

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

(45) 20

(44) 19

(94) 44Vc

7SJ641/2/(5)

R16(95) 45

R13V4

(46) 21

R14(96) 46

a b

A B

da dn

a b

A B

da dn

488 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 503: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ64

Figure A-68 Voltage connections to three Wye-connected voltage transformers withadditional open-delta windings (da–dn–winding) from the busbar

Housing Size 1/3

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

45

44

60Vc

7SJ640

R1659

R13V4

26

R1425

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

(45) 20

(44) 19

(94) 44Vc

7SJ641/2/(5)

R16(95) 45

R13V4

(46) 21

R14(96) 46

a b

A B

A

B

da

dn

a b

A B

A

B

da

dn

4897SJ62/63/64 ManualC53000-G1140-C147–1

Page 504: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

Figure A-69 Voltage connections to three Wye-connected voltage transformers andadditionally to any phase-to-phase voltage (for synchronism check for example)

Housing Size 1/3

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

45

44

60Vc

7SJ640

R1659

R13V4

26

R1425

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va

Vb

(45) 20

(44) 19

(94) 44Vc

7SJ641/2/(5)

R16(95) 45

R13V4

(46) 21

R14(96) 46

(any voltage)

(any voltage)

a b

A B

A

B

a

b

a b

A B

A

B

a

b

490 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 505: Manual 7SJ62-63-64 v44

A.3 Connection Examples7SJ64

Figure A-70 Voltage connections to three Wye-connected voltage transformers withadditional open-delta windings (da–dn–winding)

Housing Size 1/3

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va-b

Vb-c

45

44

60

7SJ640

R1659

R13V4

26

R1425

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

Panel Surface Mounted

Flush Mounted/Cubicle

A

B

C

R15

R17

R18

Va-b

Vb-c

(45) 20

(44) 19

(94) 44

7SJ641/2/(5)

R16(95) 45

R13V4

(46) 21

R14(96) 46

a b

A B

da dn

a b

A B

da dn

4917SJ62/63/64 ManualC53000-G1140-C147–1

Page 506: Manual 7SJ62-63-64 v44

A Appendix 7SJ64

Figure A-71 VT circuits with 2 VTs and any desired voltage from the bus-bar VTs (phase–phase)

A

B

C

R15

R17

R18

Va-b

Vc-b

45

44

60

7SJ640

R1659

R13V4

26

R1425

A

B

C

R15

R17

R18

Ua-b

Uc-b

(45) 58

(44) 57

(94) 56

7SJ641/2/(5)

R16(95) 55

R13U4

(46) 54

R14(96) 83

(any desired voltage)

(any desired voltage)

A

B

a

b

A

B

a

b

A

B

a

b

A

B

a

b

A

B

a

b

A

B

a

b

Panel Surface Mounted

Flush Mounted/Cubicle

Panel Surface Mounted

Flush Mounted/Cubicle

Housing Size 1/3

Housing Size 1/2 (Figures in Brackets Relating to Size 1/1)

492 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 507: Manual 7SJ62-63-64 v44

A.3 Connection Examples

A.3.4 Connection Examples for RTD-Box

Figure A-72 Simplex operation with one RTD-Boxabove: optical design (1 FO); below: design with RS485

Figure A-73 Half-duplex operation with one RTD-Boxabove: optical design (2 FOs); below: design with RS485

Figure A-74 Half-duplex operation with two RTD-Boxesabove: optical design (2 FOs); below: design with RS485

7SJ62/63/64

A’A

BB’

7XV566RTD-Box

7XV5650FO/RS485Converter

AB

T1Port C1)

*) for 7SJ64 optionally port C or D

A’A

BB’

7XV566RTD-Box

7SJ62/63/64 Port C2)A

B

Bus number: 00A’ and B’ jumpers forthe terminating resis-tors

Bus number: 00A’ and B’ jumpers forthe terminating resis-tors

7SJ62/63/64

7XV5650FO/RS485Converter

ABT1Port C1)

*) for 7SJ64 optionally port C or D

A’A

BB’

7XV566RTD-Box

7SJ62/63/64 Port C2)A

B

R1A’A

BB’

7XV566RTD-Box

Bus number: 01A’ and B’ jumpers forthe terminating resis-tors

Bus number: 01A’ and B’ jumpers forthe terminating resis-tors

7SJ62/63/64A

B

7XV566RTD-Box

Busnummer: 01

ABT1Port C1)

2) for 7SJ64 optionally port C or D

A

B

7XV566RTD-Box

Bus number: 017SJ62/63/64 Port C2)A

B

R1

A’A

BB’

7XV566RTD-Box

A’A

BB’

7XV566RTD-Box

Bus number: 02A’ and B’ jumpers forthe terminating resis-tors

Bus number: 02A’ and B’ jumpers forthe terminating resis-tors

7XV5650FO/RS485Converter

1) for 7SJ64 port D

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A Appendix

A.4 Default Settings

A.4.1 LED Displays

The LED indication presettings which are preset in the device when it leaves the fac-tory are summarised in Table A-1. Please take into consideration that LED8 to LED14is not available in the devices in housings of size 1/3.

A.4.2 Binary Inputs

The presettings of the binary inputs are listed (dependent on the ordering variant) inTables A-2 to A-4.

Table A-1 LED indication presettings

LED Descriptive Text Brief Text Message # Comments

LED 1 Relay Tripped Relay TRIP 511 One the protective functions initiated a trip.

LED 2 Pickup Phase A 50/51 Ph A PU67 A picked up

17622692

Pickup by Aφ Element

LED 3 Pickup Phase B 50/51 Ph B PU67 B picked up

17632693

Pickup by Bφ Element

LED 4 Pickup Phase C 50/51 Ph C PU67 C picked up

17642694

Pickup by Cφ Element

LED 5 Pickup G 50N/51N Pickedup67 N picked up

17652695

Pickup by Ground Element

LED 6 MeasurementFailure

Failure ΣIFail I balanceFail V balanceFail Ph. Seq. IFail Ph. Seq. V

162163167175176

Monitoring Message

LED 7 −−−−−−−−−−−−−−− −−−−−−−−−−−−−−− Not Configured

LED 8 Breaker OPENED Bkr OPENED Internal message made in CFC

LED 9 Cabinet door open >Door open Individual message coupled via BI

LED 10 Spring not charged >CB wait Individual message coupled via BI

LED 11 to 14 −−−−−−−−−−−−−−− −−−−−−−−−−−−−−− Not Configured

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A.4 Default Settings

Positions that are not indicated in the following tables have no presetting.

Table A-2 Binary input presettings for all devices and ordering variants

Binary Input LCD Text Function No. Remarks

BI1 >BLOCK 50-2>BLOCK 50N-2

17211724

Blocking the high-set stage of the over-current protection,H–active

BI2 >Reset LED 0005 Reset of LED indicators,H–active

BI3 >Light on ---- Switch on light for device display,H–active

BI4 >52-b 4602 Circuit breaker open, H–active

BI5 >52-a 4601 Circuit breaker closed,H–active

1) only devices without power relays2) only devices with power relays

Table A-3 Further binary input presettings for 7SJ631*–

Binary Input LCD Text Function No. Remarks

BI6 Disc.Swit. OPEN ---- Disconnector switch open

BI7 Disc.Swit. CLOSE ---- Disconnector switch closed

BI 21 GndSwit. OPEN ---- Ground switch open

BI 22 GndSwit. CLOSE ---- Ground switch closed

BI 23 >CB Ready ---- Spring charged

BI 24 >DoorClose ---- Door closed

(further) — — no presetting

Table A-4 Further binary input presettings for 7SJ632*–, 7SJ633*–, 7SJ635*– ,7SJ636*–, 7SJ641*–, 7SJ642*– and 7SJ645*–

Binary Input LCD Text Function No. Remarks

BI 6 Disc.Swit. OPEN ---- Disconnector switch open

BI 7 Disc.Swit. CLOSE ---- Disconnector switch closed

BI 8 GndSwit. OPEN ---- Ground switch open

BI 9 GndSwit. CLOSE ---- Ground switch closed

BI 11 >CB Ready ---- Spring charged

BI 12 >DoorClose ---- Door closed

(further) — — no presetting

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A Appendix

A.4.3 Binary Outputs

The presettings of the binary outputs are listed (dependent on the ordering variant) inTables A-5 to A-8. The Elementary Diagrams in Appendix A, A.2 show which binaryoutputs can be used as accelerated binary outputs, i. e. suited for a fast commandtripping.

Positions that are not indicated in the following tables have no presetting.

Table A-5 Binary Output presetting for all ordering variants of 7SJ62 and 7SJ63

BinaryOutput

LCD Text FunctionNo.

Remarks

BO1 Relay TRIP52Breaker OPEN

0511----

Relay (general) TRIP command, un-latched Relay TRIP

BO2 52Breaker CLOSE79 Close

----2851

Breaker CLOSEAuto Reclosing Command

BO3 52Breaker CLOSE79 Close.

----2851

Breaker CLOSEAuto Reclosing Command

Table A-6 Further binary output presettings for 7SJ62**–

BinaryOutput

LCD Text FunctionNo.

Remarks

BO4 Failure S IFail I balanceFail V balanceFail Ph. Seq. VFail Ph. Seq. I

01620163016701760175

Monitoring

BO7 Relay PICKUP 0501 Relay (general) TRIP command, un-latched

Tabelle A-7 Further binary output presettings for all 7SJ63**–

BinaryOutput

LCD Text FunctionNo.

Remarks

BO11 GndSwit. OPEN ---- Ground switch open

BO12 GndSwit. CLOSE ---- Ground switch closed

BO13 Disc.Swit. OPEN ---- Disconnector switch open

BO14 Disc.Swit. CLOSE ---- Disconnector switch closed

BO15 Failure S IFail I balanceFail V balanceFail Ph. Seq. VFail Ph. Seq. I

01620163016701760175

Monitoring

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A.4 Default Settings

A.4.4 Function Keys

Applies for all devices and ordered variants:

Tabelle A-8 Further binary output presettings for 7SJ632*–, 7SJ633*–, 7SJ635*– and7SJ636*–

BinaryOutput

LCD Text FunctionNo.

Remarks

BO10 Relay PICKUP 0501 Relay (general) PICKUP, unlatched

Tabelle A-9 Binary Output presetting for all ordering variants of 7SJ64**–

BinaryOutput

LCD Text FunctionNo.

Remarks

BO3 Relay TRIP52Breaker OPEN

0511----

Relay (general) TRIP command, un-latched Relay TRIP

BO4 52Breaker CLOSE79 Close

----2851

Breaker CLOSEAuto Reclosing Command

BO5 52Breaker CLOSE79 Close.

----2851

Breaker CLOSEAuto Reclosing Command

Table A-10 Further binary output presettings for 7SJ641*–, 7SJ642*– and 7SJ645*–

BinaryOutput

LCD Text FunctionNo.

Remarks

BO1 GndSwit. OPEN ---- Ground switch open

BO2 GndSwit. CLOSE ---- Ground switch closed

BO10 Disc.Swit. OPEN ---- Disconnector switch open

BO11 Disc.Swit. CLOSE ---- Disconnector switch closed

Function Keys Presetting

F1 Display of operational indications

F2 Display of the primary operational measured values

F3 Display of the fault indications of the last fault event

F4 No presetting

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A Appendix

A.4.5 Standard Default Display

Default Display ofthe 4-Line Display

Figure A-75 Default display for 4-line display

Standard DefaultDisplay of theGraphic Display

Figure A-76 Default display of the graphic display

1 0.50kA 12 6.31kV 2 0.50kA 23 6.30kV3 0.50kA 31 6.29kVE 0.0A E 2V

S: 0.0MVA U12: 0kV P: 0.0MW IL2: 0AQ: 0.0MVAR F: --- cosϕ: ---

[%] I ULE ULL L1 78.4 99.6 99.5L2 78.1 99.4 99.3L3 78.9 99.8 99.7

I1:123.4A f: 50.01Hz U1:10.3kV cosϕ:0.85P: 1.1MW Q 0.2MVAR

U1=10.0kV dU= 0Vf1=50.11Hz df= 13mHzU2=10.0kV dα=0.013°f1=50.02Hz

only for 7SJ64

L1 78.4A L2 78.1A L3 78.9A E 0.0A

L1 78.4A MAX 81.2AL2 78.1A MAX 81.0AL3 78.9A MAX 81.9AE 0.0A

[%] IL ULE ULL L1 0.0 0.0 0.0L2 0.0 0.0 0.0L3 0.0 0.0 0.0

I U12 0kV23 0kV31 0kVL1 0A 0kVL2 0A 0kV L3 0A 0kVE 0A 0kV

I-MIN I-MAX L1 0A 0AL2 0A 0AL3 0A 0A

S: 0.0MVA P: 0.0MW Q: 0.0MVAR F: --- cosϕ: ---

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A.4 Default Settings

A.4.6 Spontaneous Display Annunciations

Text Display The spontaneous annunciations that can be viewed on the device front serve to dis-play the most important data about a fault. The in appear automatically in the display,after a general pickup of the device, in the sequence shown in Figure A-77.

Figure A-77 Display of Spontaneous Annunciations in the HMI – Example

Graphic Display All devices featuring a graphic display allow you to select whether or not to view auto-matically the most important fault data on the display after a general pick-up (see Sub-section 2.20.1.2). The information corresponds to those of Figure A-77.

Protective Function that picked up first;Protective Function that dropped out last;Running time from general pickup to dropout;Running time from general pickup to the first trip command

501 picked up501 TRIPT Pickup= 320ms T OFF = 197ms

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A Appendix

A.4.7 Pre-Defined CFC Charts

Some CFC Charts are already supplied with the SIPROTEC® device.Depending on the variant the following charts may be implemented:

Device and SystemLogic

The NEGATOR block assigns the input signal “DataStop“ directly to an output. This isnot directly possible without the interconnection of this block.

:

Figure A-78 Device and System Logic

Set points Using modules on the running sequence “measured value processing”, a low currentmonitor for the three phase currents is implemented. The output message is set highas soon as one of the three phase currents falls below the set threshold:

Figure A-79 Undercurrent monitoring (ANSI 37-1)

IN: Device, General OUT: Control Device UnblockDT IntSP

IN: Control DeviceOUT: Device, General Feeder gnd IntSP

>DataStop SP

GndSwit. DP

OUT: Device, General Brk OPENEDIntSP

IN: Control Device,52 Breaker DP

IN: P.System Data 2Relay TRIP OUT

IN: Set points 37-1 LVIN: Measurement Ia = MV

IN: Set points 37-1 LVIN: Measurement Ib = MV

IN: Set points 37-1 LVIN: Measurement Ic = MV

OUT: Set points SP. 37-1alarm OUT

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A.4 Default Settings

Blocks of the task level “MW_BEARB” (measured value processing) are used to im-plement the overcurrent monitoring and the power monitoring.

Figure A-80 Overcurrent monitoring

Figure A-81 Power monitoring

IN: Set points I Admd> LV OUT: Set points SP. I A dmd> OUTIN: Demand meter Ia dmd= MV

OUT: Set points SP. I B dmd> OUTIN: Set points I Bdmd> LVIN: Demand meter Ib dmd= MV

IN: Set points I Cdmd> LVIN: Demand meter Ic dmd= MV

IN: Set points I1dmd> LVIN: Demand meter I1 dmd= MV

OUT: Set points SP. I C dmd> OUT

OUT: Set points SP. I1 dmd> OUT

IN: Set points |Pdmd|> LV

IN: Demand meter P dmd = MV

OUT: Set points SP.|Pdmd|> OUT

IN: Set points |Qdmd|> LV

IN: Demand meter Q dmd = MV

IN: Set points |Sdmd|> LV

IN: Demand meter S dmd = MV

IN: Set points |PF|< LU

IN: Measurement PF = MV

OUT: Set points SP.|Qdmd|> OUT

OUT: Set points SP.|Sdmd|> OUT

OUT: Set points SP.PF(55)alarm OUT

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A Appendix

Interlocking Standard Interlocking for three switching devices

Worksheet 1:

Worksheet 2 (continuation of Worksheet 1):

Figure A-82 Standard Interlocking For Circuit Breaker, Disconnector and Ground Switch

IN: Control Device 52Breaker DP

IN: Control Device 52Breaker DP

IN: Control Device Disc.Swit. DP

IN: Control Device Disc.Swit. DP

IN: Control Device GndSwit. DP

IN: Control Device GndSwit. DP

IN: Process Data >DoorClose SP

Interlocking .14 X1Interlocking .15 X1

Interlocking .13 X1

Interlocking .15 X2

Interlocking .14 X2

Interlocking .14 X3

Interlocking .13 X3

Interlocking .15 X3

OUT: Control Device 52 CloseIN: Process Data >CB ready SP IntSP

IN: Process Data >DoorClose SP

IN: Process Data >DoorClose SP

IN: Process Data >DoorClose SP

IN: Process Data >DoorClose SP

Interlocking. 1 Y Annunciation

Interlocking. 1 Y Annunciation

Interlocking. 1 Y Annunciation

Interlocking. 8 YInterlocking. 5 Y Annunciation

Interlocking. 8 YInterlocking. 10 Y

Interlocking. 3 Y AnnunciationInterlocking. 10 Y

OUT:Control Device 52 Open IntSP

OUT:Control Device Disc.Close IntSP

OUT:Control Device Disc.Open IntSP

OUT: Control Device GndSw Open IntSPOUT: Control Device GndSw Cl. IntSP

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A.5 Interoperability List

A.5 Interoperability List

1. Physical layer

1.1 Electrical interfaceEIA RS-485 Number of loads for one equipment: 32

1.2 Optical interfaceGlass fibre F-SMA type connectorPlastic fibre BFOC/2,5 type connector

1.3 Transmission speed9600 bit/s 19200 bit/s

2. Link layer

There are no choices for the link layer

3. Application layer

3.1 Transmission mode for application data Mode 1 (least significant octet first) as defined in 4.10 ofIEC 60870-5-4

3.2 Common address of ASDUOne common address of ADSU More than one common address of ASDU(identical with station address)

3.3 Selection of standard information numbers in monitor direction3.3.1 System functions in monitor direction

0 End of general interrogation 0 Time synchronization2 Reset FCB 3 Reset CU4 Start/restart 5 Power on

3.3.23.3.33.3.4 see separate table in the device manual (Information List in the following section)3.3.53.3.6

3.3.7 Measurands in monitor direction144 Measurand I 145 Measurands I, V146 Measurand I, V, P, Q 147 Measurands IN, VEN148 Measurands IL1,2,3, VL1,2,3, P, Q, f

3.3.8 Generic functions in monitor direction240 Read headings of all defined groups 241 Read values of all entries of one group243 Read directory of a single entry 244 Read value of a single entry245 End of general interrogation generic 249 Write entry with confirmation

data250 Write entry with execution 251 Write entry aborted

3.4 Selection of standard information numbers in control direction3.4.1 System functions in control direction

0 Initiation of general interrogation 0 Time synchronization3.4.2 General commands in control direction

16 Auto-recloser on / off 17 Teleprotection on / off18 Protection on / off 19 LED reset

X X

XX X

X X

X

X XX XX X

X

X X

XX X

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A Appendix

23 Activate characteristic 1 24 Activate characteristic 225 Activate characteristic 3 26 Activate characteristic 4

3.4.3 Generic functions in control direction240 Read headings of all defined groups 241 Read values of all entries of one group243 Read directory of a single entry 244 Read value of a single entry245 General interrogation of generic data 248 Write entry249 Write entry with confirmation 250 Write entry with execution251 Write entry abort

3.5 Basic application functionsTest mode Blocking of monitor directionDisturbance data Generic servicesPrivate data

3.6 Miscellaneous

Measurand max. value = rated value x1.2 2.4

Current L1Current L2Current L3Voltage L1-EVoltage L2-EVoltage L3-EVoltage L1-L2Active power PReactive power QFrequency f

X XX X

X XXX

X

X

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A.6 Protocol-dependent functions

A.6 Protocol-dependent functions

Protocol → IEC 60870–5–103 Profibus FMS Profibus DP DNP3.0 Modbus ASCII/RTU

Additionalinterface(optional)Function

Operational mea-sured values

Yes Yes Yes Yes Yes Yes

Metered values Yes Yes Yes Yes Yes Yes

Fault recording Yes Yes No. Only via addi-tional service inter-face

No. Only via addi-tional service inter-face

No. Only via addi-tional service inter-face

Yes

Remote relay setting No. Only via addi-tional service inter-face

Yes No. Only via addi-tional service inter-face

No. Only via addi-tional service inter-face

No. Only via addi-tional service inter-face

Yes

User-defined mes-sages and switchingobjects

Yes Yes Pre-defined “User-defined messag-es” in CFC

Pre-defined “User-defined messag-es” in CFC

Pre-defined “User-defined messages”in CFC

Yes

Time synchronization Via protocol;DCF77/IRIG B;Interface;Binary input

Via protocol;DCF77/IRIG B;Interface;Binary input

Via DCF77/IRIG B;Interface;Binary input

Via protocol;DCF77/IRIG B;Interface;Binary input

Via DCF77/IRIG B;Interface;Binary input

Messages with timestamp

Yes Yes No Yes No Yes

Commissioning aids

• Measured valueindication block-ing

Yes Yes No No No Yes

• Creating test mes-sages

Yes Yes No No No Yes

Physical mode Asynchronous Asynchronous Asynchronous Asynchronous Asynchronous –

Transmission mode Cyclically/Event Cyclically/Event

Cyclically Cyclically/Event Cyclically –

Baudrate 4800 to 38400 Up to 1.5MBaud

Up to 1.5 MBaud 4800 to 19200 2400 to 19200 4800 to115200

Type RS232RS485Optical fibre

RS485Optical fibre

• Single ring

• Double ring

RS485Optical fibre

• Double ring

RS485Optical fibre

RS485Optical fibre

RS232RS485Optical fi-bre

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A Appendix

A.7 Functions Overview

Note: Addresses may be missing depending on the type and the ordered variant

Addr. Setting Title Setting Options Default Setting Comments

103 Grp Chge OPTION DisabledEnabled

Disabled Setting Group Change Option

104 OSC. FAULT REC. DisabledEnabled

Disabled Oscillographic Fault Records

112 Charac. Phase DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and ResetCurve

Definite Time only 50/51

113 Charac. Ground DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and ResetCurve

Definite Time only 50N/51N

115 67/67-TOC DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and ResetCurve

Definite Time only 67, 67-TOC

116 67N/67N-TOC DisabledDefinite Time onlyTime Overcurrent Curve IECTime Overcurrent Curve ANSIUser Defined Pickup CurveUser Defined Pickup and ResetCurve

Definite Time only 67N, 67N-TOC

117 Coldload Pickup DisabledEnabled

Disabled Cold Load Pickup

122 InrushRestraint DisabledEnabled

Disabled 2nd Harmonic Inrush Restraint

131 Sens. Gnd Fault DisabledDefinite Time onlyUser Defined Pickup Curve

Disabled (sensitive) Ground fault

133 INTERM.EF Disabledwith Ignd (measured)with 3I0 (calculated)with Ignd,sensitive (measured)

Disabled Intermittent earth fault protection

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A.7 Functions Overview

140 46 DisabledTime Overcurrent Curve ANSITime Overcurrent Curve IECDefinite Time only

Disabled 46 Negative Sequence Protec-tion

141 48 DisabledEnabled

Disabled 48 Startup Supervision of Motors

142 49 DisabledWithout ambient temperaturemeasurementWith ambient temperature mea-surement

Disabled 49 Thermal Overload Protection

143 66 #of Starts DisabledEnabled

Disabled 66 Startup Counter for Motors

150 27/59 DisabledEnabled

Disabled 27, 59 Under/Overvoltage Pro-tection

154 81 O/U DisabledEnabled

Disabled 81 Over/Underfrequency Protec-tion

161 25 Function 1 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 1

162 25 Function 2 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 2

163 25 Function 3 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 3

164 25 Function 4 DisabledASYN/SYNCHRONSYNCHROCHECK

Disabled 25 Function group 4

170 50BF DisabledEnabled

Disabled 50BF Breaker Failure Protection

171 79 Auto Recl. DisabledEnabled

Disabled 79 Auto-Reclose Function

180 Fault Locator DisabledEnabled

Disabled Fault Locator

182 74 Trip Ct Supv Disabledwith 2 Binary Inputswith 1 Binary Input

Disabled 74TC Trip Circuit Supervision

190 RTD-BOX INPUT DisabledPort CPort D

Disabled External Temperature Input

191 RTD CONNECTION 6 RTD simplex operation6 RTD half duplex operation12 RTD half duplex operation

6 RTD simplexoperation

Ext. Temperature Input Connec-tion Type

Addr. Setting Title Setting Options Default Setting Comments

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A Appendix

A.8 Settings

Note: The following table lists all data which are available in the maximum complement of the devices. Depen-dent on the ordered model, only those data may be present which are valid for the individual version. In the listbelow, the setting ranges and default setting values for the pickup currents are for a device with a nominal cur-rent rating IN = 1 A. For a nominal current rating IN = 5 A, multiply the Setting Options values and Default Settingvalues by 5. Consider the current transformer ratios when setting the device with primary values.

Addresses to which the letter “A“ is attached can only be modified by using the DIGSI® 4 software at “FurtherSettings“.

Addr. Setting Title Function Setting Options Default Setting Comments

201 CT Starpoint Power SystemData 1

towards Linetowards Busbar

towards Line CT Starpoint

202 Vnom PRIMARY Power SystemData 1

0.10..800.00 kV 12.00 kV Rated Primary Voltage

203 Vnom SECON-DARY

Power SystemData 1

100..225 V 100 V Rated Secondary Voltage(L-L)

204 CT PRIMARY Power SystemData 1

10..50000 A 100 A CT Rated Primary Current

205 CT SECONDARY Power SystemData 1

1A5A

1A CT Rated Secondary Cur-rent

206A Vph / Vdelta Power SystemData 1

1.00..3.00 1.73 Matching ratio Phase-VTTo Open-Delta-VT

209 PHASE SEQ. Power SystemData 1

A B CA C B

A B C Phase Sequence

210A TMin TRIP CMD Power SystemData 1

0.01..32.00 sec 0.15 sec Minimum TRIP CommandDuration

211A TMax CLOSE CMD Power SystemData 1

0.01..32.00 sec 1.00 sec Maximum Close CommandDuration

212 BkrClosed I MIN Power SystemData 1

0.04..1.00 A 0.04 A Closed Breaker Min. Cur-rent Threshold

213 VT Connection Power SystemData 1

Van, Vbn, VcnVab, Vbc, VGndVan, Vbn, Vcn,VGndVan, Vbn, Vcn,VSyn

Van, Vbn, Vcn VT Connection

214 Rated Frequency Power SystemData 1

50 Hz60 Hz

50 Hz Rated Frequency

215 Distance Unit Power SystemData 1

kmMiles

km Distance measurement unit

217 Ignd-CT PRIM Power SystemData 1

1..50000 A 60 A Ignd-CT rated primary cur-rent

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A.8 Settings

218 Ignd-CT SEC Power SystemData 1

1A5A

1A Ignd-CT rated secondarycurrent

235A ATEX100 Power SystemData 1

NOYES

NO Storage of th. Replicas w/oPower Supply

276 TEMP. UNIT Power SystemData 1

Degree CelsiusDegree Fahrenheit

Degree Celsius Unit of temparature measu-rement

302 CHANGE Change Group Group AGroup BGroup CGroup DBinary InputProtocol

Group A Change to Another SettingGroup

401 WAVEFORMTRIG-GER

OscillographicFault Records

Save with PickupSave with TRIPStart with TRIP

Save with Pickup Waveform Capture

402 WAVEFORMDATA

OscillographicFault Records

Fault eventPower System fault

Fault event Scope of Waveform Data

403 MAX. LENGTH OscillographicFault Records

0.30..5.00 sec 2.00 sec Max. length of a WaveformCapture Record

404 PRE. TRIG. TIME OscillographicFault Records

0.05..0.50 sec 0.25 sec Captured Waveform Priorto Trigger

405 POST REC. TIME OscillographicFault Records

0.05..0.50 sec 0.10 sec Captured Waveform afterEvent

406 BinIn CAPT.TIME OscillographicFault Records

0.10..5.00 sec; ∞ 0.50 sec Capture Time via BinaryInput

610 FltDisp.LED/LCD Device, Gene-ral Settings

Display Targets onevery PickupDisplay Targets onTRIP only

Display Targets onevery Pickup

Fault Display on LED / LCD

611 Spont. FltDisp. Device, Gene-ral Settings

YESNO

NO Spontaneous display offlt.annunciations

613A 50N/51N/67N w. Power SystemData 1

Ignd (measured)3I0 (calculated)

Ignd (measured) 50N/51N/67N GroundOvercurrent with

1101 FullScaleVolt. Power SystemData 2

0.10..800.00 kV 12.00 kV Measurem:FullScaleVol-tage(Equipm.rating)

1102 FullScaleCurr. Power SystemData 2

10..50000 A 100 A Measurem:FullScaleCur-rent(Equipm.rating)

1103 RG/RL Ratio Power SystemData 2

-0.33..7.00 1.00 RG/RL - Ratio of Gnd toLine Resistance

1104 XG/XL Ratio Power SystemData 2

-0.33..7.00 1.00 XG/XL - Ratio of Gnd toLine Reactance

1105 x' Power SystemData 2

0.010..10.000 Ohm /mile

1.000 Ohm / mile x' - Line Reactance perlength unit

1106 x' Power SystemData 2

0.005..6.215 Ohm /km

0.620 Ohm / km x' - Line Reactance perlength unit

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

1107 I MOTOR START Power SystemData 2

0.60..10.00 A 2.50 A Motor Start Current (Block49, Start 48)

1201 FCT 50/51 50/51 Phase/Ground Over-current

ONOFF

ON 50, 51 Phase Time Over-current

1202 50-2 PICKUP 50/51 Phase/Ground Over-current

0.10..35.00 A; ∞ 2.00 A 50-2 Pickup

1203 50-2 DELAY 50/51 Phase/Ground Over-current

0.00..60.00 sec; ∞ 0.00 sec 50-2 Time Delay

1204 50-1 PICKUP 50/51 Phase/Ground Over-current

0.10..35.00 A; ∞ 1.00 A 50-1 Pickup

1205 50-1 DELAY 50/51 Phase/Ground Over-current

0.00..60.00 sec; ∞ 0.50 sec 50-1 Time Delay

1207 51 PICKUP 50/51 Phase/Ground Over-current

0.10..4.00 A 1.00 A 51 Pickup

1208 51 TIME DIAL 50/51 Phase/Ground Over-current

0.05..3.20 sec; ∞ 0.50 sec 51 Time Dial

1209 51 TIME DIAL 50/51 Phase/Ground Over-current

0.50..15.00; ∞ 5.00 51 Time Dial

1210 51 Drop-out 50/51 Phase/Ground Over-current

InstantaneousDisk Emulation

Disk Emulation Drop-out characteristic

1211 51 IEC CURVE 50/51 Phase/Ground Over-current

Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1212 51 ANSI CURVE 50/51 Phase/Ground Over-current

Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1213A MANUAL CLOSE 50/51 Phase/Ground Over-current

50-2 instantane-ously50 -1 instantane-ously51 instantaneouslyInactive

50-2 instantane-ously

Manual Close Mode

Addr. Setting Title Function Setting Options Default Setting Comments

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A.8 Settings

1214A 50-2 active 50/51 Phase/Ground Over-current

Alwayswith 79 active

Always 50-2 active

1230 51/51N 50/51 Phase/Ground Over-current

1.00..20.00 I / Ip; ∞0.01..999.00 TimeDial

51/51N

1231 MofPU Res T/Tp 50/51 Phase/Ground Over-current

0.05..0.95 I / Ip; ∞0.01..999.00 TimeDial

Multiple of Pickup <-> T/Tp

1301 FCT 50N/51N 50/51 Phase/Ground Over-current

ONOFF

ON 50N, 51N Ground TimeOvercurrent

1302 50N-2 PICKUP 50/51 Phase/Ground Over-current

0.05..35.00 A; ∞ 0.50 A 50N-2 Pickup

1303 50N-2 DELAY 50/51 Phase/Ground Over-current

0.00..60.00 sec; ∞ 0.10 sec 50N-2 Time Delay

1304 50N-1 PICKUP 50/51 Phase/Ground Over-current

0.05..35.00 A; ∞ 0.20 A 50N-1 Pickup

1305 50N-1 DELAY 50/51 Phase/Ground Over-current

0.00..60.00 sec; ∞ 0.50 sec 50N-1 Time Delay

1307 51N PICKUP 50/51 Phase/Ground Over-current

0.05..4.00 A 0.20 A 51N Pickup

1308 51N TIME DIAL 50/51 Phase/Ground Over-current

0.05..3.20 sec; ∞ 0.20 sec 51N Time Dial

1309 51N TIME DIAL 50/51 Phase/Ground Over-current

0.50..15.00; ∞ 5.00 51N Time Dial

1310 51N RESET 50/51 Phase/Ground Over-current

InstantaneousDisk Emulation

Disk Emulation Drop-Out Characteristic

1311 51N IEC CURVE 50/51 Phase/Ground Over-current

Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1312 51N ANSI CURVE 50/51 Phase/Ground Over-current

Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

1313A MANUALCLOSE-MODE

50/51 Phase/Ground Over-current

50N-2 instantane-ously50N-1 instantane-ously51N instantaneouslyInactive

50N-2 instantane-ously

Manual Close Mode

1314A 50N-2 active 50/51 Phase/Ground Over-current

Alwayswith 79 Active

Always 50N-2 active

1330 50N/51N 50/51 Phase/Ground Over-current

1.00..20.00 I / Ip; ∞0.01..999.00 TimeDial

50N/51N

1331 MofPU Res T/TEp 50/51 Phase/Ground Over-current

0.05..0.95 I / Ip; ∞0.01..999.00 TimeDial

Multiple of Pickup <-> T/TEp

1501 FCT 67/67-TOC 67 DirectionalPhase/GroundOvercurrent

OFFON

OFF 67, 67-TOC Phase TimeOvercurrent

1502 67-2 PICKUP 67 DirectionalPhase/GroundOvercurrent

0.10..35.00 A; ∞ 2.00 A 67-2 Pickup

1503 67-2 DELAY 67 DirectionalPhase/GroundOvercurrent

0.00..60.00 sec; ∞ 0.10 sec 67-2 Time Delay

1504 67-1 PICKUP 67 DirectionalPhase/GroundOvercurrent

0.10..35.00 A; ∞ 1.00 A 67-1 Pickup

1505 67-1 DELAY 67 DirectionalPhase/GroundOvercurrent

0.00..60.00 sec; ∞ 0.50 sec 67-1Time Delay

1507 67-TOC PICKUP 67 DirectionalPhase/GroundOvercurrent

0.10..4.00 A 1.00 A 67-TOC Pickup

1508 67 TIME DIAL 67 DirectionalPhase/GroundOvercurrent

0.05..3.20 sec; ∞ 0.50 sec 67-TOC Time Dial

1509 67 TIME DIAL 67 DirectionalPhase/GroundOvercurrent

0.50..15.00; ∞ 5.00 67-TOC Time Dial

1510 67-TOC Drop-out 67 DirectionalPhase/GroundOvercurrent

InstantaneousDisk Emulation

Disk Emulation Drop-Out Characteristic

1511 67- IEC CURVE 67 DirectionalPhase/GroundOvercurrent

Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

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A.8 Settings

1512 67- ANSI CURVE 67 DirectionalPhase/GroundOvercurrent

Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1513A MANUALCLOSE-MODE

67 DirectionalPhase/GroundOvercurrent

67-2 instantane-ously67-1 instantane-ously67-TOC instantane-ouslyInactive

67-2 instantane-ously

Manual Close Mode

1514A 67 active 67 DirectionalPhase/GroundOvercurrent

with 79 activealways

always 67 active

1515A Normal Load 67 DirectionalPhase/GroundOvercurrent

Inductive (135°)Resistive (90°)Capacitive(45°)

Inductive (135°) Normal Load (Torque angleof dir. fct)

1516 67 Direction 67 DirectionalPhase/GroundOvercurrent

ForwardReverse

Forward Phase Direction

1530 67 67 DirectionalPhase/GroundOvercurrent

1.00..20.00 I / Ip; ∞0.01..999.00 TimeDial

67

1531 MofPU Res T/Tp 67 DirectionalPhase/GroundOvercurrent

0.05..0.95 I / Ip; ∞0.01..999.00 TimeDial

Multiple of Pickup <-> T/Tp

1601 FCT 67N/67N-TOC 67 DirectionalPhase/GroundOvercurrent

OFFON

OFF 67N, 67N-TOC GroundTime Overcurrent

1602 67N-2 PICKUP 67 DirectionalPhase/GroundOvercurrent

0.05..35.00 A; ∞ 0.50 A 67N-2 Pickup

1603 67N-2 DELAY 67 DirectionalPhase/GroundOvercurrent

0.00..60.00 sec; ∞ 0.10 sec 67N-2 Time Delay

1604 67N-1 PICKUP 67 DirectionalPhase/GroundOvercurrent

0.05..35.00 A; ∞ 0.20 A 67N-1 Pickup

1605 67N-1 DELAY 67 DirectionalPhase/GroundOvercurrent

0.00..60.00 sec; ∞ 0.50 sec 67N-1 Time Delay

1607 67N-TOC PICKUP 67 DirectionalPhase/GroundOvercurrent

0.05..4.00 A 0.20 A 67N-TOC Pickup

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A Appendix

1608 67N-TOC T-DIAL 67 DirectionalPhase/GroundOvercurrent

0.05..3.20 sec; ∞ 0.20 sec 67N-TOC Time Dial

1609 67N-TOC T-DIAL 67 DirectionalPhase/GroundOvercurrent

0.50..15.00; ∞ 5.00 67N-TOC Time Dial

1610 67N-TOC RESET 67 DirectionalPhase/GroundOvercurrent

InstantaneousDisk Emulation

Disk Emulation Drop-Out Characteristic

1611 67N-TOC IEC 67 DirectionalPhase/GroundOvercurrent

Normal InverseVery InverseExtremely InverseLong Inverse

Normal Inverse IEC Curve

1612 67N-TOC ANSI 67 DirectionalPhase/GroundOvercurrent

Very InverseInverseShort InverseLong InverseModerately InverseExtremely InverseDefinite Inverse

Very Inverse ANSI Curve

1613A MANUALCLOSE-MODE

67 DirectionalPhase/GroundOvercurrent

67N-2 instantane-ously67N-1 instantane-ously67N-TOC instanta-neouslyInactive

67N-2 instantane-ously

Manual Close Mode

1614A 67N active 67 DirectionalPhase/GroundOvercurrent

alwayswith 79 active

always 67N active

1615A Normal Load 67 DirectionalPhase/GroundOvercurrent

Inductive (135°)Resistive (90°)Capacitive(45°)

Inductive (135°) Normal Load (Torque angleof dir. fct)

1616 67N Direction 67 DirectionalPhase/GroundOvercurrent

ForwardReverse

Forward Ground Direction

1630 M.of PU TD 67 DirectionalPhase/GroundOvercurrent

1.00..20.00 I / Ip; ∞0.01..999.00 TimeDial

Multiples of PU Time-Dial

1631 I/IEp Rf T/TEp 67 DirectionalPhase/GroundOvercurrent

0.05..0.95 I / Ip; ∞0.01..999.00 TimeDial

67N TOC

1701 COLDLOAD PIK-KUP

Cold Load Pik-kup

OFFON

OFF Cold-Load-Pickup Function

1702 Start Condition Cold Load Pik-kup

No CurrentBreaker Contact79M Auto Reclo-sing ready

No Current Start Condition

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A.8 Settings

1703 CB Open Time Cold Load Pik-kup

0..21600 sec 3600 sec Circuit Breaker OPEN Time

1704 Active Time Cold Load Pik-kup

1..21600 sec 3600 sec Active Time

1705 Stop Time Cold Load Pik-kup

1..600 sec; ∞ 600 sec Stop Time

1801 50c-2 PICKUP Cold Load Pik-kup

0.10..35.00 A; ∞ 10.00 A 50c-2 Pickup

1802 50c-2 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.00 sec 50c-2 Time Delay

1803 50c-1 PICKUP Cold Load Pik-kup

0.10..35.00 A; ∞ 2.00 A 50c-1 Pickup

1804 50c-1 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.30 sec 50c-1 Time Delay

1805 51c PICKUP Cold Load Pik-kup

0.10..4.00 A; ∞ 1.50 A 51c Pickup

1806 51c TIME DIAL Cold Load Pik-kup

0.05..3.20 sec; ∞ 0.50 sec 51c Time dial

1807 51c TIME DIAL Cold Load Pik-kup

0.50..15.00; ∞ 5.00 51c Time dial

1901 50Nc-2 PICKUP Cold Load Pik-kup

0.05..35.00 A; ∞ 7.00 A 50Nc-2 Pickup

1902 50Nc-2 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.00 sec 50Nc-2 Time Delay

1903 50Nc-1 PICKUP Cold Load Pik-kup

0.05..35.00 A; ∞ 1.50 A 50Nc-1 Pickup

1904 50Nc-1 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.30 sec 50Nc-1 Time Delay

1905 51Nc PICKUP Cold Load Pik-kup

0.10..4.00 A; ∞ 1.00 A 51Nc Pickup

1906 51Nc T-DIAL Cold Load Pik-kup

0.05..3.20 sec; ∞ 0.50 sec 51Nc Time Dial

1907 51Nc T-DIAL Cold Load Pik-kup

0.50..15.00; ∞ 5.00 51Nc Time Dial

2001 67c-2 PICKUP Cold Load Pik-kup

0.10..35.00 A; ∞ 10.00 A 67c-2 Pickup

2002 67c-2 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.00 sec 67c-2 Time Delay

2003 67c-1 PICKUP Cold Load Pik-kup

0.10..35.00 A; ∞ 2.00 A 67c-1 Pickup

2004 67c-1 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.30 sec 67c-1 Time Delay

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

2005 67c-TOC PICKUP Cold Load Pik-kup

0.10..4.00 A; ∞ 1.50 A 67c Pickup

2006 67c-TOC T-DIAL Cold Load Pik-kup

0.05..3.20 sec; ∞ 0.50 sec 67c Time Dial

2007 67c-TOC T-DIAL Cold Load Pik-kup

0.50..15.00; ∞ 5.00 67c Time Dial

2101 50Nc-2 PICKUP Cold Load Pik-kup

0.05..35.00 A; ∞ 7.00 A 50Nc-2 Pickup

2102 67Nc-2 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.00 sec 67Nc-2 Time Delay

2103 67Nc-1 PICKUP Cold Load Pik-kup

0.05..35.00 A; ∞ 1.50 A 67Nc-1 Pickup

2104 67Nc-1 DELAY Cold Load Pik-kup

0.00..60.00 sec; ∞ 0.30 sec 67Nc-1 Time Delay

2105 67Nc-TOC PICKUP Cold Load Pik-kup

0.05..4.00 A; ∞ 1.00 A 67Nc-TOC Pickup

2106 67Nc-TOC T-DIAL Cold Load Pik-kup

0.05..3.20 sec; ∞ 0.50 sec 67Nc-TOC Time Dial

2107 67Nc-TOC T-DIAL Cold Load Pik-kup

0.50..15.00; ∞ 5.00 67Nc-TOC Time Dial

2201 INRUSH REST. 50/51 Phase/Ground Over-current

OFFON

OFF Inrush Restraint

2202 2nd HARMONIC 50/51 Phase/Ground Over-current

10..45 % 15 % 2nd. harmonic in % of fun-damental

2203 CROSS BLOCK 50/51 Phase/Ground Over-current

NOYES

NO Cross Block

2204 CROSS BLKTIMER

50/51 Phase/Ground Over-current

0.00..180.00 sec 0.00 sec Cross Block Time

2205 I Max 50/51 Phase/Ground Over-current

0.30..25.00 A 7.50 A Maximum Current forInrush Restraint

3101 Sens. Gnd Fault 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

OFFONAlarm Only

OFF (Sensitive) Ground Fault

3102 CT Err. I1 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.001..1.600 A 0.050 A Current I1 for CT AngleError

3102 CT Err. I1 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.05..35.00 A 1.00 A Current I1 for CT AngleError

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A.8 Settings

3103 CT Err. F1 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.0..5.0 ° 0.0 ° CT Angle Error at I1

3104 CT Err. I2 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.001..1.600 A 1.000 A Current I2 for CT AngleError

3104 CT Err. I2 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.05..35.00 A 10.00 A Current I2 for CT AngleError

3105 CT Err. F2 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.0..5.0 ° 0.0 ° CT Angle Error at I2

3106 VPH MIN 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

10..100 V 40 V L-Gnd Voltage of FaultedPhase Vph Min

3107 VPH MAX 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

10..100 V 75 V L-Gnd Voltage of Unfaul-ted Phase Vph Max

3109 64-1 VGND 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

1.8..130.0 V 40.0 V 64-1 Ground DisplacementVoltage

3110 64-1 VGND 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

10.0..225.0 V 70.0 V 64-1 Ground DisplacementVoltage

3111 T-DELAY Pickup 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.04..320.00 sec; ∞ 1.00 sec Time-DELAY Pickup

3112 64-1 DELAY 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.10..40000.00 sec;∞

10.00 sec 64-1 Time Delay

3113 50Ns-2 PICKUP 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.001..1.500 A 0.300 A 50Ns-2 Pickup

3113 50Ns-2 PICKUP 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.05..35.00 A 10.00 A 50Ns-2 Pickup

3114 50Ns-2 DELAY 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.00..320.00 sec; ∞ 1.00 sec 50Ns-2 Time Delay

3115 67Ns-2 DIRECT. 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

ForwardReverseNon-Directional

Forward 67Ns-2 Direction

3117 50Ns-1 PICKUP 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.001..1.500 A 0.100 A 50Ns-1 Pickup

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

3117 50Ns-1 PICKUP 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.05..35.00 A 2.00 A 50Ns-1 Pickup

3118 50Ns-1 DELAY 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.00..320.00 sec; ∞ 2.00 sec 50Ns-1 Time delay

3119 51Ns PICKUP 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.001..1.400 A 0.100 A 51Ns Pickup

3119 51Ns PICKUP 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.05..4.00 A 1.00 A 51Ns Pickup

3120 51Ns TIME DIAL 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.10..4.00 sec; ∞ 1.00 sec 51Ns Time Dial

3122 67Ns-1 DIRECT. 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

ForwardReverseNon-Directional

Forward 67Ns-1 Direction

3123 RELEASEDIRECT.

64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.001..1.200 A 0.010 A Release directional ele-ment

3123 RELEASEDIRECT.

64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0.05..30.00 A 0.50 A Release directional ele-ment

3124 PHI CORRECTION 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

-45.0..45.0 ° 0.0 ° Correction Angle for Dir.Determination

3125 MEAS. METHOD 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

COS PhiSIN phi

COS Phi Measurement method forDirection

3126 RESET DELAY 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

0..60 sec 1 sec Reset Delay

3130 PU CRITERIA 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

Vgnd OR INsVgnd AND INs

Vgnd OR INs Sensitive Ground FaultPICKUP criteria

3131 M.of PU TD 64, 50Ns, 51Ns,67Ns (Sensi-tive) Gnd Flt

1.00..20.00 Multipleof Pickup; ∞0.01..999.00 TimeDial

Multiples of PU Time-Dial

3301 INTERM.EF IntermittentEarth Fault

OFFON

OFF Intermittent earth fault pro-tection

3302 Iie> IntermittentEarth Fault

0.05..35.00 A 1.00 A Pick-up value of interm. E/Fstage

3302 Iie> IntermittentEarth Fault

0.05..35.00 A 1.00 A Pick-up value of interm. E/Fstage

Addr. Setting Title Function Setting Options Default Setting Comments

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A.8 Settings

3302 Iie> IntermittentEarth Fault

0.050..1.500 A 1.000 A Pick-up value of interm. E/Fstage

3303 T-det.ext. IntermittentEarth Fault

0.00..10.00 sec 0.10 sec Detection extension time

3304 T-sum det. IntermittentEarth Fault

0.00..100.00 sec 20.00 sec Sum of detection times

3305 T-reset IntermittentEarth Fault

1..600 sec 300 sec Reset time

3306 Nos.det. IntermittentEarth Fault

2..10 3 No. of det. for start of int. E/F prot

4001 FCT 46 46 NegativeSequence(Time Overcur-rent)

OFFON

OFF 46 Negative Sequence Pro-tection

4002 46-1 PICKUP 46 NegativeSequence(Time Overcur-rent)

0.10..3.00 A 0.10 A 46-1 Pickup

4003 46-1 DELAY 46 NegativeSequence(Time Overcur-rent)

0.00..60.00 sec; ∞ 1.50 sec 46-1 Time Delay

4004 46-2 PICKUP 46 NegativeSequence(Time Overcur-rent)

0.10..3.00 A 0.50 A 46-2 Pickup

4005 46-2 DELAY 46 NegativeSequence(Time Overcur-rent)

0.00..60.00 sec; ∞ 1.50 sec 46-2 Time Delay

4006 46 IEC CURVE 46 NegativeSequence(Time Overcur-rent)

Normal InverseVery InverseExtremely Inverse

Extremely Inverse IEC Curve

4007 46 ANSI CURVE 46 NegativeSequence(Time Overcur-rent)

Extremely InverseInverseModerately InverseVery Inverse

Extremely Inverse ANSI Curve

4008 46-TOC PICKUP 46 NegativeSequence(Time Overcur-rent)

0.10..2.00 A 0.90 A 46-TOC Pickup

4009 46-TOC TIMEDIAL 46 NegativeSequence(Time Overcur-rent)

0.50..15.00; ∞ 5.00 46-TOC Time Dial

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

4010 46-TOC TIMEDIAL 46 NegativeSequence(Time Overcur-rent)

0.05..3.20 sec; ∞ 0.50 sec 46-TOC Time Dial

4011 46-TOC RESET 46 NegativeSequence(Time Overcur-rent)

InstantaneousDisk Emulation

Instantaneous 46-TOC Drop Out

4101 FCT 48/66 48/66 Motor(Startup Moni-tor / Counter)

OFFON

OFF 48 / 66 Motor (StartupMonitor/Counter)

4102 STARTUP CUR-RENT

48/66 Motor(Startup Moni-tor / Counter)

1.00..16.00 A 5.00 A Startup Current

4103 STARTUP TIME 48/66 Motor(Startup Moni-tor / Counter)

1.0..180.0 sec 10.0 sec Startup Time

4104 LOCK ROTORTIME

48/66 Motor(Startup Moni-tor / Counter)

0.5..120.0 sec; ∞ 2.0 sec Permissible Locked RotorTime

4201 FCT 49 49 ThermalOverload

OFFONAlarm Only

OFF 49 Thermal overload pro-tection

4202 49 K-FACTOR 49 ThermalOverload

0.10..4.00 1.10 49 K-Factor

4203 TIME CONSTANT 49 ThermalOverload

1.0..999.9 min 100.0 min Time Constant

4204 49 Θ ALARM 49 ThermalOverload

50..100 % 90 % 49 Thermal Alarm Stage

4205 I ALARM 49 ThermalOverload

0.10..4.00 A 1.00 A Current Overload AlarmSetpoint

4207A Kτ-FACTOR 49 ThermalOverload

1.0..10.0 1.0 Kt-FACTOR when motorstops

4208A T EMERGENCY 49 ThermalOverload

10..15000 sec 100 sec Emergency time

4209 49 TEMP. RISE I 49 ThermalOverload

40..200 °C 100 °C 49 Temperature rise atrated sec. curr.

4210 49 TEMP. RISE I 49 ThermalOverload

104..392 °F 212 °F 49 Temperature rise atrated sec. curr.

4301 FCT 66 48/66 Motor(Startup Moni-tor / Counter)

OFFON

OFF 66 Startup Counter forMotors

4302 IStart/IMOTnom 48/66 Motor(Startup Moni-tor / Counter)

3.0..10.0 4.9 I Start / I Motor nominal

Addr. Setting Title Function Setting Options Default Setting Comments

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A.8 Settings

4303 T START MAX 48/66 Motor(Startup Moni-tor / Counter)

3..320 sec 10 sec Maximum Permissible Star-ting Time

4304 T Equal 48/66 Motor(Startup Moni-tor / Counter)

0.0..320.0 min 1.0 min Temperature EqualizatonTime

4305 I MOTOR NOMI-NAL

48/66 Motor(Startup Moni-tor / Counter)

0.20..1.20 A 1.00 A Rated Motor Current

4306 MAX.WARMSTARTS

48/66 Motor(Startup Moni-tor / Counter)

1..4 2 Maximum Number of WarmStarts

4307 #COLD-#WARM 48/66 Motor(Startup Moni-tor / Counter)

1..2 1 Number of Cold Starts -Warm Starts

4308 Kτ at STOP 48/66 Motor(Startup Moni-tor / Counter)

0.2..100.0 5.0 Extension of Time Constantat Stop

4309 Kτ at RUNNING 48/66 Motor(Startup Moni-tor / Counter)

0.2..100.0 2.0 Extension of Time Constantat Running

4310 T MIN. INHIBIT 48/66 Motor(Startup Moni-tor / Counter)

0.2..120.0 min 6.0 min Minimum Restart InhibitTime

5001 FCT 59 27/59 Under/Over Voltage

OFFONAlarm Only

OFF 59 Overvoltage Protection

5002 59-1 PICKUP 27/59 Under/Over Voltage

40..260 V 110 V 59-1 Pickup

5003 59-1 PICKUP 27/59 Under/Over Voltage

40..130 V 110 V 59-1 Pickup

5004 59-1 DELAY 27/59 Under/Over Voltage

0.00..100.00 sec; ∞ 0.50 sec 59-1 Time Delay

5005 59-2 PICKUP 27/59 Under/Over Voltage

40..260 V 120 V 59-2 Pickup

5006 59-2 PICKUP 27/59 Under/Over Voltage

40..130 V 120 V 59-2 Pickup

5007 59-2 DELAY 27/59 Under/Over Voltage

0.00..100.00 sec; ∞ 0.50 sec 59-2 Time Delay

5101 FCT 27 27/59 Under/Over Voltage

OFFONAlarm Only

OFF 27 Undervoltage Protection

5102 27-1 PICKUP 27/59 Under/Over Voltage

10..210 V 75 V 27-1 Pickup

Addr. Setting Title Function Setting Options Default Setting Comments

5217SJ62/63/64 ManualC53000-G1140-C147–1

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A Appendix

5103 27-1 PICKUP 27/59 Under/Over Voltage

10..120 V 75 V 27-1 Pickup

5105A 27-1 DOUT RATIO 27/59 Under/Over Voltage

1.05..3.00 1.20 27-1 Drop out Ratio

5106 27-1 DELAY 27/59 Under/Over Voltage

0.00..100.00 sec; ∞ 1.50 sec 27-1 Time Delay

5110 27-2 PICKUP 27/59 Under/Over Voltage

10..210 V 70 V 27-2 Pickup

5111 27-2 PICKUP 27/59 Under/Over Voltage

10..120 V 70 V 27-2 Pickup

5112 27-2 DELAY 27/59 Under/Over Voltage

0.00..100.00 sec; ∞ 0.50 sec 27-2 Time Delay

5120A CURRENTSUPERV.

27/59 Under/Over Voltage

OFFON

ON Current Supervision

5301 FUSE FAIL MON. MeasurementSupervision

ONOFF

OFF Fuse Fail Monitor

5302 FUSE FAIL 3Vo MeasurementSupervision

10..100 V 30 V Zero Sequence Voltage

5303 FUSE FAIL RESID MeasurementSupervision

0.10..1.00 A 0.10 A Residual Current

5401 FCT 81 O/U 81 Over/UnderFrequency

OFFON

OFF 81 Over/Under FrequencyProtection

5402 Vmin 81 Over/UnderFrequency

10..150 V 65 V Minimum required voltagefor operation

5403 81-1 PICKUP 81 Over/UnderFrequency

45.50..54.50 Hz 49.50 Hz 81-1 Pickup

5404 81-1 PICKUP 81 Over/UnderFrequency

55.50..64.50 Hz 59.50 Hz 81-1 Pickup

5405 81-1 DELAY 81 Over/UnderFrequency

0.00..100.00 sec; ∞ 60.00 sec 81-1 Time Delay

5406 81-2 PICKUP 81 Over/UnderFrequency

45.50..54.50 Hz 49.00 Hz 81-2 Pickup

5407 81-2 PICKUP 81 Over/UnderFrequency

55.50..64.50 Hz 59.00 Hz 81-2 Pickup

5408 81-2 DELAY 81 Over/UnderFrequency

0.00..100.00 sec; ∞ 30.00 sec 81-2 Time Delay

5409 81-3 PICKUP 81 Over/UnderFrequency

45.50..54.50 Hz 47.50 Hz 81-3 Pickup

5410 81-3 PICKUP 81 Over/UnderFrequency

55.50..64.50 Hz 57.50 Hz 81-3 Pickup

5411 81-3 DELAY 81 Over/UnderFrequency

0.00..100.00 sec; ∞ 3.00 sec 81-3 Time delay

Addr. Setting Title Function Setting Options Default Setting Comments

522 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.8 Settings

5412 81-4 PICKUP 81 Over/UnderFrequency

45.50..54.50 Hz 51.00 Hz 81-4 Pickup

5413 81-4 PICKUP 81 Over/UnderFrequency

55.50..64.50 Hz 61.00 Hz 81-4 Pickup

5414 81-4 DELAY 81 Over/UnderFrequency

0.00..100.00 sec; ∞ 30.00 sec 81-4 Time delay

6101 Synchronizing SYNC Functiongroup 1

ONOFF

OFF Synchronizing Function

6102 SyncCB SYNC Functiongroup 1

Synchronizable circuitbreaker

6103 Vmin SYNC Functiongroup 1

20..125 V 90 V Minimum voltage limit:Vmin

6104 Vmax SYNC Functiongroup 1

20..140 V 110 V Maximum voltage limit:Vmax

6105 V< SYNC Functiongroup 1

1..60 V 5 V Threshold V1, V2 withoutvoltage

6106 V> SYNC Functiongroup 1

20..140 V 80 V Threshold V1, V2 withvoltage

6107 SYNC V1<V2> SYNC Functiongroup 1

YESNO

NO ON-Command at V1< andV2>

6108 SYNC V1>V2< SYNC Functiongroup 1

YESNO

NO ON-Command at V1> andV2<

6109 SYNC V1<V2< SYNC Functiongroup 1

YESNO

NO ON-Command at V1< andV2>

6110A Direct CO SYNC Functiongroup 1

YESNO

NO Direct ON-Command

6111A TSUP VOLTAGE SYNC Functiongroup 1

0.0..60.0 sec 0.1 sec Supervision time ofV1>;V2> or V1<;V2<

6112 T-SYN. DURATION SYNC Functiongroup 1

0.01..1200.00 sec;∞

30.00 sec Maximum duration of Syn-chronization

6120 T-CB close SYNC Functiongroup 1

0.01..0.60 sec 0.06 sec Closing (operating) time ofCB

6121 Balancing V1/V2 SYNC Functiongroup 1

0.50..2.00 1.00 Balancing factor V1/V2

6122A ANGLE ADJUSTM. SYNC Functiongroup 1

0..360 ° 0 ° Angle adjustment (transfor-mer)

6123 CONNECTIONofV2

SYNC Functiongroup 1

A-GB-GC-GA-BB-CC-A

A-B Connection of V2

6125 VT Vn2, primary SYNC Functiongroup 1

0.10..800.00 kV 12.00 kV VT nominal voltage V2, pri-mary

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

6130 dV ASYN V2>V1 SYNC Functiongroup 1

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2>V1

6131 dV ASYN V2<V1 SYNC Functiongroup 1

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2<V1

6132 df ASYN f2>f1 SYNC Functiongroup 1

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6133 df ASYN f2<f1 SYNC Functiongroup 1

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6140 SYNC PERMIS. SYNC Functiongroup 1

YESNO

YES Switching at synchronousconditions

6141 F SYNCHRON SYNC Functiongroup 1

0.01..0.04 Hz 0.01 Hz Frequency threshold ASYN<--> SYN

6142 dV SYNC V2>V1 SYNC Functiongroup 1

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6143 dV SYNC V2<V1 SYNC Functiongroup 1

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6144 dα SYNC α2> α1 SYNC Functiongroup 1

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6145 dα SYNC α2< α1 SYNC Functiongroup 1

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6146 T SYNC-DELAY SYNC Functiongroup 1

0.00..60.00 sec 0.00 sec Release delay at synchro-nous conditions

6150 dV SYNCHKV2>V1

SYNC Functiongroup 1

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6151 dV SYNCHKV2<V1

SYNC Functiongroup 1

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6152 df SYNCHK f2>f1 SYNC Functiongroup 1

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6153 df SYNCHK f2<f1 SYNC Functiongroup 1

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6154 dα SYNCHKα2>α1

SYNC Functiongroup 1

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6155 dα SYNCHKα2<α1

SYNC Functiongroup 1

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6201 Synchronizing SYNC Functiongroup 2

ONOFF

OFF Synchronizing Function

6202 SyncCB SYNC Functiongroup 2

Synchronizable circuitbreaker

6203 Vmin SYNC Functiongroup 2

20..125 V 90 V Minimum voltage limit:Vmin

6204 Vmax SYNC Functiongroup 2

20..140 V 110 V Maximum voltage limit:Vmax

Addr. Setting Title Function Setting Options Default Setting Comments

524 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.8 Settings

6205 V< SYNC Functiongroup 2

1..60 V 5 V Threshold V1, V2 withoutvoltage

6206 V> SYNC Functiongroup 2

20..140 V 80 V Threshold V1, V2 withvoltage

6207 SYNC V1<V2> SYNC Functiongroup 2

YESNO

NO ON-Command at V1< andV2>

6208 SYNC V1>V2< SYNC Functiongroup 2

YESNO

NO ON-Command at V1> andV2<

6209 SYNC V1<V2< SYNC Functiongroup 2

YESNO

NO ON-Command at V1< andV2>

6210A Direct CO SYNC Functiongroup 2

YESNO

NO Direct ON-Command

6211A TSUP VOLTAGE SYNC Functiongroup 2

0.0..60.0 sec 0.1 sec Supervision time ofV1>;V2> or V1<;V2<

6212 T-SYN. DURATION SYNC Functiongroup 2

0.01..1200.00 sec;∞

30.00 sec Maximum duration of Syn-chronization

6220 T-CB close SYNC Functiongroup 2

0.01..0.60 sec 0.06 sec Closing (operating) time ofCB

6221 Balancing V1/V2 SYNC Functiongroup 2

0.50..2.00 1.00 Balancing factor V1/V2

6222A ANGLE ADJUSTM. SYNC Functiongroup 2

0..360 ° 0 ° Angle adjustment (transfor-mer)

6223 CONNECTIONofV2

SYNC Functiongroup 2

A-GB-GC-GA-BB-CC-A

A-B Connection of V2

6225 VT Vn2, primary SYNC Functiongroup 2

0.10..800.00 kV 12.00 kV VT nominal voltage V2, pri-mary

6230 dV ASYN V2>V1 SYNC Functiongroup 2

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2>V1

6231 dV ASYN V2<V1 SYNC Functiongroup 2

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2<V1

6232 df ASYN f2>f1 SYNC Functiongroup 2

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6233 df ASYN f2<f1 SYNC Functiongroup 2

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6240 SYNC PERMIS. SYNC Functiongroup 2

YESNO

YES Switching at synchronousconditions

6241 F SYNCHRON SYNC Functiongroup 2

0.01..0.04 Hz 0.01 Hz Frequency threshold ASYN<--> SYN

6242 dV SYNC V2>V1 SYNC Functiongroup 2

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

Addr. Setting Title Function Setting Options Default Setting Comments

5257SJ62/63/64 ManualC53000-G1140-C147–1

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A Appendix

6243 dV SYNC V2<V1 SYNC Functiongroup 2

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6244 dα SYNC α2> α1 SYNC Functiongroup 2

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6245 dα SYNC α2< α1 SYNC Functiongroup 2

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6246 T SYNC-DELAY SYNC Functiongroup 2

0.00..60.00 sec 0.00 sec Release delay at synchro-nous conditions

6250 dV SYNCHKV2>V1

SYNC Functiongroup 2

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6251 dV SYNCHKV2<V1

SYNC Functiongroup 2

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6252 df SYNCHK f2>f1 SYNC Functiongroup 2

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6253 df SYNCHK f2<f1 SYNC Functiongroup 2

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6254 dα SYNCHKα2>α1

SYNC Functiongroup 2

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6255 dα SYNCHKα2<α1

SYNC Functiongroup 2

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6301 Synchronizing SYNC Functiongroup 3

ONOFF

OFF Synchronizing Function

6302 SyncCB SYNC Functiongroup 3

Synchronizable circuitbreaker

6303 Vmin SYNC Functiongroup 3

20..125 V 90 V Minimum voltage limit:Vmin

6304 Vmax SYNC Functiongroup 3

20..140 V 110 V Maximum voltage limit:Vmax

6305 V< SYNC Functiongroup 3

1..60 V 5 V Threshold V1, V2 withoutvoltage

6306 V> SYNC Functiongroup 3

20..140 V 80 V Threshold V1, V2 withvoltage

6307 SYNC V1<V2> SYNC Functiongroup 3

YESNO

NO ON-Command at V1< andV2>

6308 SYNC V1>V2< SYNC Functiongroup 3

YESNO

NO ON-Command at V1> andV2<

6309 SYNC V1<V2< SYNC Functiongroup 3

YESNO

NO ON-Command at V1< andV2>

6310A Direct CO SYNC Functiongroup 3

YESNO

NO Direct ON-Command

6311A TSUP VOLTAGE SYNC Functiongroup 3

0.0..60.0 sec 0.1 sec Supervision time ofV1>;V2> or V1<;V2<

Addr. Setting Title Function Setting Options Default Setting Comments

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A.8 Settings

6312 T-SYN. DURATION SYNC Functiongroup 3

0.01..1200.00 sec;∞

30.00 sec Maximum duration of Syn-chronization

6320 T-CB close SYNC Functiongroup 3

0.01..0.60 sec 0.06 sec Closing (operating) time ofCB

6321 Balancing V1/V2 SYNC Functiongroup 3

0.50..2.00 1.00 Balancing factor V1/V2

6322A ANGLE ADJUSTM. SYNC Functiongroup 3

0..360 ° 0 ° Angle adjustment (transfor-mer)

6323 CONNECTIONofV2

SYNC Functiongroup 3

A-GB-GC-GA-BB-CC-A

A-B Connection of V2

6325 VT Vn2, primary SYNC Functiongroup 3

0.10..800.00 kV 12.00 kV VT nominal voltage V2, pri-mary

6330 dV ASYN V2>V1 SYNC Functiongroup 3

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2>V1

6331 dV ASYN V2<V1 SYNC Functiongroup 3

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2<V1

6332 df ASYN f2>f1 SYNC Functiongroup 3

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6333 df ASYN f2<f1 SYNC Functiongroup 3

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6340 SYNC PERMIS. SYNC Functiongroup 3

YESNO

YES Switching at synchronousconditions

6341 F SYNCHRON SYNC Functiongroup 3

0.01..0.04 Hz 0.01 Hz Frequency threshold ASYN<--> SYN

6342 dV SYNC V2>V1 SYNC Functiongroup 3

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6343 dV SYNC V2<V1 SYNC Functiongroup 3

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6344 dα SYNC α2> α1 SYNC Functiongroup 3

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6345 dα SYNC α2< α1 SYNC Functiongroup 3

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6346 T SYNC-DELAY SYNC Functiongroup 3

0.00..60.00 sec 0.00 sec Release delay at synchro-nous conditions

6350 dV SYNCHKV2>V1

SYNC Functiongroup 3

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6351 dV SYNCHKV2<V1

SYNC Functiongroup 3

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6352 df SYNCHK f2>f1 SYNC Functiongroup 3

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

Addr. Setting Title Function Setting Options Default Setting Comments

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A Appendix

6353 df SYNCHK f2<f1 SYNC Functiongroup 3

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6354 dα SYNCHKα2>α1

SYNC Functiongroup 3

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6355 dα SYNCHKα2<α1

SYNC Functiongroup 3

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6401 Synchronizing SYNC Functiongroup 4

ONOFF

OFF Synchronizing Function

6402 SyncCB SYNC Functiongroup 4

Synchronizable circuitbreaker

6403 Vmin SYNC Functiongroup 4

20..125 V 90 V Minimum voltage limit:Vmin

6404 Vmax SYNC Functiongroup 4

20..140 V 110 V Maximum voltage limit:Vmax

6405 V< SYNC Functiongroup 4

1..60 V 5 V Threshold V1, V2 withoutvoltage

6406 V> SYNC Functiongroup 4

20..140 V 80 V Threshold V1, V2 withvoltage

6407 SYNC V1<V2> SYNC Functiongroup 4

YESNO

NO ON-Command at V1< andV2>

6408 SYNC V1>V2< SYNC Functiongroup 4

YESNO

NO ON-Command at V1> andV2<

6409 SYNC V1<V2< SYNC Functiongroup 4

YESNO

NO ON-Command at V1< andV2>

6410A Direct CO SYNC Functiongroup 4

YESNO

NO Direct ON-Command

6411A TSUP VOLTAGE SYNC Functiongroup 4

0.0..60.0 sec 0.1 sec Supervision time ofV1>;V2> or V1<;V2<

6412 T-SYN. DURATION SYNC Functiongroup 4

0.01..1200.00 sec;∞

30.00 sec Maximum duration of Syn-chronization

6420 T-CB close SYNC Functiongroup 4

0.01..0.60 sec 0.06 sec Closing (operating) time ofCB

6421 Balancing V1/V2 SYNC Functiongroup 4

0.50..2.00 1.00 Balancing factor V1/V2

6422A ANGLE ADJUSTM. SYNC Functiongroup 4

0..360 ° 0 ° Angle adjustment (transfor-mer)

6423 CONNECTIONofV2

SYNC Functiongroup 4

A-GB-GC-GA-BB-CC-A

A-B Connection of V2

6425 VT Vn2, primary SYNC Functiongroup 4

0.10..800.00 kV 12.00 kV VT nominal voltage V2, pri-mary

Addr. Setting Title Function Setting Options Default Setting Comments

528 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.8 Settings

6430 dV ASYN V2>V1 SYNC Functiongroup 4

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2>V1

6431 dV ASYN V2<V1 SYNC Functiongroup 4

0.5..40.0 V 2.0 V Maximum voltage diffe-rence V2<V1

6432 df ASYN f2>f1 SYNC Functiongroup 4

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6433 df ASYN f2<f1 SYNC Functiongroup 4

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6440 SYNC PERMIS. SYNC Functiongroup 4

YESNO

YES Switching at synchronousconditions

6441 F SYNCHRON SYNC Functiongroup 4

0.01..0.04 Hz 0.01 Hz Frequency threshold ASYN<--> SYN

6442 dV SYNC V2>V1 SYNC Functiongroup 4

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6443 dV SYNC V2<V1 SYNC Functiongroup 4

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6444 dα SYNC α2> α1 SYNC Functiongroup 4

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6445 dα SYNC α2< α1 SYNC Functiongroup 4

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

6446 T SYNC-DELAY SYNC Functiongroup 4

0.00..60.00 sec 0.00 sec Release delay at synchro-nous conditions

6450 dV SYNCHKV2>V1

SYNC Functiongroup 4

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2>V1

6451 dV SYNCHKV2<V1

SYNC Functiongroup 4

0.5..40.0 V 5.0 V Maximum voltage diffe-rence V2<V1

6452 df SYNCHK f2>f1 SYNC Functiongroup 4

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2>f1

6453 df SYNCHK f2<f1 SYNC Functiongroup 4

0.01..2.00 Hz 0.10 Hz Maximum frequency diffe-rence f2<f1

6454 dα SYNCHKα2>α1

SYNC Functiongroup 4

2..80 ° 10 ° Maximum angle differencealpha2>alpha1

6455 dα SYNCHKα2<α1

SYNC Functiongroup 4

2..80 ° 10 ° Maximum angle differencealpha2<alpha1

7001 FCT 50BF 50BF BreakerFailure

OFFON

OFF 50BF Breaker Failure Pro-tection

7004 Chk BRK CON-TACT

50BF BreakerFailure

OFFON

OFF Check Breaker contacts

7005 TRIP-Timer 50BF BreakerFailure

0.06..60.00 sec; ∞ 0.25 sec TRIP-Timer

7101 FCT 79 79M AutoReclosing

OFFON

OFF 79 Auto-Reclose Function

Addr. Setting Title Function Setting Options Default Setting Comments

5297SJ62/63/64 ManualC53000-G1140-C147–1

Page 544: Manual 7SJ62-63-64 v44

A Appendix

7103 BLOCK MC Dur. 79M AutoReclosing

0.50..320.00 sec; 0 1.00 sec AR blocking duration aftermanual close

7105 TIME RESTRAINT 79M AutoReclosing

0.50..320.00 sec 3.00 sec 79 Auto Reclosing resettime

7108 SAFETY 79 ready 79M AutoReclosing

0.01..320.00 sec 0.50 sec Safety Time until 79 isready

7113 CHECK CB? 79M AutoReclosing

No checkCheck each cycle

No check Check circuit breakerbefore AR?

7114 T-Start MONITOR 79M AutoReclosing

0.01..320.00 sec; ∞ 0.50 sec AR start-signal monitoringtime

7115 CB TIME OUT 79M AutoReclosing

0.10..320.00 sec 3.00 sec Circuit Breaker (CB) Super-vision Time

7116 Max. DEAD EXT. 79M AutoReclosing

0.50..1800.00 sec;∞

100.00 sec Maximum dead time exten-sion

7117 T-ACTION 79M AutoReclosing

0.01..320.00 sec; ∞ 0.20 sec Action time

7127 DEADTIME 1: PH 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 1: Phase Fault

7128 DEADTIME 1: G 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 1: Ground Fault

7129 DEADTIME 2: PH 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 2: Phase Fault

7130 DEADTIME 2: G 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 2: Ground Fault

7131 DEADTIME 3: PH 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 3: Phase Fault

7132 DEADTIME 3: G 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 3: Ground Fault

7133 DEADTIME 4: PH 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 4: Phase Fault

7134 DEADTIME 4: G 79M AutoReclosing

0.01..320.00 sec 0.50 sec Dead Time 4: Ground Fault

7135 # OF RECL. GND 79M AutoReclosing

0..9 1 Number of ReclosingCycles Ground

7136 # OF RECL. PH 79M AutoReclosing

0..9 1 Number of ReclosingCycles Phase

7137 Cmd.via control 79M AutoReclosing

Close command via controldevice

7138 Internal SYNC 79M AutoReclosing

Internal 25 synchronisation

7139 External SYNC 79M AutoReclosing

YESNO

NO External 25 synchronisation

Addr. Setting Title Function Setting Options Default Setting Comments

530 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.8 Settings

7140 ZONESEQ.COORD.

79M AutoReclosing

OFFON

OFF ZSC - Zone sequence coor-dination

7150 50-1 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 50-1

7151 50N-1 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 50N-1

7152 50-2 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 50-2

7153 50N-2 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 50N-2

7154 51 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 51

7155 51N 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 51N

7156 67-1 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 67-1

7157 67N-1 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 67N-1

7158 67-2 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 67-2

7159 67N-2 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 67N-2

7160 67 TOC 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 67 TOC

7161 67N TOC 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 67N TOC

7162 sens Ground Flt 79M AutoReclosing

No influenceStarts 79Stops 79

No influence (Sensitive) Ground Fault

7163 46 79M AutoReclosing

No influenceStarts 79Stops 79

No influence 46

7164 BINARY INPUT 79M AutoReclosing

No influenceStarts 79Stops 79

No influence Binary Input

Addr. Setting Title Function Setting Options Default Setting Comments

5317SJ62/63/64 ManualC53000-G1140-C147–1

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A Appendix

7165 3Pol.PICKUP BLK 79M AutoReclosing

YESNO

NO 3 Pole Pickup blocks 79

7200 bef.1.Cy:50-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50-1

7201 bef.1.Cy:50N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50N-1

7202 bef.1.Cy:50-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50-2

7203 bef.1.Cy:50N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 50N-2

7204 bef.1.Cy:51 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 51

7205 bef.1.Cy:51N 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 51N

7206 bef.1.Cy:67-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67-1

7207 bef.1.Cy:67N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67N-1

7208 bef.1.Cy:67-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67-2

7209 bef.1.Cy:67N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67N-2

7210 bef.1.Cy:67 TOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67 TOC

7211 bef.1.Cy:67NTOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 1. Cycle: 67N TOC

7212 bef.2.Cy:50-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50-1

7213 bef.2.Cy:50N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50N-1

7214 bef.2.Cy:50-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50-2

Addr. Setting Title Function Setting Options Default Setting Comments

532 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 547: Manual 7SJ62-63-64 v44

A.8 Settings

7215 bef.2.Cy:50N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 50N-2

7216 bef.2.Cy:51 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 51

7217 bef.2.Cy:51N 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 51N

7218 bef.2.Cy:67-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67-1

7219 bef.2.Cy:67N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67N-1

7220 bef.2.Cy:67-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67-2

7221 bef.2.Cy:67N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67N-2

7222 bef.2.Cy:67 TOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67 TOC

7223 bef.2.Cy:67NTOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 2. Cycle: 67N TOC

7224 bef.3.Cy:50-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50-1

7225 bef.3.Cy:50N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50N-1

7226 bef.3.Cy:50-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50-2

7227 bef.3.Cy:50N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 50N-2

7228 bef.3.Cy:51 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 51

7229 bef.3.Cy:51N 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 51N

Addr. Setting Title Function Setting Options Default Setting Comments

5337SJ62/63/64 ManualC53000-G1140-C147–1

Page 548: Manual 7SJ62-63-64 v44

A Appendix

7230 bef.3.Cy:67-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67-1

7231 bef.3.Cy:67N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67N-1

7232 bef.3.Cy:67-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67-2

7233 bef.3.Cy:67N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67N-2

7234 bef.3.Cy:67 TOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67 TOC

7235 bef.3.Cy:67NTOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 3. Cycle: 67N TOC

7236 bef.4.Cy:50-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50-1

7237 bef.4.Cy:50N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50N-1

7238 bef.4.Cy:50-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50-2

7239 bef.4.Cy:50N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 50N-2

7240 bef.4.Cy:51 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 51

7241 bef.4.Cy:51N 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 51N

7242 bef.4.Cy:67-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67-1

7243 bef.4.Cy:67N-1 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67N-1

7244 bef.4.Cy:67-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67-2

Addr. Setting Title Function Setting Options Default Setting Comments

534 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 549: Manual 7SJ62-63-64 v44

A.8 Settings

7245 bef.4.Cy:67N-2 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67N-2

7246 bef.4.Cy:67 TOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67 TOC

7247 bef.4.Cy:67NTOC 79M AutoReclosing

Set value, T=Tinstantaneous, T= 0blocked, T= infinite

Set value, T=T before 4. Cycle: 67N TOC

8001 START Fault Locator PickupTRIP

Pickup Start fault locator with

8101 MEASURE.SUPERV

MeasurementSupervision

OFFON

ON Measurement Supervision

8102 BALANCE V-LIMIT MeasurementSupervision

10..100 V 50 V Voltage Threshold forBalance Monitoring

8103 BAL. FACTOR V MeasurementSupervision

0.58..0.90 0.75 Balance Factor for VoltageMonitor

8104 BALANCE I LIMIT MeasurementSupervision

0.10..1.00 A 0.50 A Current Threshold forBalance Monitoring

8105 BAL. FACTOR I MeasurementSupervision

0.10..0.90 0.50 Balance Factor for CurrentMonitor

8106 Σ I THRESHOLD MeasurementSupervision

0.05..2.00 A; ∞ 0.10 A Summated Current Monito-ring Threshold

8107 Σ I FACTOR MeasurementSupervision

0.00..0.95 0.10 Summated Current Monito-ring Factor

8201 FCT 74TC 74TC Trip Cir-cuit Supervision

ONOFF

ON 74TC TRIP Circuit Supervi-sion

8301 DMD Interval Demand Mea-surement Setup

15 Min per., 1 Sub15 Min per., 3 Subs15 Min per., 15Subs30 Min per., 1 Sub.60 Min per., 1 Sub.60 Min per., 10Subs5 Min per., 5 Subs

60 Min per., 1 Sub. Demand Calculation Inter-vals

8302 DMD Sync.Time Demand Mea-surement Setup

On the Hour15 Min. after Hour30 Min. after Hour45 Min. after Hour

On the Hour Demand SynchronizationTime

8311 MinMax cycRESET Min/Max Mea-surement Setup

NOYES

YES Automatic Cyclic ResetFunction

8312 MiMa RESET TIME Min/Max Mea-surement Setup

0..1439 min 0 min MinMax Reset Timer

8313 MiMa RESET-CYCLE

Min/Max Mea-surement Setup

1..365 day(s) 7 day(s) MinMax Reset Cycle Period

Addr. Setting Title Function Setting Options Default Setting Comments

5357SJ62/63/64 ManualC53000-G1140-C147–1

Page 550: Manual 7SJ62-63-64 v44

A Appendix

8314 MinMax-RES.START

Min/Max Mea-surement Setup

1..365 Days 1 Days MinMax Start Reset Cyclein

8315 MeterResolution Energy StandardResolution Factor10Resolution Factor100

Standard Meter resolution

9011A RTD 1 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

Pt 100 Ohm RTD 1: Type

9012A RTD 1 LOCATION RTD-Box OilAmbientWindingBearingOther

Oil RTD 1: Location

9013 RTD 1 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 1: Temperature Stage1 Pickup

9014 RTD 1 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 1: Temperature Stage1 Pickup

9015 RTD 1 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 1: Temperature Stage2 Pickup

9016 RTD 1 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 1: Temperature Stage2 Pickup

9021A RTD 2 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 2: Type

9022A RTD 2 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 2: Location

9023 RTD 2 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 2: Temperature Stage1 Pickup

9024 RTD 2 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 2: Temperature Stage1 Pickup

9025 RTD 2 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 2: Temperature Stage2 Pickup

9026 RTD 2 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 2: Temperature Stage2 Pickup

9031A RTD 3 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 3: Type

Addr. Setting Title Function Setting Options Default Setting Comments

536 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 551: Manual 7SJ62-63-64 v44

A.8 Settings

9032A RTD 3 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 3: Location

9033 RTD 3 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 3: Temperature Stage1 Pickup

9034 RTD 3 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 3: Temperature Stage1 Pickup

9035 RTD 3 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 3: Temperature Stage2 Pickup

9036 RTD 3 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 3: Temperature Stage2 Pickup

9041A RTD 4 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 4: Type

9042A RTD 4 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 4: Location

9043 RTD 4 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 4: Temperature Stage1 Pickup

9044 RTD 4 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 4: Temperature Stage1 Pickup

9045 RTD 4 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 4: Temperature Stage2 Pickup

9046 RTD 4 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 4: Temperature Stage2 Pickup

9051A RTD 5 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 5: Type

9052A RTD 5 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 5: Location

9053 RTD 5 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 5: Temperature Stage1 Pickup

9054 RTD 5 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 5: Temperature Stage1 Pickup

9055 RTD 5 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 5: Temperature Stage2 Pickup

Addr. Setting Title Function Setting Options Default Setting Comments

5377SJ62/63/64 ManualC53000-G1140-C147–1

Page 552: Manual 7SJ62-63-64 v44

A Appendix

9056 RTD 5 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 5: Temperature Stage2 Pickup

9061A RTD 6 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 6: Type

9062A RTD 6 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 6: Location

9063 RTD 6 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 6: Temperature Stage1 Pickup

9064 RTD 6 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 6: Temperature Stage1 Pickup

9065 RTD 6 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 6: Temperature Stage2 Pickup

9066 RTD 6 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 6: Temperature Stage2 Pickup

9071A RTD 7 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 7: Type

9072A RTD 7 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 7: Location

9073 RTD 7 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 7: Temperature Stage1 Pickup

9074 RTD 7 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 7: Temperature Stage1 Pickup

9075 RTD 7 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 7: Temperature Stage2 Pickup

9076 RTD 7 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 7: Temperature Stage2 Pickup

9081A RTD 8 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 8: Type

9082A RTD 8 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 8: Location

9083 RTD 8 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 8: Temperature Stage1 Pickup

Addr. Setting Title Function Setting Options Default Setting Comments

538 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 553: Manual 7SJ62-63-64 v44

A.8 Settings

9084 RTD 8 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 8: Temperature Stage1 Pickup

9085 RTD 8 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 8: Temperature Stage2 Pickup

9086 RTD 8 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 8: Temperature Stage2 Pickup

9091A RTD 9 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD 9: Type

9092A RTD 9 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD 9: Location

9093 RTD 9 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD 9: Temperature Stage1 Pickup

9094 RTD 9 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD 9: Temperature Stage1 Pickup

9095 RTD 9 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD 9: Temperature Stage2 Pickup

9096 RTD 9 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD 9: Temperature Stage2 Pickup

9101A RTD10 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD10: Type

9102A RTD10 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD10: Location

9103 RTD10 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD10: TemperatureStage 1 Pickup

9104 RTD10 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD10: TemperatureStage 1 Pickup

9105 RTD10 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD10: TemperatureStage 2 Pickup

9106 RTD10 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD10: TemperatureStage 2 Pickup

9111A RTD11 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD11: Type

Addr. Setting Title Function Setting Options Default Setting Comments

5397SJ62/63/64 ManualC53000-G1140-C147–1

Page 554: Manual 7SJ62-63-64 v44

A Appendix

9112A RTD11 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD11: Location

9113 RTD11 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD11: TemperatureStage 1 Pickup

9114 RTD11 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD11: TemperatureStage 1 Pickup

9115 RTD11 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD11: TemperatureStage 2 Pickup

9116 RTD11 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD11: TemperatureStage 2 Pickup

9121A RTD12 TYPE RTD-Box not connectedPt 100 OhmNi 120 OhmNi 100 Ohm

not connected RTD12: Type

9122A RTD12 LOCATION RTD-Box OilAmbientWindingBearingOther

Other RTD12: Location

9123 RTD12 STAGE 1 RTD-Box -50..250 °C; ∞ 100 °C RTD12: TemperatureStage 1 Pickup

9124 RTD12 STAGE 1 RTD-Box -58..482 °F; ∞ 212 °F RTD12: TemperatureStage 1 Pickup

9125 RTD12 STAGE 2 RTD-Box -50..250 °C; ∞ 120 °C RTD12: TemperatureStage 2 Pickup

9126 RTD12 STAGE 2 RTD-Box -58..482 °F; ∞ 248 °F RTD12: TemperatureStage 2 Pickup

Addr. Setting Title Function Setting Options Default Setting Comments

540 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 555: Manual 7SJ62-63-64 v44

A.9 Overview of the masking features of the user defined information

A.9 Overview of the masking features of the user defined information

Type of Information Source Destination CFC Task level

Bin

ary

Inp

uts

Fu

nct

ion

Key

s

CF

C

Bin

ary

Ou

tpu

ts

LE

D

CF

C

Mea

sure

men

t

PL

C1

(slo

w)

PL

C(f

ast)

Inte

rlo

ckin

g

• Annunciation:Single Point

– SP_Ev Single Point Indication Event – – – – – – – – – –

– SP Single Point Indication ON/OFF X – X X X X – X X –

– SP Single Point Indication Open/Close X – X X X X – X X –

Double Point

– DP Double Point Indication (Breaker indication “00” =not valid/transmitted as “3”)

X – X – – X X1) X X X2)

– DP_I Double Point Indication (Breaker indication “00” =intermediate/transmitted as “0”)

X – X – – X X1) X X X2)

Output Slow

– OUT Output Indication Event – – – – – – – – – –

– OUT Output Indication ON/OFF – – X X X X X1) X X X2)

– OUT Output Indication Open/Close – – X X X X X1) X X X2)

Output Fast

– OUT Protection ON/OFF – – X X X X – X X X2)

– OUT Protection Open/Close – – X X X X – X X X2)

Tagging

– IntSP_ Ev Internal Single Point Indication Event – – – – – – – – – –

– IntSP Internal Single Point Indication ON/OFF – X X X X X X1) X X X2)

– IntSP Internal Single Point Indication Open/Close – X X X X X X1) X X X2)

– IntDP Internal Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

– – X – – X X1) X X X2)

– IntDP_I Internal Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

– – X – – X X1) X X X2)

Tap Changer

– TxTap Transformer Tap Changer X – – – – – – – – –

• Control Commands without feedback:Single Controls

– C_S ON/OFF – – X X – X – X X X

– C_S Open/Close – – X X – X – X X X

1) Only for measurement setpoints (is processed cyclically every 600 ms); do not use for binary inputs.2) Only for commands (is triggered by commands only).

5417SJ62/63/64 ManualC53000-G1140-C147–1

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A Appendix

Single Controls negated

– C_SN ON/OFF – – X X – X – X X X

– C_SN Open/Close – – X X – X – X X X

Double Controls 1 Trip 1 Close

– C_D2 ON/OFF – – X X – X – X X X

– C_D2 Open/Close – – X X – X – X X X

– C_D2 Transformer Tap Changer – – X X – X – X X X

Double Controls 1 Trip 1 Close 1 Common

– C_D3 ON/OFF – – X X – X – X X X

– C_D3 Open/Close – – X X – X – X X X

– C_D3 Transformer Tap Changer – – X X – X – X X X

Double Controls 2 Trip 2 Close

– C_D4 ON/OFF – – X X – X – X X X

– C_D4 Open/Close – – X X – X – X X X

– C_D4 Transformer Tap Changer – – X X – X – X X X

Double Controls 1 Trip 2 Close

– C_D12 ON/OFF – – X X – X – X X X

– C_D12 Open/Close – – X X – X – X X X

– C_D12 Transformer Tap Changer – – X X – X – X X X

Double Controls negated

– C_D2N ON/OFF – – X X – X – X X X

– C_D2N Open/Close – – X X – X – X X X

– C_D2N Transformer Tap Changer – – X X – X – X X X

Type of Information Source Destination CFC Task level

Bin

ary

Inp

uts

Fu

nct

ion

Key

s

CF

C

Bin

ary

Ou

tpu

ts

LE

D

CF

C

Mea

sure

men

t

PL

C1

(slo

w)

PL

C(f

ast)

Inte

rlo

ckin

g1) Only for measurement setpoints (is processed cyclically every 600 ms); do not use for binary inputs.2) Only for commands (is triggered by commands only).

542 7SJ62/63/64 ManualC53000-G1140-C147–1

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A.9 Overview of the masking features of the user defined information

Type of Information Source Destination CFC Task level

Bin

ary

Inp

uts

Fu

nct

ion

Key

s

CF

C

Bin

ary

Ou

tpu

ts

LE

D

CF

C

Mea

sure

men

t

PL

C1

(slo

w)

PL

C(f

ast)

Inte

rlo

ckin

g

• Control Commands with feedback:Single Controls

– CF_S Single Point Indication ON/OFF Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_S Single Point Indication Open/Close Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_S Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

Control – – X X – X – X X X

– DP Feedback X – X – – X – X X X

– CF_S Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

Control – – X X – X – X X X

– DP_I Feedback X – X – – X – X X X

Double Controls 1 Trip 1 Close

– CF_D2 Single Point Indication ON/OFF Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D2 Single Point Indication Open/Close Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D2 Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

Control – – X X – X – X X X

– DP Feedback X – X – – X – X X X

– CF_D2 Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

Control – – X X – X – X X X

– DP_I Feedback X – X – – X – X X X

– CF_D2 Transformer Tap Changer Control – – X X – X – X X X

– TxTap Feedback – – – – – – – – – –

Double Controls 1 Trip 1 Close 1 Common

– CF_D3 Single Point Indication ON/OFF Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D3 Single Point Indication Open/Close Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D3 Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

Control – – X X – X – X X X

– DP Feedback X – X – – X – X X X

– CF_D3 Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

Control – – X X – X – X X X

– DP_I Feedback X – X – – X – X X X

– CF_D3 Transformer Tap Changer Control – – X X – X – X X X

– TxTap Feedback – – – – – – – – – –

Double Controls 2 Trip 2 Close

– CF_D4 Single Point Indication ON/OFF Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D4 Single Point Indication Open/Close Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D4 Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

Control – – X X – X – X X X

– DP Feedback X – X – – X – X X X

5437SJ62/63/64 ManualC53000-G1140-C147–1

Page 558: Manual 7SJ62-63-64 v44

A Appendix

– CF_D4 Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

Control – – X X – X – X X X

– DP_I Feedback X – X – – X – X X X

– CF_D4 Transformer Tap Changer Control – – X X – X – X X X

– TxTap Feedback – – – – – – – – – –

Double Controls 1 Trip 2 Close

– CF_D12 Single Point Indication ON/OFF Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D12 Single Point Indication Open/Close Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D12 Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

Control – – X X – X – X X X

– DP Feedback X – X – – X – X X X

– CF_D12 Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

Control – – X X – X – X X X

– DP_I Feedback X – X – – X – X X X

– CF_D12 Transformer Tap Changer Control – – X X – X – X X X

– TxTap Feedback – – – – – – – – – –

Double Controls 1 Trip 1 Close negated

– CF_D2N Single Point Indication ON/OFF Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D2N Single Point Indication Open/Close Control – – X X – X – X X X

– SP Feedback X – X X X X – X X X

– CF_D2N Double Point Indication (Breaker indication“00” = not valid/transmitted as “3”)

Control – – X X – X – X X X

– DP Feedback X – X – – X – X X X

– CF_D2N Double Point Indication (Breaker indication“00” = intermediate/transmitted as “0”)

Control – – X X – X – X X X

– DP_I Feedback X – X – – X – X X X

– CF_D2N Transformer Tap Changer Control – – X X – X – X X X

– TxTap Feedback – – – – – – – – – –

• Measured Values:– MV Measured Value – – – – – X X – – –

– MVU Measured Value, User Defined – – X – – – X – – –

– LV Limit Value – – – – – X X – – –

– LVU Limit Value, User Defined – – – – – X X – – –

• Metered Values:– MVMV Metered Value of Measured Values – – – – – – – – – –

– PMV Pulse Metered Values X – – – – – – – – –

Type of Information Source Destination CFC Task level

Bin

ary

Inp

uts

Fu

nct

ion

Key

s

CF

C

Bin

ary

Ou

tpu

ts

LE

D

CF

C

Mea

sure

men

t

PL

C1

(slo

w)

PL

C(f

ast)

Inte

rlo

ckin

g

544 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 559: Manual 7SJ62-63-64 v44

A.10 Information List

A.10 Information List

NOTE: The following table lists all data which are available in the maximum complement of the device. Depen-dent on the ordered model, only those data may be present which are valid for the individual version.

The symbol ’ > ’ indicates that the source of the indication is a binary input.

Indications for T103 are always reported ON / OFF if they are subject to general interrogation forIEC 60870-5-103. If not, they are reported only as ON.

New user-defined indications or such newly allocated to IEC 60870-5-103 are set to ON / OFF and subjectedto general interrogation if the information type is not a spontaneous event (".._Ev").

In columns “Event Log”, “Trip Log” and “Ground Fault Log” the following applies:

UPPER CASE: ON/OFF definitely set, not allocatablelower case: preset, allocatable*: not preset, allocatable<blank>: neither preset nor allocatable

O/O – ON / OFF DP – Double Point Indication

OUT – Output Indication C – Command without feedback

SP – Single Point Indication CF – Command with Feedback

IntSP – Internal Single Point Indication MV – Measured Value

SP_Ev

– Spontaneous Event LV – Limit Value

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

00003 >Synchronize Internal Real TimeClock (>Time Synch)

Device, GeneralSettings

SP_Ev LED BI BO 135 48 1 GI

00004 >Trigger Waveform Capture(>Trig.Wave.Cap.)

OscillographicFault Records

SP M LED BI BO 135 49 1 GI

00005 >Reset LED (>Reset LED) Device, GeneralSettings

SP LED BI BO 135 50 1 GI

00007 >Setting Group Select Bit 0 (>SetGroup Bit0)

Change Group SP LED BI BO 135 51 1 GI

00008 >Setting Group Select Bit 1 (>SetGroup Bit1)

Change Group SP LED BI BO 135 52 1 GI

00015 >Test mode (>Test mode) Device, GeneralSettings

SP LED BI BO 135 53 1 GI

5457SJ62/63/64 ManualC53000-G1140-C147–1

Page 560: Manual 7SJ62-63-64 v44

A Appendix

00016 >Stop data transmission(>DataStop)

Device, GeneralSettings

SP LED BI BO 135 54 1 GI

00051 Device is Operational and Protec-ting (Device OK)

Device, GeneralSettings

OUT ONOFF

LED BO 135 81 1 GI

00052 At Least 1 Protection Funct. isActive (ProtActive)

Device, GeneralSettings

IntSP ONOFF

LED BO 160 18 1 GI

00055 Reset Device (Reset Device) Device, GeneralSettings

OUT ON

00056 Initial Start of Device (Initial Start) Device, GeneralSettings

OUT ON LED BO 160 5 1

00060 Reset LED (Reset LED) Device, GeneralSettings

OUT_Ev ON LED BO 160 19 1

00067 Resume (Resume) Device, GeneralSettings

OUT on * LED BO

00068 Clock Synchronization Error (ClockSyncError)

Device, GeneralSettings

OUT onoff

LED BO

00069 Daylight Saving Time (DayLightS-avTime)

Device, GeneralSettings

OUT ONOFF

LED BO

00070 Setting calculation is running (Set-tings Calc.)

Device, GeneralSettings

OUT ONOFF

LED BO 160 22 1 GI

00071 Settings Check (Settings Check) Device, GeneralSettings

OUT LED BO

00072 Level-2 change (Level-2 change) Device, GeneralSettings

OUT ONOFF

LED BO

00073 Local setting change (Localchange)

Device, GeneralSettings

OUT

00110 Event lost (Event Lost) Device, GeneralSettings

OUT_Ev ON LED BO 135 130 1

00113 Flag Lost (Flag Lost) Device, GeneralSettings

OUT ON M LED BO 135 136 1 GI

00125 Chatter ON (Chatter ON) Device, GeneralSettings

OUT ONOFF

LED BO 135 145 1 GI

00126 Protection ON/OFF (via systemport) (ProtON/OFF)

Power SystemData 2

IntSP ONOFF

LED BO

00127 79 ON/OFF (via system port) (79ON/OFF)

79M Auto Reclo-sing

IntSP ONOFF

LED BO

00140 Error with a summary alarm (ErrorSum Alarm)

Device, GeneralSettings

OUT ONOFF

LED BO 160 47 1 GI

00144 Error 5V (Error 5V) Device, GeneralSettings

OUT ONOFF

LED BO

00145 Error 0V (Error 0V) Device, GeneralSettings

OUT ONOFF

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

546 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 561: Manual 7SJ62-63-64 v44

A.10 Information List

00146 Error -5V (Error -5V) Device, GeneralSettings

OUT ONOFF

LED BO

00147 Error Power Supply (Error Pwr-Supply)

Device, GeneralSettings

OUT ONOFF

LED BO

00160 Alarm Summary Event (Alarm SumEvent)

Device, GeneralSettings

OUT ONOFF

LED BO 160 46 1 GI

00161 Failure: General Current Supervi-sion (Fail I Superv.)

MeasurementSupervision

OUT ONOFF

LED BO 160 32 1 GI

00162 Failure: Current Summation(Failure Σ I)

MeasurementSupervision

OUT ONOFF

LED BO 135 182 1 GI

00163 Failure: Current Balance (Fail Ibalance)

MeasurementSupervision

OUT ONOFF

LED BO 135 183 1 GI

00167 Failure: Voltage Balance (Fail Vbalance)

MeasurementSupervision

OUT ONOFF

LED BO 135 186 1 GI

00171 Failure: Phase Sequence (Fail Ph.Seq.)

MeasurementSupervision

OUT ONOFF

LED BO 160 35 1 GI

00175 Failure: Phase Sequence Current(Fail Ph. Seq. I)

MeasurementSupervision

OUT ONOFF

LED BO 135 191 1 GI

00176 Failure: Phase Sequence Voltage(Fail Ph. Seq. V)

MeasurementSupervision

OUT ONOFF

LED BO 135 192 1 GI

00177 Failure: Battery empty (Fail Bat-tery)

Device, GeneralSettings

OUT ONOFF

LED BO

00178 I/O-Board Error (I/O-Board error) Device, GeneralSettings

OUT ONOFF

LED BO

00183 Error Board 1 (Error Board 1) Device, GeneralSettings

OUT ONOFF

LED BO

00184 Error Board 2 (Error Board 2) Device, GeneralSettings

OUT ONOFF

LED BO

00185 Error Board 3 (Error Board 3) Device, GeneralSettings

OUT ONOFF

LED BO

00186 Error Board 4 (Error Board 4) Device, GeneralSettings

OUT ONOFF

LED BO

00187 Error Board 5 (Error Board 5) Device, GeneralSettings

OUT ONOFF

LED BO

00188 Error Board 6 (Error Board 6) Device, GeneralSettings

OUT ONOFF

LED BO

00189 Error Board 7 (Error Board 7) Device, GeneralSettings

OUT ONOFF

LED BO

00197 Measurement Supervision is swit-ched OFF (MeasSup OFF)

MeasurementSupervision

OUT ONOFF

LED BO 135 197 1 GI

00203 Waveform data deleted (Wave.deleted)

OscillographicFault Records

OUT_Ev ON LED BO 135 203 1

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5477SJ62/63/64 ManualC53000-G1140-C147–1

Page 562: Manual 7SJ62-63-64 v44

A Appendix

00264 Failure: RTD-Box 1 (Fail: RTD-Box1)

RTD-Box OUT ONOFF

* LED BO

00267 Failure: RTD-Box 2 (Fail: RTD-Box2)

RTD-Box OUT ONOFF

* LED BO

00268 Supervision Pressure(Superv.Pressure)

Measurement OUT onoff

LED BO

00269 Supervision Temperature(Superv.Temp.)

Measurement OUT onoff

LED BO

00270 Set Point Pressure< (SP. Pres-sure<)

Set Points (Mea-sured Values)

OUT onoff

LED BO

00271 Set Point Temp> (SP. Temp>) Set Points (Mea-sured Values)

OUT onoff

LED BO

00272 Set Point Operating Hours (SP. OpHours>)

Set Points (Stati-stic)

OUT onoff

LED BO 135 229 1 GI

00273 Set Point Phase A dmd> (SP. I Admd>)

Set Points (Mea-sured Values)

OUT onoff

LED BO 135 230 1 GI

00274 Set Point Phase B dmd> (SP. I Bdmd>)

Set Points (Mea-sured Values)

OUT onoff

LED BO 135 234 1 GI

00275 Set Point Phase C dmd> (SP. I Cdmd>)

Set Points (Mea-sured Values)

OUT onoff

LED BO 135 235 1 GI

00276 Set Point positive sequenceI1dmd> (SP. I1dmd>)

Set Points (Mea-sured Values)

OUT onoff

LED BO 135 236 1 GI

00277 Set Point |Pdmd|> (SP. |Pdmd|>) Set Points (Mea-sured Values)

OUT onoff

LED BO 135 237 1 GI

00278 Set Point |Qdmd|> (SP. |Qdmd|>) Set Points (Mea-sured Values)

OUT onoff

LED BO 135 238 1 GI

00279 Set Point |Sdmd|> (SP. |Sdmd|>) Set Points (Mea-sured Values)

OUT onoff

LED BO 135 239 1 GI

00284 Set Point 37-1 Undercurrent alarm(SP. 37-1 alarm)

Set Points (Mea-sured Values)

OUT onoff

LED BO 135 244 1 GI

00285 Set Point 55 Power factor alarm(SP. PF(55)alarm)

Set Points (Mea-sured Values)

OUT onoff

LED BO 135 245 1 GI

00301 Power System fault (Pow.Sys.Flt.) Device, GeneralSettings

OUT ONOFF

ONOFF

135 231 2 GI

00302 Fault Event (Fault Event) Device, GeneralSettings

OUT ON 135 232 2 GI

00303 sensitive Ground fault (sens Gndflt)

Device, GeneralSettings

OUT ONOFF

ON 135 233 1 GI

00356 >Manual close signal (>ManualClose)

Power SystemData 2

SP LED BI BO 150 6 1 GI

00395 >I MIN/MAX Buffer Reset (>I Min-Max Reset)

Min/Max Measu-rement Setup

SP ON BI BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

548 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 563: Manual 7SJ62-63-64 v44

A.10 Information List

00396 >I1 MIN/MAX Buffer Reset (>I1MiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00397 >V MIN/MAX Buffer Reset (>VMiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00398 >Vphph MIN/MAX Buffer Reset(>VphphMiMaRes)

Min/Max Measu-rement Setup

SP ON BI BO

00399 >V1 MIN/MAX Buffer Reset (>V1MiMa Reset)

Min/Max Measu-rement Setup

SP ON BI BO

00400 >P MIN/MAX Buffer Reset (>PMiMa Reset)

Min/Max Measu-rement Setup

SP ON BI BO

00401 >S MIN/MAX Buffer Reset (>SMiMa Reset)

Min/Max Measu-rement Setup

SP ON BI BO

00402 >Q MIN/MAX Buffer Reset (>QMiMa Reset)

Min/Max Measu-rement Setup

SP ON BI BO

00403 >Idmd MIN/MAX Buffer Reset(>Idmd MiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00404 >Pdmd MIN/MAX Buffer Reset(>Pdmd MiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00405 >Qdmd MIN/MAX Buffer Reset(>Qdmd MiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00406 >Sdmd MIN/MAX Buffer Reset(>Sdmd MiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00407 >Frq. MIN/MAX Buffer Reset (>FrqMiMa Reset)

Min/Max Measu-rement Setup

SP ON BI BO

00408 >Power Factor MIN/MAX BufferReset (>PF MiMaReset)

Min/Max Measu-rement Setup

SP ON BI BO

00409 >BLOCK Op Counter (>BLOCKOp Count)

Statistics SP onoff

LED BI BO

00412 >Theta MIN/MAX Buffer Reset (>Θ MiMa Reset)

Min/Max Measu-rement Setup

SP ON BI BO

00501 Relay PICKUP (Relay PICKUP) Power SystemData 2

OUT ON M LED BO 150 151 2 GI

00511 Relay GENERAL TRIP command(Relay TRIP)

Power SystemData 2

OUT ON M LED BO 150 161 2 GI

00533 Primary fault current Ia (Ia =) Power SystemData 2

OUT ONOFF

150 177 4

00534 Primary fault current Ib (Ib =) Power SystemData 2

OUT ONOFF

150 178 4

00535 Primary fault current Ic (Ic =) Power SystemData 2

OUT ONOFF

150 179 4

00561 Manual close signal detected(Man.Clos.Detect)

Power SystemData 2

OUT ONOFF

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5497SJ62/63/64 ManualC53000-G1140-C147–1

Page 564: Manual 7SJ62-63-64 v44

A Appendix

01020 Counter of operating hours(Op.Hours=)

Statistics OUT

01021 Accumulation of interrupted currentPh A (Σ Ia =)

Statistics OUT

01022 Accumulation of interrupted currentPh B (Σ Ib =)

Statistics OUT

01023 Accumulation of interrupted currentPh C (Σ Ic =)

Statistics OUT

01106 >Start Fault Locator (>Start Flt.Loc)

Fault Locator SP ON LED BI BO 151 6 1 GI

01118 Flt Locator: secondary REAC-TANCE (Xsec =)

Fault Locator OUT ONOFF

151 18 4

01119 Flt Locator: Distance to fault (dist=)

Fault Locator OUT ONOFF

151 19 4

01123 Fault Locator Loop AG (FL LoopAG)

Fault Locator OUT ON

01124 Fault Locator Loop BG (FL LoopBG)

Fault Locator OUT ON

01125 Fault Locator Loop CG (FL LoopCG)

Fault Locator OUT ON

01126 Fault Locator Loop AB (FL LoopAB)

Fault Locator OUT ON

01127 Fault Locator Loop BC (FL LoopBC)

Fault Locator OUT ON

01128 Fault Locator Loop CA (FL LoopCA)

Fault Locator OUT ON

01132 Fault location invalid (Flt.Loc.inva-lid)

Fault Locator OUT ON

01201 >BLOCK 64 (>BLOCK 64) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

SP ONOFF

LED BI BO 151 101 1 GI

01202 >BLOCK 50Ns-2 (>BLOCK 50Ns-2)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

SP ONOFF

LED BI BO 151 102 1 GI

01203 >BLOCK 50Ns-1 (>BLOCK 50Ns-1)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

SP ONOFF

LED BI BO 151 103 1 GI

01204 >BLOCK 51Ns (>BLOCK 51Ns) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

SP ONOFF

LED BI BO 151 104 1 GI

01207 >BLOCK 50Ns/67Ns (>BLK 50Ns/67Ns)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

SP ONOFF

LED BI BO 151 107 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

550 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 565: Manual 7SJ62-63-64 v44

A.10 Information List

01211 50Ns/67Ns is OFF (50Ns/67NsOFF)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

LED BO 151 111 1 GI

01212 50Ns/67Ns is ACTIVE (50Ns/67NsACT)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

LED BO 151 112 1 GI

01215 64 displacement voltage pick up(64 Pickup)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

LED BO 151 115 2 GI

01217 64 displacement voltage elementTRIP (64 TRIP)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ON M LED BO 151 117 2 GI

01221 50Ns-2 Pickup (50Ns-2 Pickup) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

LED BO 151 121 2 GI

01223 50Ns-2 TRIP (50Ns-2 TRIP) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ON M LED BO 151 123 2 GI

01224 50Ns-1 Pickup (50Ns-1 Pickup) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

LED BO 151 124 2 GI

01226 50Ns-1 TRIP (50Ns-1 TRIP) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ON M LED BO 151 126 2 GI

01227 51Ns picked up (51Ns Pickup) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

LED BO 151 127 2 GI

01229 51Ns TRIP (51Ns TRIP) 64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ON M LED BO 151 129 2 GI

01230 Sensitive ground fault detectionBLOCKED (Sens. Gnd block)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ONOFF

LED BO 151 130 1 GI

01272 Sensitive Ground fault picked up inPh A (Sens. Gnd Ph A)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ON ON LED BO 160 48 1 GI

01273 Sensitive Ground fault picked up inPh B (Sens. Gnd Ph B)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ON ON LED BO 160 49 1 GI

01274 Sensitive Ground fault picked up inPh C (Sens. Gnd Ph C)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ON ON LED BO 160 50 1 GI

01276 Sensitive Gnd fault in forwarddirection (SensGnd Forward)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ON ON LED BO 160 51 1 GI

01277 Sensitive Gnd fault in reversedirection (SensGnd Reverse)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ON ON LED BO 160 52 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5517SJ62/63/64 ManualC53000-G1140-C147–1

Page 566: Manual 7SJ62-63-64 v44

A Appendix

01278 Sensitive Gnd fault direction unde-fined (SensGnd undef.)

64, 50Ns, 51Ns,67Ns (Sensitive)Gnd Flt

OUT ONOFF

ON ON LED BO 151 178 1 GI

01403 >BLOCK 50BF (>BLOCK 50BF) 50BF BreakerFailure

SP ONOFF

LED BI BO 166 103 1 GI

01431 >50BF initiated externally (>50BFext SRC)

50BF BreakerFailure

SP ONOFF

LED BI BO 166 104 1 GI

01451 50BF is switched OFF (50BF OFF) 50BF BreakerFailure

OUT ONOFF

LED BO 166 151 1 GI

01452 50BF is BLOCKED (50BF BLOCK) 50BF BreakerFailure

OUT ONOFF

ONOFF

LED BO 166 152 1 GI

01453 50BF is ACTIVE (50BF ACTIVE) 50BF BreakerFailure

OUT ONOFF

LED BO 166 153 1 GI

01456 50BF (internal) PICKUP (50BF intPikkup)

50BF BreakerFailure

OUT ONOFF

LED BO 166 156 2 GI

01457 50BF (external) PICKUP (50BF extPickup)

50BF BreakerFailure

OUT ONOFF

LED BO 166 157 2 GI

01471 50BF TRIP (50BF TRIP) 50BF BreakerFailure

OUT ON M LED BO 160 85 2

01480 50BF (internal) TRIP (50BF intTRIP)

50BF BreakerFailure

OUT ON LED BO 166 180 2 GI

01481 50BF (external) TRIP (50BF extTRIP)

50BF BreakerFailure

OUT ON LED BO 166 181 2 GI

01503 >BLOCK 49 Overload Protection(>BLOCK 49 O/L)

49 Thermal Over-load

SP LED BI BO 167 3 1 GI

01507 >Emergency start of motors(>EmergencyStart)

49 Thermal Over-load

SP ONOFF

LED BI BO 167 7 1 GI

01511 49 Overload Protection is OFF (49O / L OFF)

49 Thermal Over-load

OUT ONOFF

LED BO 167 11 1 GI

01512 49 Overload Protection is BLOK-KED (49 O/L BLOCK)

49 Thermal Over-load

OUT ONOFF

ONOFF

LED BO 167 12 1 GI

01513 49 Overload Protection is ACTIVE(49 O/L ACTIVE)

49 Thermal Over-load

OUT ONOFF

LED BO 167 13 1 GI

01515 49 Overload Current Alarm (Ialarm) (49 O/L I Alarm)

49 Thermal Over-load

OUT ONOFF

LED BO 167 15 1 GI

01516 49 Overload Alarm! Near ThermalTrip (49 O/L Θ Alarm)

49 Thermal Over-load

OUT ONOFF

LED BO 167 16 1 GI

01517 49 Winding Overload (49 WindingO/L)

49 Thermal Over-load

OUT ONOFF

LED BO 167 17 1 GI

01521 49 Thermal Overload TRIP (49 ThO/L TRIP)

49 Thermal Over-load

OUT ON M LED BO 167 21 2 GI

01580 >49 Reset of Thermal OverloadImage (>RES 49 Image)

49 Thermal Over-load

SP ONOFF

LED BI BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

552 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 567: Manual 7SJ62-63-64 v44

A.10 Information List

01581 49 Thermal Overload Image reset(49 Image res.)

49 Thermal Over-load

OUT ONOFF

LED BO

01704 >BLOCK 50/51 (>BLK 50/51) 50/51 Phase/Ground Overcur-rent

SP LED BI BO

01714 >BLOCK 50N/51N (>BLK 50N/51N)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01721 >BLOCK 50-2 (>BLOCK 50-2) 50/51 Phase/Ground Overcur-rent

SP LED BI BO 60 1 1 GI

01722 >BLOCK 50-1 (>BLOCK 50-1) 50/51 Phase/Ground Overcur-rent

SP LED BI BO 60 2 1 GI

01723 >BLOCK 51 (>BLOCK 51) 50/51 Phase/Ground Overcur-rent

SP LED BI BO 60 3 1 GI

01724 >BLOCK 50N-2 (>BLOCK 50N-2) 50/51 Phase/Ground Overcur-rent

SP LED BI BO 60 4 1 GI

01725 >BLOCK 50N-1 (>BLOCK 50N-1) 50/51 Phase/Ground Overcur-rent

SP LED BI BO 60 5 1 GI

01726 >BLOCK 51N (>BLOCK 51N) 50/51 Phase/Ground Overcur-rent

SP LED BI BO 60 6 1 GI

01730 >BLOCK Cold-Load-Pickup(>BLOCK CLP)

Cold Load Pickup SP LED BI BO

01731 >BLOCK Cold-Load-Pickup stoptimer (>BLK CLP stpTim)

Cold Load Pickup SP ONOFF

LED BI BO 60 243 1 GI

01732 >ACTIVATE Cold-Load-Pickup(>ACTIVATE CLP)

Cold Load Pickup SP ONOFF

LED BI BO

01751 50/51 O/C switched OFF (50/51PH OFF)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 21 1 GI

01752 50/51 O/C is BLOCKED (50/51 PHBLK)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 22 1 GI

01753 50/51 O/C is ACTIVE (50/51 PHACT)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 23 1 GI

01756 50N/51N is OFF (50N/51N OFF) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 26 1 GI

01757 50N/51N is BLOCKED (50N/51NBLK)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 27 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5537SJ62/63/64 ManualC53000-G1140-C147–1

Page 568: Manual 7SJ62-63-64 v44

A Appendix

01758 50N/51N is ACTIVE (50N/51NACT)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 28 1 GI

01761 50(N)/51(N) O/C PICKUP (50(N)/51(N) PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

M LED BO 160 84 2 GI

01762 50/51 Phase A picked up (50/51Ph A PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

M LED BO 160 64 2 GI

01763 50/51 Phase B picked up (50/51Ph B PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

M LED BO 160 65 2 GI

01764 50/51 Phase C picked up (50/51Ph C PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

M LED BO 160 66 2 GI

01765 50N/51N picked up (50N/51NPickedup)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

M LED BO 160 67 2 GI

01791 50(N)/51(N) TRIP (50(N)/51(N)TRIP)

50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 160 68 2

01800 50-2 picked up (50-2 picked up) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 75 2 GI

01804 50-2 Time Out (50-2 TimeOut) 50/51 Phase/Ground Overcur-rent

OUT LED BO 60 49 2 GI

01805 50-2 TRIP (50-2 TRIP) 50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 160 91 2

01810 50-1 picked up (50-1 picked up) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 76 2 GI

01814 50-1 Time Out (50-1 TimeOut) 50/51 Phase/Ground Overcur-rent

OUT LED BO 60 53 2 GI

01815 50/51 I> TRIP (50/51 TRIP) 50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 160 90 2

01820 51 picked up (51 picked up) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 77 2 GI

01824 51 Time Out (51 Time Out) 50/51 Phase/Ground Overcur-rent

OUT LED BO 60 57 2 GI

01825 51 TRIP (51 TRIP) 50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 60 58 2 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

554 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 569: Manual 7SJ62-63-64 v44

A.10 Information List

01831 50N-2 picked up (50N-2 picked up) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 59 2 GI

01832 50N-2 Time Out (50N-2 TimeOut) 50/51 Phase/Ground Overcur-rent

OUT LED BO 60 60 2 GI

01833 50N-2 TRIP (50N-2 TRIP) 50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 160 93 2

01834 50N-1 picked up (50N-1 picked up) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 62 2 GI

01835 50N-1 Time Out (50N-1 TimeOut) 50/51 Phase/Ground Overcur-rent

OUT LED BO 60 63 2 GI

01836 50N-1 TRIP (50N-1 TRIP) 50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 160 92 2

01837 51N picked up (51N picked up) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 64 2 GI

01838 51N Time Out (51N TimeOut) 50/51 Phase/Ground Overcur-rent

OUT LED BO 60 65 2 GI

01839 51N TRIP (51N TRIP) 50/51 Phase/Ground Overcur-rent

OUT ON M LED BO 60 66 2 GI

01840 Phase A trip blocked by inrushdetection (PhA InrushBlk)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 101 2 GI

01841 Phase B trip blocked by inrushdetection (PhB InrushBlk)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 102 2 GI

01842 Phase C trip blocked by inrushdetection (PhC InrushBlk)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 103 2 GI

01843 Cross blk: PhX blocked PhY(INRUSH X-BLK)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 104 2 GI

01851 50-1 BLOCKED (50-1 BLOCKED) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 105 1 GI

01852 50-2 BLOCKED (50-2 BLOCKED) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 106 1 GI

01853 50N-1 BLOCKED (50N-1 BLOK-KED)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 107 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5557SJ62/63/64 ManualC53000-G1140-C147–1

Page 570: Manual 7SJ62-63-64 v44

A Appendix

01854 50N-2 BLOCKED (50N-2 BLOK-KED)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 108 1 GI

01855 51 BLOCKED (51 BLOCKED) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 109 1 GI

01856 51N BLOCKED (51N BLOCKED) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 110 1 GI

01910 >50-2 instantaneously(>INSTANT. 50-2)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01911 50-2 instantaneously (50-2INSTANT.)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO

01912 >50-1 instantaneously(>INSTANT. 50-1)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01913 50-1 instantaneously (50-1INSTANT.)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO

01914 >51 instantaneously (>INSTANT.51)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01915 51 instantaneously (51 INSTANT.) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO

01916 >50N-2 instantaneously(>INSTANT. 50N-2)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01917 50N-2 instantaneously (50N-2INSTANT.)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO

01918 >50N-1 instantaneously(>INSTANT. 50N-1)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01919 50N-1 instantaneously (50N-1INSTANT.)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO

01983 >51N instantaneously (>INSTANT.51N)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

01984 51N instantaneously (51NINSTANT.)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO

01994 Cold-Load-Pickup switched OFF(CLP OFF)

Cold Load Pickup OUT ONOFF

LED BO 60 244 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

556 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 571: Manual 7SJ62-63-64 v44

A.10 Information List

01995 Cold-Load-Pickup is BLOCKED(CLP BLOCKED)

Cold Load Pickup OUT ONOFF

ONOFF

LED BO 60 245 1 GI

01996 Cold-Load-Pickup is RUNNING(CLP running)

Cold Load Pickup OUT ONOFF

LED BO 60 246 1 GI

01997 Dynamic settings are ACTIVE(Dyn set. ACTIVE)

Cold Load Pickup OUT ONOFF

LED BO 60 247 1 GI

02604 >BLOCK 67/67-TOC (>BLK 67/67-TOC)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

02614 >BLOCK 67N/67N-TOC (>BLK67N/67NTOC)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

02615 >BLOCK 67-2 (>BLOCK 67-2) 67 DirectionalPhase/GroundOvercurrent

SP LED BI BO 63 73 1 GI

02616 >BLOCK 67N-2 (>BLOCK 67N-2) 67 DirectionalPhase/GroundOvercurrent

SP LED BI BO 63 74 1 GI

02621 >BLOCK 67-1 (>BLOCK 67-1) 67 DirectionalPhase/GroundOvercurrent

SP LED BI BO 63 1 1 GI

02622 >BLOCK 67-TOC (>BLOCK 67-TOC)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO 63 2 1 GI

02623 >BLOCK 67N-1 (>BLOCK 67N-1) 67 DirectionalPhase/GroundOvercurrent

SP LED BI BO 63 3 1 GI

02624 >BLOCK 67N-TOC (>BLOCK 67N-TOC)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO 63 4 1 GI

02628 Phase A forward (Phase A for-ward)

67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 81 1 GI

02629 Phase B forward (Phase B for-ward)

67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 82 1 GI

02630 Phase C forward (Phase C for-ward)

67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 83 1 GI

02632 Phase A reverse (Phase Areverse)

67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 84 1 GI

02633 Phase B reverse (Phase Breverse)

67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 85 1 GI

02634 Phase C reverse (Phase Creverse)

67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 86 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5577SJ62/63/64 ManualC53000-G1140-C147–1

Page 572: Manual 7SJ62-63-64 v44

A Appendix

02635 Ground forward (Ground forward) 67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 87 1 GI

02636 Ground reverse (Ground reverse) 67 DirectionalPhase/GroundOvercurrent

OUT ON LED BO 63 88 1 GI

02637 67-1 is BLOCKED (67-1 BLOK-KED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 91 1 GI

02642 67-2 picked up (67-2 picked up) 67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 67 2 GI

02646 67N-2 picked up (67N-2 picked up) 67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 62 2 GI

02647 67-2 Time Out (67-2 Time Out) 67 DirectionalPhase/GroundOvercurrent

OUT LED BO 63 71 2 GI

02648 67N-2 Time Out (67N-2 Time Out) 67 DirectionalPhase/GroundOvercurrent

OUT LED BO 63 63 2 GI

02649 67-2 TRIP (67-2 TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 72 2 GI

02651 67/67-TOC switched OFF (67/67-TOC OFF)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 10 1 GI

02652 67/67-TOC is BLOCKED (67BLOKKED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 11 1 GI

02653 67/67-TOC is ACTIVE (67ACTIVE)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 12 1 GI

02655 67-2 is BLOCKED (67-2 BLOK-KED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 92 1 GI

02656 67N/67N-TOC switched OFF (67NOFF)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 13 1 GI

02657 67N/67N-TOC is BLOCKED (67NBLOCKED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 14 1 GI

02658 67N/67N-TOC is ACTIVE (67NACTIVE)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 15 1 GI

02659 67N-1 is BLOCKED (67N-1 BLOK-KED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 93 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

558 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 573: Manual 7SJ62-63-64 v44

A.10 Information List

02660 67-1 picked up (67-1 picked up) 67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 20 2 GI

02664 67-1 Time Out (67-1 Time Out) 67 DirectionalPhase/GroundOvercurrent

OUT LED BO 63 24 2 GI

02665 67-1 TRIP (67-1 TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 25 2 GI

02668 67N-2 is BLOCKED (67N-2 BLOK-KED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 94 1 GI

02669 67-TOC is BLOCKED (67-TOCBLOKKED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 95 1 GI

02670 67-TOC picked up (67-TOC picke-dup)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 30 2 GI

02674 67-TOC Time Out (67-TOC TimeOut)

67 DirectionalPhase/GroundOvercurrent

OUT LED BO 63 34 2 GI

02675 67-TOC TRIP (67-TOC TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 35 2 GI

02677 67N-TOC is BLOCKED (67N-TOCBLOCKED)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO 63 96 1 GI

02679 67-2 TRIP (67N-2 TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 64 2 GI

02681 67N-1 picked up (67N-1 picked up) 67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 41 2 GI

02682 67N-1 Time Out (67N-1 Time Out) 67 DirectionalPhase/GroundOvercurrent

OUT LED BO 63 42 2 GI

02683 67N-1 TRIP (67N-1 TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 43 2 GI

02684 67N-TOC picked up (67N-TOCPik-kedup)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 44 2 GI

02685 67N-TOC Time Out (67N-TOCTimeOut)

67 DirectionalPhase/GroundOvercurrent

OUT LED BO 63 45 2 GI

02686 67N-TOC TRIP (67N-TOC TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 46 2 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5597SJ62/63/64 ManualC53000-G1140-C147–1

Page 574: Manual 7SJ62-63-64 v44

A Appendix

02691 67/67N picked up (67/67N picke-dup)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

M LED BO 63 50 2 GI

02692 67/67-TOC Phase A picked up (67A picked up)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 51 2 GI

02693 67/67-TOC Phase B picked up (67B picked up)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 52 2 GI

02694 67/67-TOC Phase C picked up (67C picked up)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 53 2 GI

02695 67N/67N-TOC picked up (67N pik-ked up)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

LED BO 63 54 2 GI

02696 67/67N TRIP (67/67N TRIP) 67 DirectionalPhase/GroundOvercurrent

OUT ON M LED BO 63 55 2 GI

02701 >79 ON (>79 ON) 79M Auto Reclo-sing

SP ONOFF

LED BI BO 40 1 1 GI

02702 >79 OFF (>79 OFF) 79M Auto Reclo-sing

SP ONOFF

LED BI BO 40 2 1 GI

02703 >BLOCK 79 (>BLOCK 79) 79M Auto Reclo-sing

SP ONOFF

LED BI BO 40 3 1 GI

02711 >79 External start of internal A/R(>79 Start)

79M Auto Reclo-sing

SP ONOFF

LED BI BO

02715 >Start 79 Ground program (>Start79 Gnd)

79M Auto Reclo-sing

SP ON LED BI BO 40 15 1 GI

02716 >Start 79 Phase program (>Start79 Ph)

79M Auto Reclo-sing

SP ON LED BI BO 40 16 1 GI

02720 >Enable 50/67-(N)-2 (override 79blk) (>Enable ANSI#-2)

Power SystemData 2

SP ONOFF

LED BI BO 40 20 1 GI

02722 >Switch zone sequence coordina-tion ON (>ZSC ON)

79M Auto Reclo-sing

SP ONOFF

LED BI BO

02723 >Switch zone sequence coordina-tion OFF (>ZSC OFF)

79M Auto Reclo-sing

SP ONOFF

LED BI BO

02730 >Circuit breaker READY for reclo-sing (>CB Ready)

79M Auto Reclo-sing

SP ONOFF

LED BI BO 40 30 1 GI

02731 >AR: Sync. release from ext.sync.-check (>Sync.release)

79M Auto Reclo-sing

SP ON LED BI BO

02781 79 Auto recloser is switched OFF(79 OFF)

79M Auto Reclo-sing

OUT ON LED BO 40 81 1 GI

02782 79 Auto recloser is switched ON(79 ON)

79M Auto Reclo-sing

IntSP ONOFF

LED BO 160 16 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

560 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 575: Manual 7SJ62-63-64 v44

A.10 Information List

02784 79 Auto recloser is NOT ready (79is NOT ready)

79M Auto Reclo-sing

OUT ONOFF

LED BO 160 130 1 GI

02785 79 - Auto-reclose is dynamicallyBLOCKED (79 DynBlock)

79M Auto Reclo-sing

OUT ONOFF

ON LED BO 40 85 1 GI

02788 79: CB ready monitoring windowexpired (79 T-CBreadyExp)

79M Auto Reclo-sing

OUT ON LED BO

02801 79 - in progress (79 in progress) 79M Auto Reclo-sing

OUT ON LED BO 40 101 1 GI

02808 79: CB open with no trip (79 BLK:CB open)

79M Auto Reclo-sing

OUT ONOFF

LED BO

02809 79: Start-signal monitoring timeexpired (79 T-Start Exp)

79M Auto Reclo-sing

OUT ON LED BO

02810 79: Maximum dead time expired(79 TdeadMax Exp)

79M Auto Reclo-sing

OUT ON LED BO

02823 79: no starter configured (79 nostarter)

79M Auto Reclo-sing

OUT ONOFF

LED BO

02824 79: no cycle configured (79 nocycle)

79M Auto Reclo-sing

OUT ONOFF

LED BO

02827 79: blocking due to trip (79 BLK bytrip)

79M Auto Reclo-sing

OUT ON LED BO

02828 79: blocking due to 3-phase pickup(79 BLK:3ph p.u.)

79M Auto Reclo-sing

OUT ON LED BO

02829 79: action time expired before trip(79 Tact expired)

79M Auto Reclo-sing

OUT ON LED BO

02830 79: max. no. of cycles exceeded(79 Max. No. Cyc)

79M Auto Reclo-sing

OUT ON LED BO

02844 79 1st cycle running (79 1stCyc.run.)

79M Auto Reclo-sing

OUT ON LED BO

02845 79 2nd cycle running (79 2ndCyc.run.)

79M Auto Reclo-sing

OUT ON LED BO

02846 79 3rd cycle running (79 3rdCyc.run.)

79M Auto Reclo-sing

OUT ON LED BO

02847 79 4th or higher cycle running (794thCyc. run.)

79M Auto Reclo-sing

OUT ON LED BO

02851 79 - Close command (79 Close) 79M Auto Reclo-sing

OUT ON M LED BO 160 128 1

02862 79 - cycle successful (79 Suc-cessful)

79M Auto Reclo-sing

OUT ON ON LED BO 40 162 1 GI

02863 79 - Lockout (79 Lockout) 79M Auto Reclo-sing

OUT ON ON LED BO 40 163 2 GI

02865 79: Synchro-check request (79Sync.Request)

79M Auto Reclo-sing

OUT ON LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5617SJ62/63/64 ManualC53000-G1140-C147–1

Page 576: Manual 7SJ62-63-64 v44

A Appendix

02878 79-A/R single phase reclosingsequence (79 L-N Sequence)

79M Auto Reclo-sing

OUT ON LED BO 40 180 2 GI

02879 79-A/R multi-phase reclosingsequence (79 L-L Sequence)

79M Auto Reclo-sing

OUT ON LED BO 40 181 2 GI

02883 Zone Sequencing is active (ZSCactive)

79M Auto Reclo-sing

OUT ONOFF

ON LED BO

02884 Zone sequence coordination swit-ched ON (ZSC ON)

79M Auto Reclo-sing

OUT ON LED BO

02885 Zone sequence coordination swit-ched OFF (ZSC OFF)

79M Auto Reclo-sing

OUT ON LED BO

02889 79 1st cycle zone extensionrelease (79 1.CycZoneRel)

79M Auto Reclo-sing

OUT LED BO

02890 79 2nd cycle zone extensionrelease (79 2.CycZoneRel)

79M Auto Reclo-sing

OUT LED BO

02891 79 3rd cycle zone extensionrelease (79 3.CycZoneRel)

79M Auto Reclo-sing

OUT LED BO

02892 79 4th cycle zone extensionrelease (79 4.CycZoneRel)

79M Auto Reclo-sing

OUT LED BO

02896 No. of 1st AR-cycle CLOSE com-mands,3pole (79 #Close1./3p=)

Statistics OUT

02898 No. of higher AR-cycle CLOSEcommands,3p (79 #Close2./3p=)

Statistics OUT

02899 79: Close request to ControlFunction (79 CloseRequest)

79M Auto Reclo-sing

OUT ON LED BO

04601 >52-a contact (OPEN, if bkr isopen) (>52-a)

Power SystemData 2

SP LED BI BO

04602 >52-b contact (OPEN, if bkr is clo-sed) (>52-b)

Power SystemData 2

SP LED BI BO

04822 >BLOCK Motor Startup counter(>BLOCK 66)

48/66 Motor(Startup Monitor /Counter)

SP LED BI BO

04823 >Emergency start (>66 emer.start) 48/66 Motor(Startup Monitor /Counter)

SP ONOFF

LED BI BO 168 51 1 GI

04824 66 Motor start protection OFF (66OFF)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO 168 52 1 GI

04825 66 Motor start protection BLOK-KED (66 BLOCKED)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

ONOFF

LED BO 168 53 1 GI

04826 66 Motor start protection ACTIVE(66 ACTIVE)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO 168 54 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

562 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 577: Manual 7SJ62-63-64 v44

A.10 Information List

04827 66 Motor start protection TRIP (66TRIP)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO 168 55 1 GI

04828 >66 Reset thermal memory (>66RM th.repl.)

48/66 Motor(Startup Monitor /Counter)

SP ONOFF

LED BI BO

04829 66 Reset thermal memory (66 RMth.repl.)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO

05143 >BLOCK 46 (>BLOCK 46) 46 NegativeSequence (TimeOvercurrent)

SP LED BI BO 70 126 1 GI

05145 >Reverse Phase Rotation(>Reverse Rot.)

Power SystemData 1

SP ONOFF

LED BI BO

05147 Phase rotation ABC (RotationABC)

Power SystemData 1

OUT ONOFF

LED BO 70 128 1 GI

05148 Phase rotation ACB (RotationACB)

Power SystemData 1

OUT ONOFF

LED BO 70 129 1 GI

05151 46 switched OFF (46 OFF) 46 NegativeSequence (TimeOvercurrent)

OUT ONOFF

LED BO 70 131 1 GI

05152 46 is BLOCKED (46 BLOCKED) 46 NegativeSequence (TimeOvercurrent)

OUT ONOFF

ONOFF

LED BO 70 132 1 GI

05153 46 is ACTIVE (46 ACTIVE) 46 NegativeSequence (TimeOvercurrent)

OUT ONOFF

LED BO 70 133 1 GI

05159 46-2 picked up (46-2 picked up) 46 NegativeSequence (TimeOvercurrent)

OUT ONOFF

LED BO 70 138 2 GI

05165 46-1 picked up (46-1 picked up) 46 NegativeSequence (TimeOvercurrent)

OUT ONOFF

LED BO 70 150 2 GI

05166 46-TOC picked up (46-TOC picke-dup)

46 NegativeSequence (TimeOvercurrent)

OUT ONOFF

LED BO 70 141 2 GI

05170 46 TRIP (46 TRIP) 46 NegativeSequence (TimeOvercurrent)

OUT ON M LED BO 70 149 2 GI

05171 46 Disk emulation picked up (46Dsk pickedup)

46 NegativeSequence (TimeOvercurrent)

OUT LED BO

05203 >BLOCK 81O/U (>BLOCK 81O/U) 81 Over/UnderFrequency

SP ONOFF

LED BI BO 70 176 1 GI

05206 >BLOCK 81-1 (>BLOCK 81-1) 81 Over/UnderFrequency

SP ONOFF

LED BI BO 70 177 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5637SJ62/63/64 ManualC53000-G1140-C147–1

Page 578: Manual 7SJ62-63-64 v44

A Appendix

05207 >BLOCK 81-2 (>BLOCK 81-2) 81 Over/UnderFrequency

SP ONOFF

LED BI BO 70 178 1 GI

05208 >BLOCK 81-3 (>BLOCK 81-3) 81 Over/UnderFrequency

SP ONOFF

LED BI BO 70 179 1 GI

05209 >BLOCK 81-4 (>BLOCK 81-4) 81 Over/UnderFrequency

SP ONOFF

LED BI BO 70 180 1 GI

05211 81 OFF (81 OFF) 81 Over/UnderFrequency

OUT ONOFF

LED BO 70 181 1 GI

05212 81 BLOCKED (81 BLOCKED) 81 Over/UnderFrequency

OUT ONOFF

ONOFF

LED BO 70 182 1 GI

05213 81 ACTIVE (81 ACTIVE) 81 Over/UnderFrequency

OUT ONOFF

LED BO 70 183 1 GI

05214 81 Under Voltage Block (81 UnderV Blk)

81 Over/UnderFrequency

OUT ONOFF

ONOFF

LED BO 70 184 1 GI

05232 81-1 picked up (81-1 picked up) 81 Over/UnderFrequency

OUT ONOFF

LED BO 70 230 2 GI

05233 81-2 picked up (81-2 picked up) 81 Over/UnderFrequency

OUT ONOFF

LED BO 70 231 2 GI

05234 81-3 picked up (81-3 picked up) 81 Over/UnderFrequency

OUT ONOFF

LED BO 70 232 2 GI

05235 81-4 picked up (81-4 picked up) 81 Over/UnderFrequency

OUT ONOFF

LED BO 70 233 2 GI

05236 81-1 TRIP (81-1 TRIP) 81 Over/UnderFrequency

OUT ON M LED BO 70 234 2 GI

05237 81-2 TRIP (81-2 TRIP) 81 Over/UnderFrequency

OUT ON M LED BO 70 235 2 GI

05238 81-3 TRIP (81-3 TRIP) 81 Over/UnderFrequency

OUT ON M LED BO 70 236 2 GI

05239 81-4 TRIP (81-4 TRIP) 81 Over/UnderFrequency

OUT ON M LED BO 70 237 2 GI

06503 >BLOCK 27 undervoltage protec-tion (>BLOCK 27)

27/59 Under/OverVoltage

SP LED BI BO 74 3 1 GI

06505 >27-Switch current supervision ON(>27 I SUPRVSN)

27/59 Under/OverVoltage

SP ONOFF

LED BI BO 74 5 1 GI

06506 >BLOCK 27-1 Undervoltage pro-tection (>BLOCK 27-1)

27/59 Under/OverVoltage

SP ONOFF

LED BI BO 74 6 1 GI

06508 >BLOCK 27-2 Undervoltage pro-tection (>BLOCK 27-2)

27/59 Under/OverVoltage

SP ONOFF

LED BI BO 74 8 1 GI

06509 >Failure: Feeder VT (>FAIL:FEE-DER VT)

MeasurementSupervision

SP ONOFF

LED BI BO 74 9 1 GI

06510 >Failure: Busbar VT (>FAIL: BUSVT)

MeasurementSupervision

SP ONOFF

LED BI BO 74 10 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

564 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 579: Manual 7SJ62-63-64 v44

A.10 Information List

06513 >BLOCK 59-1 overvoltage protec-tion (>BLOCK 59-1)

27/59 Under/OverVoltage

SP LED BI BO 74 13 1 GI

06530 27 Undervoltage protection swit-ched OFF (27 OFF)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 30 1 GI

06531 27 Undervoltage protection isBLOKKED (27 BLOCKED)

27/59 Under/OverVoltage

OUT ONOFF

ONOFF

LED BO 74 31 1 GI

06532 27 Undervoltage protection isACTIVE (27 ACTIVE)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 32 1 GI

06533 27-1 Undervoltage picked up (27-1picked up)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 33 2 GI

06534 27-1 Undervoltage PICKUP w/curr.superv (27-1 PU CS)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 34 2 GI

06537 27-2 Undervoltage picked up (27-2picked up)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 37 2 GI

06538 27-2 Undervoltage PICKUP w/curr.superv (27-2 PU CS)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 38 2 GI

06539 27-1 Undervoltage TRIP (27-1TRIP)

27/59 Under/OverVoltage

OUT ON M LED BO 74 39 2 GI

06540 27-2 Undervoltage TRIP (27-2TRIP)

27/59 Under/OverVoltage

OUT ON M LED BO 74 40 2 GI

06565 59-Overvoltage protection swit-ched OFF (59 OFF)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 65 1 GI

06566 59-Overvoltage protection isBLOKKED (59 BLOCKED)

27/59 Under/OverVoltage

OUT ONOFF

ONOFF

LED BO 74 66 1 GI

06567 59-Overvoltage protection isACTIVE (59 ACTIVE)

27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 67 1 GI

06568 59 picked up (59-1 picked up) 27/59 Under/OverVoltage

OUT ONOFF

LED BO 74 68 2 GI

06570 59 TRIP (59-1 TRIP) 27/59 Under/OverVoltage

OUT ON M LED BO 74 70 2 GI

06571 59-2 Overvoltage V>> picked up(59-2 picked up)

27/59 Under/OverVoltage

OUT ONOFF

LED BO

06573 59-2 Overvoltage V>> TRIP (59-2TRIP)

27/59 Under/OverVoltage

OUT ON LED BO

06575 Voltage Transformer Fuse Failure(VT Fuse Failure)

MeasurementSupervision

OUT ONOFF

LED BO 74 74 1 GI

06801 >BLOCK Startup Supervision(>BLK START-SUP)

48/66 Motor(Startup Monitor /Counter)

SP LED BI BO

06805 >Rotor locked (>Rotor locked) 48/66 Motor(Startup Monitor /Counter)

SP LED BI BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5657SJ62/63/64 ManualC53000-G1140-C147–1

Page 580: Manual 7SJ62-63-64 v44

A Appendix

06811 Startup supervision OFF (START-SUP OFF)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO 169 51 1 GI

06812 Startup supervision is BLOCKED(START-SUP BLK)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

ONOFF

LED BO 169 52 1 GI

06813 Startup supervision is ACTIVE(START-SUP ACT)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO 169 53 1 GI

06821 Startup supervision TRIP (START-SUP TRIP)

48/66 Motor(Startup Monitor /Counter)

OUT ON M LED BO 169 54 2 GI

06822 Rotor locked (Rotor locked) 48/66 Motor(Startup Monitor /Counter)

OUT ON LED BO 169 55 2 GI

06823 Startup supervision Pickup(START-SUP pu)

48/66 Motor(Startup Monitor /Counter)

OUT ONOFF

LED BO 169 56 1 GI

06851 >BLOCK 74TC (>BLOCK 74TC) 74TC Trip CircuitSupervision

SP LED BI BO

06852 >74TC Trip circuit superv.: triprelay (>74TC trip rel.)

74TC Trip CircuitSupervision

SP ONOFF

LED BI BO 170 51 1 GI

06853 >74TC Trip circuit superv.: bkrrelay (>74TC brk rel.)

74TC Trip CircuitSupervision

SP ONOFF

LED BI BO 170 52 1 GI

06861 74TC Trip circuit supervision OFF(74TC OFF)

74TC Trip CircuitSupervision

OUT ONOFF

LED BO 170 53 1 GI

06862 74TC Trip circuit supervision isBLOKKED (74TC BLOCKED)

74TC Trip CircuitSupervision

OUT ONOFF

ONOFF

LED BO 153 16 1 GI

06863 74TC Trip circuit supervision isACTIVE (74TC ACTIVE)

74TC Trip CircuitSupervision

OUT ONOFF

LED BO 153 17 1 GI

06864 74TC blocked. Bin. input is not set(74TC ProgFail)

74TC Trip CircuitSupervision

OUT ONOFF

LED BO 170 54 1 GI

06865 74TC Failure Trip Circuit (FAIL:Trip cir.)

74TC Trip CircuitSupervision

OUT ONOFF

LED BO 170 55 1 GI

06903 >block interm. E/F prot. (>IEFblock)

Intermittent EarthFault

SP LED BI BO 152 1 1 GI

06921 Interm. E/F prot. is switched off(IEF OFF)

Intermittent EarthFault

OUT ONOFF

LED BO 152 10 1 GI

06922 Interm. E/F prot. is blocked (IEFblokked)

Intermittent EarthFault

OUT ONOFF

ONOFF

LED BO 152 11 1 GI

06923 Interm. E/F prot. is active (IEF ena-bled)

Intermittent EarthFault

OUT ONOFF

LED BO 152 12 1 GI

06924 Interm. E/F detection stage Iie>(IIE Fault det)

Intermittent EarthFault

OUT LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

566 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 581: Manual 7SJ62-63-64 v44

A.10 Information List

06925 Interm. E/F stab detection (IIEstab.Flt)

Intermittent EarthFault

OUT LED BO

06926 Interm. E/F detection stage Iie>(IIE Fault det)

Intermittent EarthFault

OUT ON 152 13 2

06927 Interm. E/F detected (Intermitt.EF) Intermittent EarthFault

OUT ONOFF

LED BO 152 14 2 GI

06928 Counter of det. times elapsed (IEFTsum exp.)

Intermittent EarthFault

OUT ON LED BO 152 15 2

06929 Interm. E/F: reset time running(IEF Tres run.)

Intermittent EarthFault

OUT ONOFF

LED BO 152 16 2 GI

06930 Interm. E/F: trip (IEF Trip) Intermittent EarthFault

OUT ON LED BO 152 17 2

06931 Max RMS current value of fault =(Iie/In=)

Intermittent EarthFault

OUT ONOFF

152 18 2

06932 No. of detections by stage Iie>=(Nos.IIE=)

Intermittent EarthFault

OUT ONOFF

152 19 2

07551 50-1 InRush picked up (50-1InRushPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 80 2 GI

07552 50N-1 InRush picked up (50N-1InRushPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 81 2 GI

07553 51 InRush picked up (51 InRus-hPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 82 2 GI

07554 51N InRush picked up (51N InRus-hPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 83 2 GI

07556 InRush OFF (InRush OFF) 50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 92 1 GI

07557 InRush Phase BLOCKED (InRus-hPhBLOCKED)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

ONOFF

LED BO 60 93 1 GI

07558 InRush Ground BLOCKED(InRush Gnd BLK)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 94 1 GI

07559 67-1 InRush picked up (67-1InRushPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 84 2 GI

07560 67N-1 InRush picked up (67N-1InRushPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 85 2 GI

07561 67-TOC InRush picked up (67-TOC InRushPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 86 2 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5677SJ62/63/64 ManualC53000-G1140-C147–1

Page 582: Manual 7SJ62-63-64 v44

A Appendix

07562 67N-TOC InRush picked up (67N-TOCInRushPU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 87 2 GI

07563 >BLOCK InRush Phase (>BLOCKInRushPh)

50/51 Phase/Ground Overcur-rent

SP LED BI BO

07564 Ground InRush picked up (GndInRush PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 88 2 GI

07565 Phase A InRush picked up (IaInRush PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 89 2 GI

07566 Phase B InRush picked up (IbInRush PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 90 2 GI

07567 Phase C InRush picked up (IcInRush PU)

50/51 Phase/Ground Overcur-rent

OUT ONOFF

LED BO 60 91 2 GI

14101 Fail: RTD (broken wire/shorted)(Fail: RTD)

RTD-Box OUT ONOFF

* LED BO

14111 Fail: RTD 1 (broken wire/shorted)(Fail: RTD 1)

RTD-Box OUT ONOFF

* LED BO

14112 RTD 1 Temperature stage 1 pickedup (RTD 1 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14113 RTD 1 Temperature stage 2 pickedup (RTD 1 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14121 Fail: RTD 2 (broken wire/shorted)(Fail: RTD 2)

RTD-Box OUT ONOFF

* LED BO

14122 RTD 2 Temperature stage 1 pickedup (RTD 2 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14123 RTD 2 Temperature stage 2 pickedup (RTD 2 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14131 Fail: RTD 3 (broken wire/shorted)(Fail: RTD 3)

RTD-Box OUT ONOFF

* LED BO

14132 RTD 3 Temperature stage 1 pickedup (RTD 3 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14133 RTD 3 Temperature stage 2 pickedup (RTD 3 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14141 Fail: RTD 4 (broken wire/shorted)(Fail: RTD 4)

RTD-Box OUT ONOFF

* LED BO

14142 RTD 4 Temperature stage 1 pickedup (RTD 4 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14143 RTD 4 Temperature stage 2 pickedup (RTD 4 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

568 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 583: Manual 7SJ62-63-64 v44

A.10 Information List

14151 Fail: RTD 5 (broken wire/shorted)(Fail: RTD 5)

RTD-Box OUT ONOFF

* LED BO

14152 RTD 5 Temperature stage 1 pickedup (RTD 5 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14153 RTD 5 Temperature stage 2 pickedup (RTD 5 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14161 Fail: RTD 6 (broken wire/shorted)(Fail: RTD 6)

RTD-Box OUT ONOFF

* LED BO

14162 RTD 6 Temperature stage 1 pickedup (RTD 6 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14163 RTD 6 Temperature stage 2 pickedup (RTD 6 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14171 Fail: RTD 7 (broken wire/shorted)(Fail: RTD 7)

RTD-Box OUT ONOFF

* LED BO

14172 RTD 7 Temperature stage 1 pickedup (RTD 7 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14173 RTD 7 Temperature stage 2 pickedup (RTD 7 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14181 Fail: RTD 8 (broken wire/shorted)(Fail: RTD 8)

RTD-Box OUT ONOFF

* LED BO

14182 RTD 8 Temperature stage 1 pickedup (RTD 8 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14183 RTD 8 Temperature stage 2 pickedup (RTD 8 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14191 Fail: RTD 9 (broken wire/shorted)(Fail: RTD 9)

RTD-Box OUT ONOFF

* LED BO

14192 RTD 9 Temperature stage 1 pickedup (RTD 9 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14193 RTD 9 Temperature stage 2 pickedup (RTD 9 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14201 Fail: RTD10 (broken wire/shorted)(Fail: RTD10)

RTD-Box OUT ONOFF

* LED BO

14202 RTD10 Temperature stage 1 pik-ked up (RTD10 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14203 RTD10 Temperature stage 2 pik-ked up (RTD10 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14211 Fail: RTD11 (broken wire/shorted)(Fail: RTD11)

RTD-Box OUT ONOFF

* LED BO

14212 RTD11 Temperature stage 1 pik-ked up (RTD11 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14213 RTD11 Temperature stage 2 pik-ked up (RTD11 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5697SJ62/63/64 ManualC53000-G1140-C147–1

Page 584: Manual 7SJ62-63-64 v44

A Appendix

14221 Fail: RTD12 (broken wire/shorted)(Fail: RTD12)

RTD-Box OUT ONOFF

* LED BO

14222 RTD12 Temperature stage 1 pik-ked up (RTD12 St.1 p.up)

RTD-Box OUT ONOFF

* LED BO

14223 RTD12 Temperature stage 2 pik-ked up (RTD12 St.2 p.up)

RTD-Box OUT ONOFF

* LED BO

14501 >67-2 instantaneously(>INSTANT. 67-2)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

14502 67-2 instantaneously (67-2INSTANT.)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO

14503 >67-1 instantaneously(>INSTANT. 67-1)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

14504 67-1 instantaneously (67-1INSTANT.)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO

14505 >67-TOC instantaneously(>INSTANT 67-TOC)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

14506 67-TOC instantaneously (67-TOCINSTANT.)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO

14507 >67N-2 instantaneously(>INSTANT. 67N-2)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

14508 67N-2 instantaneously (67N-2INSTANT.)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO

14509 >67N-1 instantaneously(>INSTANT. 67N-1)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

14510 67N-1 instantaneously (67N-1INSTANT.)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO

14511 >67N-TOC instantaneously(>INST. 67N-TOC)

67 DirectionalPhase/GroundOvercurrent

SP LED BI BO

14512 67N-TOC instantaneously (67N-TOC INSTANT)

67 DirectionalPhase/GroundOvercurrent

OUT ONOFF

ONOFF

LED BO

170.2095 25 alphadiff too large (a2<a1) (25α2<α1)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2095 25 alphadiff too large (a2<a1) (25α2<α1)

SYNC Functiongroup 2

OUT onoff

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

570 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 585: Manual 7SJ62-63-64 v44

A.10 Information List

170.2095 25 alphadiff too large (a2<a1) (25α2<α1)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2095 25 alphadiff too large (a2<a1) (25α2<α1)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2094 25 alphadiff too large (a2>a1) (25α2>α1)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2094 25 alphadiff too large (a2>a1) (25α2>α1)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2094 25 alphadiff too large (a2>a1) (25α2>α1)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2094 25 alphadiff too large (a2>a1) (25α2>α1)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2032 25 Angle difference (alphadiff)okay (25 αdiff ok)

SYNC Functiongroup 1

OUT onoff

LED BO 41 209 1 GI

170.2032 25 Angle difference (alphadiff)okay (25 αdiff ok)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2032 25 Angle difference (alphadiff)okay (25 αdiff ok)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2032 25 Angle difference (alphadiff)okay (25 αdiff ok)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2103 25 CLOSE command is BLOCKED(25 CLOSE BLK)

SYNC Functiongroup 1

OUT onoff

LED BO 41 37 1 GI

170.2103 25 CLOSE command is BLOCKED(25 CLOSE BLK)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2103 25 CLOSE command is BLOCKED(25 CLOSE BLK)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2103 25 CLOSE command is BLOCKED(25 CLOSE BLK)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2029 25 Condition V1<V2< fulfilled (25V1< V2<)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2029 25 Condition V1<V2< fulfilled (25V1< V2<)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2029 25 Condition V1<V2< fulfilled (25V1< V2<)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2029 25 Condition V1<V2< fulfilled (25V1< V2<)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2027 25 Condition V1<V2> fulfilled (25V1< V2>)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2027 25 Condition V1<V2> fulfilled (25V1< V2>)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2027 25 Condition V1<V2> fulfilled (25V1< V2>)

SYNC Functiongroup 3

OUT onoff

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5717SJ62/63/64 ManualC53000-G1140-C147–1

Page 586: Manual 7SJ62-63-64 v44

A Appendix

170.2027 25 Condition V1<V2> fulfilled (25V1< V2>)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2028 25 Condition V1>V2< fulfilled (25V1> V2<)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2028 25 Condition V1>V2< fulfilled (25V1> V2<)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2028 25 Condition V1>V2< fulfilled (25V1> V2<)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2028 25 Condition V1>V2< fulfilled (25V1> V2<)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2093 25 fdiff too large (f2<f1) (25 f2<f1) SYNC Functiongroup 1

OUT onoff

LED BO

170.2093 25 fdiff too large (f2<f1) (25 f2<f1) SYNC Functiongroup 2

OUT onoff

LED BO

170.2093 25 fdiff too large (f2<f1) (25 f2<f1) SYNC Functiongroup 3

OUT onoff

LED BO

170.2093 25 fdiff too large (f2<f1) (25 f2<f1) SYNC Functiongroup 4

OUT onoff

LED BO

170.2092 25 fdiff too large (f2>f1) (25 f2>f1) SYNC Functiongroup 1

OUT onoff

LED BO

170.2092 25 fdiff too large (f2>f1) (25 f2>f1) SYNC Functiongroup 2

OUT onoff

LED BO

170.2092 25 fdiff too large (f2>f1) (25 f2>f1) SYNC Functiongroup 3

OUT onoff

LED BO

170.2092 25 fdiff too large (f2>f1) (25 f2>f1) SYNC Functiongroup 4

OUT onoff

LED BO

170.2031 25 Frequency difference (fdiff)okay (25 fdiff ok)

SYNC Functiongroup 1

OUT onoff

LED BO 41 208 1 GI

170.2031 25 Frequency difference (fdiff)okay (25 fdiff ok)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2031 25 Frequency difference (fdiff)okay (25 fdiff ok)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2031 25 Frequency difference (fdiff)okay (25 fdiff ok)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2034 25 Frequency f1 < fmin permissible(25 f1<<)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2034 25 Frequency f1 < fmin permissible(25 f1<<)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2034 25 Frequency f1 < fmin permissible(25 f1<<)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2034 25 Frequency f1 < fmin permissible(25 f1<<)

SYNC Functiongroup 4

OUT onoff

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

572 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 587: Manual 7SJ62-63-64 v44

A.10 Information List

170.2033 25 Frequency f1 > fmax permissi-ble (25 f1>>)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2033 25 Frequency f1 > fmax permissi-ble (25 f1>>)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2033 25 Frequency f1 > fmax permissi-ble (25 f1>>)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2033 25 Frequency f1 > fmax permissi-ble (25 f1>>)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2036 25 Frequency f2 < fmin permissible(25 f2<<)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2036 25 Frequency f2 < fmin permissible(25 f2<<)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2036 25 Frequency f2 < fmin permissible(25 f2<<)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2036 25 Frequency f2 < fmin permissible(25 f2<<)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2035 25 Frequency f2 > fmax permissi-ble (25 f2>>)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2035 25 Frequency f2 > fmax permissi-ble (25 f2>>)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2035 25 Frequency f2 > fmax permissi-ble (25 f2>>)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2035 25 Frequency f2 > fmax permissi-ble (25 f2>>)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2025 25 Monitoring time exceeded (25MonTimeExc)

SYNC Functiongroup 1

OUT onoff

LED BO 41 205 1 GI

170.2025 25 Monitoring time exceeded (25MonTimeExc)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2025 25 Monitoring time exceeded (25MonTimeExc)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2025 25 Monitoring time exceeded (25MonTimeExc)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2096 25 Multiple selection of func-groups (25 FG-Error)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2096 25 Multiple selection of func-groups (25 FG-Error)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2096 25 Multiple selection of func-groups (25 FG-Error)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2096 25 Multiple selection of func-groups (25 FG-Error)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2097 25 Setting error (25 Set-Error) SYNC Functiongroup 1

OUT onoff

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5737SJ62/63/64 ManualC53000-G1140-C147–1

Page 588: Manual 7SJ62-63-64 v44

A Appendix

170.2097 25 Setting error (25 Set-Error) SYNC Functiongroup 2

OUT onoff

LED BO

170.2097 25 Setting error (25 Set-Error) SYNC Functiongroup 3

OUT onoff

LED BO

170.2097 25 Setting error (25 Set-Error) SYNC Functiongroup 4

OUT onoff

LED BO

170.2007 25 Sync. Measuring request ofControl (25 Measu. req.)

SYNC Functiongroup 1

SP onoff

LED

170.2007 25 Sync. Measuring request ofControl (25 Measu. req.)

SYNC Functiongroup 2

SP onoff

LED

170.2007 25 Sync. Measuring request ofControl (25 Measu. req.)

SYNC Functiongroup 3

SP onoff

LED

170.2007 25 Sync. Measuring request ofControl (25 Measu. req.)

SYNC Functiongroup 4

SP onoff

LED

170.0049 25 Sync. Release of CLOSE Com-mand (25 CloseRelease)

SYNC Functiongroup 1

OUT onoff

LED BO 41 201 1 GI

170.0049 25 Sync. Release of CLOSE Com-mand (25 CloseRelease)

SYNC Functiongroup 2

OUT onoff

LED BO

170.0049 25 Sync. Release of CLOSE Com-mand (25 CloseRelease)

SYNC Functiongroup 3

OUT onoff

LED BO

170.0049 25 Sync. Release of CLOSE Com-mand (25 CloseRelease)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2026 25 Synchronization conditionsokay (25 Synchron)

SYNC Functiongroup 1

OUT onoff

LED BO 41 206 1 GI

170.2026 25 Synchronization conditionsokay (25 Synchron)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2026 25 Synchronization conditionsokay (25 Synchron)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2026 25 Synchronization conditionsokay (25 Synchron)

SYNC Functiongroup 4

OUT onoff

LED BO

170.0050 25 Synchronization Error (25 Sync.Error)

SYNC Functiongroup 1

OUT onoff

LED BO 41 202 1 GI

170.0050 25 Synchronization Error (25 Sync.Error)

SYNC Functiongroup 2

OUT onoff

LED BO

170.0050 25 Synchronization Error (25 Sync.Error)

SYNC Functiongroup 3

OUT onoff

LED BO

170.0050 25 Synchronization Error (25 Sync.Error)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2091 25 Vdiff too large (V2<V1) (25V2<V1)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2091 25 Vdiff too large (V2<V1) (25V2<V1)

SYNC Functiongroup 2

OUT onoff

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

574 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 589: Manual 7SJ62-63-64 v44

A.10 Information List

170.2091 25 Vdiff too large (V2<V1) (25V2<V1)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2091 25 Vdiff too large (V2<V1) (25V2<V1)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2090 25 Vdiff too large (V2>V1) (25V2>V1)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2090 25 Vdiff too large (V2>V1) (25V2>V1)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2090 25 Vdiff too large (V2>V1) (25V2>V1)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2090 25 Vdiff too large (V2>V1) (25V2>V1)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2030 25 Voltage difference (Vdiff) okay(25 Vdiff ok)

SYNC Functiongroup 1

OUT onoff

LED BO 41 207 1 GI

170.2030 25 Voltage difference (Vdiff) okay(25 Vdiff ok)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2030 25 Voltage difference (Vdiff) okay(25 Vdiff ok)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2030 25 Voltage difference (Vdiff) okay(25 Vdiff ok)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2038 25 Voltage V1 < Umin permissible(25 V1<<)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2038 25 Voltage V1 < Umin permissible(25 V1<<)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2038 25 Voltage V1 < Umin permissible(25 V1<<)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2038 25 Voltage V1 < Umin permissible(25 V1<<)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2037 25 Voltage V1 > Umax permissible(25 V1>>)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2037 25 Voltage V1 > Umax permissible(25 V1>>)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2037 25 Voltage V1 > Umax permissible(25 V1>>)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2037 25 Voltage V1 > Umax permissible(25 V1>>)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2040 25 Voltage V2 < Umin permissible(25 V2<<)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2040 25 Voltage V2 < Umin permissible(25 V2<<)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2040 25 Voltage V2 < Umin permissible(25 V2<<)

SYNC Functiongroup 3

OUT onoff

LED BO

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5757SJ62/63/64 ManualC53000-G1140-C147–1

Page 590: Manual 7SJ62-63-64 v44

A Appendix

170.2040 25 Voltage V2 < Umin permissible(25 V2<<)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2039 25 Voltage V2 > Umax permissible(25 V2>>)

SYNC Functiongroup 1

OUT onoff

LED BO

170.2039 25 Voltage V2 > Umax permissible(25 V2>>)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2039 25 Voltage V2 > Umax permissible(25 V2>>)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2039 25 Voltage V2 > Umax permissible(25 V2>>)

SYNC Functiongroup 4

OUT onoff

LED BO

170.0051 25-group 1 is BLOCKED (25-1BLOCK)

SYNC Functiongroup 1

OUT onoff

LED BO 41 204 1 GI

170.2022 25-group 1: measurement in pro-gress (25-1 meas.)

SYNC Functiongroup 1

OUT onoff

LED BO 41 203 1 GI

170.0051 25-group 2 is BLOCKED (25-2BLOCK)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2022 25-group 2: measurement in pro-gress (25-2 meas.)

SYNC Functiongroup 2

OUT onoff

LED BO

170.0051 25-group 3 is BLOCKED (25-3BLOCK)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2022 25-group 3: measurement in pro-gress (25-3 meas.)

SYNC Functiongroup 3

OUT onoff

LED BO

170.0051 25-group 4 is BLOCKED (25-4BLOCK)

SYNC Functiongroup 4

OUT onoff

LED BO

170.2022 25-group 4: measurement in pro-gress (25-4 meas.)

SYNC Functiongroup 4

OUT onoff

LED BO

234.2100 27, 59 blocked via operation (27,59 blk)

27/59 Under/OverVoltage

IntSP ONOFF

LED BO

52 Breaker (52Breaker) Control Device CF_D12 onoff

BO 240 160 1 GI

52 Breaker (52Breaker) Control Device DP onoff

BI CB 240 160 1 GI

170.2009 >25 Direct Command output(>25direct CO)

SYNC Functiongroup 1

SP onoff

LED BI

170.2009 >25 Direct Command output(>25direct CO)

SYNC Functiongroup 2

SP onoff

LED BI

170.2009 >25 Direct Command output(>25direct CO)

SYNC Functiongroup 3

SP onoff

LED BI

170.2009 >25 Direct Command output(>25direct CO)

SYNC Functiongroup 4

SP onoff

LED BI

170.2011 >25 Start of synchronization (>25Start)

SYNC Functiongroup 1

SP onoff

LED BI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

576 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 591: Manual 7SJ62-63-64 v44

A.10 Information List

170.2011 >25 Start of synchronization (>25Start)

SYNC Functiongroup 2

SP onoff

LED BI

170.2011 >25 Start of synchronization (>25Start)

SYNC Functiongroup 3

SP onoff

LED BI

170.2011 >25 Start of synchronization (>25Start)

SYNC Functiongroup 4

SP onoff

LED BI

170.2012 >25 Stop of synchronization (>25Stop)

SYNC Functiongroup 1

SP onoff

LED BI

170.2012 >25 Stop of synchronization (>25Stop)

SYNC Functiongroup 2

SP onoff

LED BI

170.2012 >25 Stop of synchronization (>25Stop)

SYNC Functiongroup 3

SP onoff

LED BI

170.2012 >25 Stop of synchronization (>25Stop)

SYNC Functiongroup 4

SP onoff

LED BI

170.2015 >25 Switch to V1< and V2< (>25V1<V2<)

SYNC Functiongroup 1

SP onoff

LED BI

170.2015 >25 Switch to V1< and V2< (>25V1<V2<)

SYNC Functiongroup 2

SP onoff

LED BI

170.2015 >25 Switch to V1< and V2< (>25V1<V2<)

SYNC Functiongroup 3

SP onoff

LED BI

170.2015 >25 Switch to V1< and V2< (>25V1<V2<)

SYNC Functiongroup 4

SP onoff

LED BI

170.2014 >25 Switch to V1< and V2> (>25V1<V2>)

SYNC Functiongroup 1

SP onoff

LED BI

170.2014 >25 Switch to V1< and V2> (>25V1<V2>)

SYNC Functiongroup 2

SP onoff

LED BI

170.2014 >25 Switch to V1< and V2> (>25V1<V2>)

SYNC Functiongroup 3

SP onoff

LED BI

170.2014 >25 Switch to V1< and V2> (>25V1<V2>)

SYNC Functiongroup 4

SP onoff

LED BI

170.2013 >25 Switch to V1> and V2< (>25V1>V2<)

SYNC Functiongroup 1

SP onoff

LED BI

170.2013 >25 Switch to V1> and V2< (>25V1>V2<)

SYNC Functiongroup 2

SP onoff

LED BI

170.2013 >25 Switch to V1> and V2< (>25V1>V2<)

SYNC Functiongroup 3

SP onoff

LED BI

170.2013 >25 Switch to V1> and V2< (>25V1>V2<)

SYNC Functiongroup 4

SP onoff

LED BI

170.0043 >25 Sync. Measurement Only (>25Measu. Only)

SYNC Functiongroup 1

SP onoff

LED BI

170.0043 >25 Sync. Measurement Only (>25Measu. Only)

SYNC Functiongroup 2

SP onoff

LED BI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5777SJ62/63/64 ManualC53000-G1140-C147–1

Page 592: Manual 7SJ62-63-64 v44

A Appendix

170.0043 >25 Sync. Measurement Only (>25Measu. Only)

SYNC Functiongroup 3

SP onoff

LED BI

170.0043 >25 Sync. Measurement Only (>25Measu. Only)

SYNC Functiongroup 4

SP onoff

LED BI

170.0001 >25-group 1 activate (>25-1 act) SYNC Functiongroup 1

SP onoff

LED BI

170.0001 >25-group 2 activate (>25-2 act) SYNC Functiongroup 2

SP onoff

LED BI

170.0001 >25-group 3 activate (>25-3 act) SYNC Functiongroup 3

SP onoff

LED BI

170.0001 >25-group 4 activate (>25-4 act) SYNC Functiongroup 4

SP onoff

LED BI

>Back Light on (>Light on) Device, GeneralSettings

SP onoff

* LED BI BO

170.2102 >BLOCK 25 CLOSE command(>BLK 25 CLOSE)

SYNC Functiongroup 1

SP onoff

LED BI

170.2102 >BLOCK 25 CLOSE command(>BLK 25 CLOSE)

SYNC Functiongroup 2

SP onoff

LED BI

170.2102 >BLOCK 25 CLOSE command(>BLK 25 CLOSE)

SYNC Functiongroup 3

SP onoff

LED BI

170.2102 >BLOCK 25 CLOSE command(>BLK 25 CLOSE)

SYNC Functiongroup 4

SP onoff

LED BI

170.2008 >BLOCK 25-group 1 (>BLK 25-1) SYNC Functiongroup 1

SP onoff

LED BI

170.2008 >BLOCK 25-group 2 (>BLK 25-2) SYNC Functiongroup 2

SP onoff

LED BI

170.2008 >BLOCK 25-group 3 (>BLK 25-3) SYNC Functiongroup 3

SP onoff

LED BI

170.2008 >BLOCK 25-group 4 (>BLK 25-4) SYNC Functiongroup 4

SP onoff

LED BI

>Cabinet door open (>Door open) Process Data SP onoff

LED BI BO CB 101 1 1 GI

>CB ready Spring is charged (>CBready)

Process Data SP * LED BI BO CB

>CB waiting for Spring charged(>CB wait)

Process Data SP onoff

LED BI BO CB 101 2 1 GI

>Door closed (>DoorClose) Process Data SP * LED BI BO CB

>Error Control Voltage (>ErrCn-trlV)

Process Data SP onoff

LED BI BO CB 240 182 1 GI

>Error Meter (>Err Meter) Process Data SP onoff

LED BI BO CB 240 184 1 GI

>Error Motor Voltage (>Err Mot V) Process Data SP onoff

LED BI BO CB 240 181 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

578 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 593: Manual 7SJ62-63-64 v44

A.10 Information List

>No Voltage (Fuse blown) (>NoVolt.)

Process Data SP ONOFF

LED BI BO CB 160 38 1 GI

>SF6-Loss (>SF6-Loss) Process Data SP onoff

LED BI BO CB 240 183 1 GI

>Transformer Danger (>Tx Dan-ger)

Process Data SP onoff

LED BI BO CB 240 186 1 GI

>Transformer Temperature (>TxTemp.)

Process Data SP onoff

LED BI BO CB 240 185 1 GI

Breaker OPENED (Brk OPENED) Device, GeneralSettings

IntSP * * LED BO

Clock Synchronization (Synch-Clock)

Device, GeneralSettings

IntSP_Ev

Control Authority (Cntrl Auth) Control Authori-zation

DP ONOFF

LED 101 85 1 GI

Control Authority (Cntrl Auth) Control Authori-zation

IntSP ONOFF

LED

Controlmode LOCAL (ModeLO-CAL)

Control Authori-zation

DP ONOFF

LED 101 86 1 GI

Controlmode LOCAL (ModeLO-CAL)

Control Authori-zation

IntSP ONOFF

LED

Controlmode REMOTE (ModeRE-MOTE)

Control Authori-zation

IntSP ONOFF

LED

Disconnect Switch (Disc.Swit.) Control Device CF_D2 onoff

BO 240 161 1 GI

Disconnect Switch (Disc.Swit.) Control Device DP onoff

BI CB 240 161 1 GI

Error FMS FO 1 (Error FMS1) Device, GeneralSettings

OUT onoff

LED BO

Error FMS FO 2 (Error FMS2) Device, GeneralSettings

OUT onoff

LED BO

Error Systeminterface (SysIntErr.) Protocol IntSP onoff

LED BO

Fan ON/OFF (Fan ON/OFF) Control Device CF_D2 onoff

BO 240 175 1 GI

Fan ON/OFF (Fan ON/OFF) Control Device DP onoff

BI CB 240 175 1 GI

Fault Recording Start (FltRecSta) OscillographicFault Records

IntSP ONOFF

LED BO

Feeder GROUNDED (Feeder gnd) Device, GeneralSettings

IntSP * * LED BO

Ground Switch (GndSwit.) Control Device CF_D2 onoff

BO 240 164 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5797SJ62/63/64 ManualC53000-G1140-C147–1

Page 594: Manual 7SJ62-63-64 v44

A Appendix

Ground Switch (GndSwit.) Control Device DP onoff

BI CB 240 164 1 GI

Group A (Group A) Change Group IntSP ONOFF

LED BO 160 23 1 GI

Group B (Group B) Change Group IntSP ONOFF

LED BO 160 24 1 GI

Group C (Group C) Change Group IntSP ONOFF

LED BO 160 25 1 GI

Group D (Group D) Change Group IntSP ONOFF

LED BO 160 26 1 GI

Hardware Test Mode (HWTest-Mod)

Device, GeneralSettings

IntSP ONOFF

LED BO

Interlocking: 52 Close (52 Close) Control Device IntSP

Interlocking: 52 Open (52 Open) Control Device IntSP

Interlocking: Disconnect switchClose (Disc.Close)

Control Device IntSP

Interlocking: Disconnect switchOpen (Disc.Open)

Control Device IntSP

Interlocking: Ground switch Close(GndSw Cl.)

Control Device IntSP

Interlocking: Ground switch Open(GndSw Open)

Control Device IntSP

Q2 Open/Close (Q2 Op/Cl) Control Device CF_D2 onoff

BO 240 162 1 GI

Q2 Open/Close (Q2 Op/Cl) Control Device DP onoff

BI CB 240 162 1 GI

Q9 Open/Close (Q9 Op/Cl) Control Device CF_D2 onoff

BO 240 163 1 GI

Q9 Open/Close (Q9 Op/Cl) Control Device DP onoff

BI CB 240 163 1 GI

Stop data transmission (DataStop) Device, GeneralSettings

IntSP ONOFF

LED BO 160 20 1 GI

170.2101 Sync-group 1 is switched OFF (25-1 OFF)

SYNC Functiongroup 1

OUT onoff

LED BO 41 36 1 GI

170.2101 Sync-group 2 is switched OFF (25-2 OFF)

SYNC Functiongroup 2

OUT onoff

LED BO

170.2101 Sync-group 3 is switched OFF (25-3 OFF)

SYNC Functiongroup 3

OUT onoff

LED BO

170.2101 Sync-group 4 is switched OFF (25-4 OFF)

SYNC Functiongroup 4

OUT onoff

LED BO

Test mode (Test mode) Device, GeneralSettings

IntSP ONOFF

LED BO 160 21 1 GI

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

580 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 595: Manual 7SJ62-63-64 v44

A.10 Information List

Threshold Value 1 (ThreshVal1) Threshold-Switch IntSP onoff

LED BI FK BO CB

Unlock data transmission via BI(UnlockDT)

Control Device IntSP

F.No. Description Function Type ofInfor-

mation

Log-Buffers Configurable in Matrix IEC 60870-5-103

Eve

nt

Lo

gO

n/O

ff

Tri

p(F

ault

)L

og

On

/Off

Gro

un

dF

ault

Lo

gO

n/O

ff

Mar

ked

inO

scill

.Rec

ord

LE

D

Bin

ary

Inp

ut

Fu

nct

ion

Key

Bin

ary

Ou

tpu

t

Ch

atte

rB

lock

ing

Typ

e

Info

rmat

ion

-No

Dat

aU

nit

(AS

DU

)

Gen

eral

Inte

rro

gat

ion

5817SJ62/63/64 ManualC53000-G1140-C147–1

Page 596: Manual 7SJ62-63-64 v44

A Appendix

A.11 Measured Values

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

nct

ion

typ

e

Info

rmat

ion

-No

Co

mp

atib

ility

Dat

aU

nit

(AS

DU

)

Po

siti

on

CF

C

Co

ntr

olD

isp

lay

Def

ault

Dis

pla

y

00601 Ia (Ia =) Measurement 134 137 priv 9 1 CFC CD DD

00602 Ib (Ib =) Measurement 160 145 comp 3 1 CFC CD DD

134 137 priv 9 2

00603 Ic (Ic =) Measurement 134 137 priv 9 3 CFC CD DD

00604 In (In =) Measurement 134 137 priv 9 4 CFC CD DD

00605 I1 (positive sequence) (I1 =) Measurement CFC CD DD

00606 I2 (negative sequence) (I2 =) Measurement CFC CD DD

00621 Va (Va =) Measurement 134 137 priv 9 5 CFC CD DD

00622 Vb (Vb =) Measurement 134 137 priv 9 6 CFC CD DD

00623 Vc (Vc =) Measurement 134 137 priv 9 7 CFC CD DD

00624 Va-b (Va-b=) Measurement 160 145 comp 3 2 CFC CD DD

134 137 priv 9 8

00625 Vb-c (Vb-c=) Measurement 134 137 priv 9 9 CFC CD DD

00626 Vc-a (Vc-a=) Measurement 134 137 priv 9 10 CFC CD DD

00627 VN (VN =) Measurement CFC CD DD

00629 V1 (positive sequence) (V1 =) Measurement CFC CD DD

00630 V2 (negative sequence) (V2 =) Measurement CFC CD DD

00632 Vsync (synchronism) (Vsync =) Measurement CFC CD DD

00641 P (active power) (P =) Measurement 134 137 priv 9 11 CFC CD DD

00642 Q (reactive power) (Q =) Measurement 134 137 priv 9 12 CFC CD DD

00644 Frequency (Freq=) Measurement 134 137 priv 9 13 CFC CD DD

00645 S (apparent power) (S =) Measurement CFC CD DD

00661 Threshold of Restart Inhibit (Θ REST. =) Measurement CFC CD DD

00701 Resistive ground current in isol systems (INsReal)

Measurement 134 137 priv 9 15 CFC CD DD

00702 Reactive ground current in isol systems (INsReac)

Measurement 134 137 priv 9 16 CFC CD DD

00805 Temperature of Rotor (Θ Rotor) Measurement CFC CD DD

00807 Thermal Overload (Θ /Θtrip) Measurement CFC CD DD

00809 Time untill release of reclose-blocking (T rec-lose=)

Measurement CFC CD DD

00830 INs Senstive Ground Fault Current (INs =) Measurement CFC CD DD

582 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 597: Manual 7SJ62-63-64 v44

A.11 Measured Values

00831 3Io (zero sequence) (3Io =) Measurement CFC CD DD

00832 Vo (zero sequence) (Vo =) Measurement CFC CD DD

00833 I1 (positive sequence) Demand (I1 dmd=) Demand Mea-surement Setup

CFC CD DD

00834 Active Power Demand (P dmd =) Demand Mea-surement Setup

CFC CD DD

00835 Reactive Power Demand (Q dmd =) Demand Mea-surement Setup

CFC CD DD

00836 Apparent Power Demand (S dmd =) Demand Mea-surement Setup

CFC CD DD

00837 I A Demand Minimum (IAdmdMin) Min/Max Mea-surement Setup

CFC CD DD

00838 I A Demand Maximum (IAdmdMax) Min/Max Mea-surement Setup

CFC CD DD

00839 I B Demand Minimum (IBdmdMin) Min/Max Mea-surement Setup

CFC CD DD

00840 I B Demand Maximum (IBdmdMax) Min/Max Mea-surement Setup

CFC CD DD

00841 I C Demand Minimum (ICdmdMin) Min/Max Mea-surement Setup

CFC CD DD

00842 I C Demand Maximum (ICdmdMax) Min/Max Mea-surement Setup

CFC CD DD

00843 I1 (positive sequence) Demand Minimum(I1dmdMin)

Min/Max Mea-surement Setup

CFC CD DD

00844 I1 (positive sequence) Demand Maximum(I1dmdMax)

Min/Max Mea-surement Setup

CFC CD DD

00845 Active Power Demand Minimum (PdMin=) Min/Max Mea-surement Setup

CFC CD DD

00846 Active Power Demand Maximum (PdMax=) Min/Max Mea-surement Setup

CFC CD DD

00847 Reactive Power Minimum (QdMin=) Min/Max Mea-surement Setup

CFC CD DD

00848 Reactive Power Maximum (QdMax=) Min/Max Mea-surement Setup

CFC CD DD

00849 Apparent Power Minimum (SdMin=) Min/Max Mea-surement Setup

CFC CD DD

00850 Apparent Power Maximum (SdMax=) Min/Max Mea-surement Setup

CFC CD DD

00851 Ia Min (Ia Min=) Min/Max Mea-surement Setup

CFC CD DD

00852 Ia Max (Ia Max=) Min/Max Mea-surement Setup

CFC CD DD

00853 Ib Min (Ib Min=) Min/Max Mea-surement Setup

CFC CD DD

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

nct

ion

typ

e

Info

rmat

ion

-No

Co

mp

atib

ility

Dat

aU

nit

(AS

DU

)

Po

siti

on

CF

C

Co

ntr

olD

isp

lay

Def

ault

Dis

pla

y

5837SJ62/63/64 ManualC53000-G1140-C147–1

Page 598: Manual 7SJ62-63-64 v44

A Appendix

00854 Ib Max (Ib Max=) Min/Max Mea-surement Setup

CFC CD DD

00855 Ic Min (Ic Min=) Min/Max Mea-surement Setup

CFC CD DD

00856 Ic Max (Ic Max=) Min/Max Mea-surement Setup

CFC CD DD

00857 I1 (positive sequence) Minimum (I1 Min=) Min/Max Mea-surement Setup

CFC CD DD

00858 I1 (positive sequence) Maximum (I1 Max=) Min/Max Mea-surement Setup

CFC CD DD

00859 Va-n Min (Va-nMin=) Min/Max Mea-surement Setup

CFC CD DD

00860 Va-n Max (Va-nMax=) Min/Max Mea-surement Setup

CFC CD DD

00861 Vb-n Min (Vb-nMin=) Min/Max Mea-surement Setup

CFC CD DD

00862 Vb-n Max (Vb-nMax=) Min/Max Mea-surement Setup

CFC CD DD

00863 Vc-n Min (Vc-nMin=) Min/Max Mea-surement Setup

CFC CD DD

00864 Vc-n Max (Vc-nMax=) Min/Max Mea-surement Setup

CFC CD DD

00865 Va-b Min (Va-bMin=) Min/Max Mea-surement Setup

CFC CD DD

00867 Va-b Max (Va-bMax=) Min/Max Mea-surement Setup

CFC CD DD

00868 Vb-c Min (Vb-cMin=) Min/Max Mea-surement Setup

CFC CD DD

00869 Vb-c Max (Vb-cMax=) Min/Max Mea-surement Setup

CFC CD DD

00870 Vc-a Min (Vc-aMin=) Min/Max Mea-surement Setup

CFC CD DD

00871 Vc-a Max (Vc-aMax=) Min/Max Mea-surement Setup

CFC CD DD

00872 V neutral Min (Vn Min =) Min/Max Mea-surement Setup

CFC CD DD

00873 V neutral Max (Vn Max =) Min/Max Mea-surement Setup

CFC CD DD

00874 V1 (positive sequence) Voltage Minimum (V1 Min=)

Min/Max Mea-surement Setup

CFC CD DD

00875 V1 (positive sequence) Voltage Maximum (V1Max =)

Min/Max Mea-surement Setup

CFC CD DD

00876 Active Power Minimum (Pmin=) Min/Max Mea-surement Setup

CFC CD DD

00877 Active Power Maximum (Pmax=) Min/Max Mea-surement Setup

CFC CD DD

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

nct

ion

typ

e

Info

rmat

ion

-No

Co

mp

atib

ility

Dat

aU

nit

(AS

DU

)

Po

siti

on

CF

C

Co

ntr

olD

isp

lay

Def

ault

Dis

pla

y

584 7SJ62/63/64 ManualC53000-G1140-C147–1

Page 599: Manual 7SJ62-63-64 v44

A.11 Measured Values

00878 Reactive Power Minimum (Qmin=) Min/Max Mea-surement Setup

CFC CD DD

00879 Reactive Power Maximum (Qmax=) Min/Max Mea-surement Setup

CFC CD DD

00880 Apparent Power Minimum (Smin=) Min/Max Mea-surement Setup

CFC CD DD

00881 Apparent Power Maximum (Smax=) Min/Max Mea-surement Setup

CFC CD DD

00882 Frequency Minimum (fmin=) Min/Max Mea-surement Setup

CFC CD DD

00883 Frequency Maximum (fmax=) Min/Max Mea-surement Setup

CFC CD DD

00884 Power Factor Maximum (PF Max=) Min/Max Mea-surement Setup

CFC CD DD

00885 Power Factor Minimum (PF Min=) Min/Max Mea-surement Setup

CFC CD DD

00888 Pulsed Energy Wp (active) (Wp(puls)) Energy CD DD

00889 Pulsed Energy Wq (reactive) (Wq(puls)) Energy CD DD

00901 Power Factor (PF =) Measurement 134 137 priv 9 14 CFC CD DD

00924 Wp Forward (WpForward) Energy CD DD

00925 Wq Forward (WqForward) Energy CD DD

00928 Wp Reverse (WpReverse) Energy CD DD

00929 Wq Reverse (WqReverse) Energy CD DD

00963 I A demand (Ia dmd=) Demand Mea-surement Setup

CFC CD DD

00964 I B demand (Ib dmd=) Demand Mea-surement Setup

CFC CD DD

00965 I C demand (Ic dmd=) Demand Mea-surement Setup

CFC CD DD

00991 Pressure (Press =) Measurement CD DD

00992 Temperature (Temp =) Measurement CD DD

00996 Transducer 1 (Td1=) Measurement CFC CD DD

00997 Transducer 2 (Td2=) Measurement CFC CD DD

01058 Overload Meter Max (Θ /ΘTrpMax=) Min/Max Mea-surement Setup

CFC CD DD

01059 Overload Meter Min (Θ /ΘTrpMin=) Min/Max Mea-surement Setup

CFC CD DD

01068 Temperature of RTD 1 (Θ RTD 1 =) Measurement 134 146 priv 9 1 CFC CD DD

01069 Temperature of RTD 2 (Θ RTD 2 =) Measurement 134 146 priv 9 2 CFC CD DD

01070 Temperature of RTD 3 (Θ RTD 3 =) Measurement 134 146 priv 9 3 CFC CD DD

01071 Temperature of RTD 4 (Θ RTD 4 =) Measurement 134 146 priv 9 4 CFC CD DD

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

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typ

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Info

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-No

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A Appendix

01072 Temperature of RTD 5 (Θ RTD 5 =) Measurement 134 146 priv 9 5 CFC CD DD

01073 Temperature of RTD 6 (Θ RTD 6 =) Measurement 134 146 priv 9 6 CFC CD DD

01074 Temperature of RTD 7 (Θ RTD 7 =) Measurement 134 146 priv 9 7 CFC CD DD

01075 Temperature of RTD 8 (Θ RTD 8 =) Measurement 134 146 priv 9 8 CFC CD DD

01076 Temperature of RTD 9 (Θ RTD 9 =) Measurement 134 146 priv 9 9 CFC CD DD

01077 Temperature of RTD10 (Θ RTD10 =) Measurement 134 146 priv 9 10 CFC CD DD

01078 Temperature of RTD11 (Θ RTD11 =) Measurement 134 146 priv 9 11 CFC CD DD

01079 Temperature of RTD12 (Θ RTD12 =) Measurement 134 146 priv 9 12 CFC CD DD

30701 P, L1 (active power, phase L1) (P, L1 =) Measurement CFC CD DD

30702 P, L2 (active power, phase L2) (P, L2 =) Measurement CFC CD DD

30703 P, L3 (active power, phase L3) (P, L3 =) Measurement CFC CD DD

30704 Q, L1 (reactive power, phase L1) (Q, L1 =) Measurement CFC CD DD

30705 Q, L2 (reactive power, phase L2) (Q, L2 =) Measurement CFC CD DD

30706 Q, L3 (reactive power, phase L3) (Q, L3 =) Measurement CFC CD DD

30707 Power Factor, phase L1 (PF, L1 =) Measurement CFC CD DD

30708 Power Factor, phase L2 (PF, L2 =) Measurement CFC CD DD

30709 Power Factor, phase L3 (PF, L3 =) Measurement CFC CD DD

37-1 under current (37-1) Set Points(MeasuredValues)

CFC CD DD

170.2056 dalpha = (dα =) SYNC Functiongroup 1

130 1 priv 9 6 CFC CD DD

170.2056 dalpha = (dα =) SYNC Functiongroup 2

130 2 priv 9 6 CFC CD DD

170.2056 dalpha = (dα =) SYNC Functiongroup 3

130 3 priv 9 6 CFC CD DD

170.2056 dalpha = (dα =) SYNC Functiongroup 4

130 4 priv 9 6 CFC CD DD

170.2055 df = (df =) SYNC Functiongroup 1

130 1 priv 9 5 CFC CD DD

170.2055 df = (df =) SYNC Functiongroup 2

130 2 priv 9 5 CFC CD DD

170.2055 df = (df =) SYNC Functiongroup 3

130 3 priv 9 5 CFC CD DD

170.2055 df = (df =) SYNC Functiongroup 4

130 4 priv 9 5 CFC CD DD

170.2054 dV = (dV =) SYNC Functiongroup 1

130 1 priv 9 2 CFC CD DD

170.2054 dV = (dV =) SYNC Functiongroup 2

130 2 priv 9 2 CFC CD DD

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

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typ

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Info

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-No

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A.11 Measured Values

170.2054 dV = (dV =) SYNC Functiongroup 3

130 3 priv 9 2 CFC CD DD

170.2054 dV = (dV =) SYNC Functiongroup 4

130 4 priv 9 2 CFC CD DD

170.2051 f1 = (f1 =) SYNC Functiongroup 1

130 1 priv 9 4 CFC CD DD

170.2051 f1 = (f1 =) SYNC Functiongroup 2

130 2 priv 9 4 CFC CD DD

170.2051 f1 = (f1 =) SYNC Functiongroup 3

130 3 priv 9 4 CFC CD DD

170.2051 f1 = (f1 =) SYNC Functiongroup 4

130 4 priv 9 4 CFC CD DD

170.2053 f2 = (f2 =) SYNC Functiongroup 1

130 1 priv 9 7 CFC CD DD

170.2053 f2 = (f2 =) SYNC Functiongroup 2

130 2 priv 9 7 CFC CD DD

170.2053 f2 = (f2 =) SYNC Functiongroup 3

130 3 priv 9 7 CFC CD DD

170.2053 f2 = (f2 =) SYNC Functiongroup 4

130 4 priv 9 7 CFC CD DD

I A dmd> (I Admd>) Set Points(MeasuredValues)

CFC CD DD

I B dmd> (I Bdmd>) Set Points(MeasuredValues)

CFC CD DD

I C dmd> (I Cdmd>) Set Points(MeasuredValues)

CFC CD DD

I1dmd> (I1dmd>) Set Points(MeasuredValues)

CFC CD DD

Number of TRIPs= (#of TRIPs=) Statistics CD DD

Operating hours greater than (OpHour>) CD DD

Pressure< (Press<) Set Points(MeasuredValues)

CFC CD DD

Temp> (Temp>) Set Points(MeasuredValues)

CFC CD DD

170.2050 V1 = (V1 =) SYNC Functiongroup 1

130 1 priv 9 1 CFC CD DD

170.2050 V1 = (V1 =) SYNC Functiongroup 2

130 2 priv 9 1 CFC CD DD

170.2050 V1 = (V1 =) SYNC Functiongroup 3

130 3 priv 9 1 CFC CD DD

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

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A Appendix

170.2050 V1 = (V1 =) SYNC Functiongroup 4

130 4 priv 9 1 CFC CD DD

170.2052 V2 = (V2 =) SYNC Functiongroup 1

130 1 priv 9 3 CFC CD DD

170.2052 V2 = (V2 =) SYNC Functiongroup 2

130 2 priv 9 3 CFC CD DD

170.2052 V2 = (V2 =) SYNC Functiongroup 3

130 3 priv 9 3 CFC CD DD

170.2052 V2 = (V2 =) SYNC Functiongroup 4

130 4 priv 9 3 CFC CD DD

|Pdmd|> (|Pdmd|>) Set Points(MeasuredValues)

CFC CD DD

|Power Factor|< (|PF|<) Set Points(MeasuredValues)

CFC CD DD

|Qdmd|> (|Qdmd|>) Set Points(MeasuredValues)

CFC CD DD

|Sdmd|> (|Sdmd|>) Set Points(MeasuredValues)

CFC CD DD

F.No. Description Function IEC 60870-5-103 Configurable inMatrix

Fu

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588 7SJ62/63/64 ManualC53000-G1140-C147–1

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Index

Index

Numerics

27 10, 94, 37246 10, 104, 37346-1 104, 37346-2 104, 37346-TOC 10, 105, 37348 112, 37949 130, 38250 9, 38, 35950-1 950-2 950BF 205, 38950c 8750N 9, 38, 35950N-1 950N-2 950Nc 8750Ns 11, 155, 38451 9, 38, 36051 and 51N 36051N 9, 38, 36051Nc 8751Ns 1159 10, 94, 37264 155, 38466/68 112, 38067 10, 64, 37067 and 67N Elements 37067c 8767N 10, 64, 37067Nc 8767Ns 11, 155, 38467N-TOC 1067-TOC 1074TC 147, 39879M 177, 38881 126, 38181 O/U 126

A

Accessories 423Acknowledgement of

commands to local/remote/Digsi 262commands to the device front 262

A–CPU 288

A–I/O–2 292Analog Inputs 2, 346Analog Outputs 346Angular Error Compensation 166Automatic Reclosing 11, 194Automatic Reclosing System 177, 388Auxiliary voltage 288Auxiliary Voltages 140Average Calculation 247

B

Battery 424B–CPU 294B–I/O–2 300Binary Inputs 4Binary Inputs and Outputs 4, 276Binary Outputs 4Blocked by Protection 261Blocking of auto reclose via internal control 192Blocking of Reclosing 190Blocking Three-Phase Faults 192Blocking Time 181, 188Breaker Control 13, 252, 399Breaker Failure Protection 12, 205, 209, 389Buffer Battery 140Bus address 307, 310, 312

C

Caution (definition) iiCFC 392Changeover of setting groups 277Check

Current and voltage connection 331Rotation 331

Checking Connections 318Checking System Connections 321Checking the Binary Inputs and Outputs 326Circuit Breaker Monitoring 183, 188Climatic Stress Tests 356Clock 353, 399Command Duration 29Command Output and Switching Relays 263Command Sequence 254Commissioning 323

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Index

Commissioning Aids 245Communication 7Communications Interfaces 349Connection Examples 470Connections 275, 318Construction 357Contact mode for output relay BO1 and BO2 291Contact type for output relays 281Control Functions 6Control voltage 288, 291, 294Control voltage of BI 1 to BI 7 294Control voltage of BI 21 to BI 24 298Control voltage of BI 8 to BI 20 308Control voltage of BI8 to BI20 309Control voltages of BI 25 to BI 37 308Control voltages of BI18 to BI33 309Control voltages of BI4 to BI11 293Covering Caps 423Cross Blocking 47Cross blocking 58Cubicle Installation 426, 432, 456Current Flow Monitoring 29Current Inputs 346Current Rotation 143Current Supervision 101Current Symmetry 142Currents 275, 276

D

Danger (definition) iiDCF77 399Default Settings 494Definite 359Definite Time Elements (46-1, 46-2) 104Definite Time, Directional Overcurrent Protection 66Definite Time, Instantaneous Overcurrent Protection 39Definite-Time, Overcurrent Protection 359Detached Operation Unit 446Detached Operator Panel 405Determination of Direction 70, 156Determination of the Phase with a Ground Connection164Device Dropout 236Device Pickup 236Device Position 261DIGRA 424DIGSI REMOTE 4 425Dimensions 400

Direction check with load current 333Directional Time Overcurrent Ground Protection 81Directional Time Overcurrent Protection 10, 63, 370Disassembly of the Device 281Display Editor 424DNP3.0 8, 352Double Operation 261Dynamic Blocking 181, 188Dynamic Cold Load Pick-up Function 87, 371Dynamic Cold Load Setting Adjustment 10

E

Electrical Tests 353Elementary Diagrams 426EMC Tests for Immunity 353EMC Tests For Noise Emission 354Emergency Start 117Emergency Starting 136Excessive rotor temperature 114Exchanging interface modules 313Extension of Time Constants 116, 136External Current Transformer Circuits 142

F

Fault Location 201, 204, 389Fault value recording 245Femal Plugs 424Fibre optic cable 320Final Preparation of the Device 344Frequency Protection 10, 126, 128, 381Front Elements 4Functional Scope 20Fuse 144Fuse–Failure–Monitoring 144

G

General Device Dropout 236General Device Pickup 236Graphic Tools 425Graphical symbols iiiGround fault check 336Ground Impedance Ratios 34Group alarms 154

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Index

H

Hardware Modifications 279Hardware Monitoring 140Housing

for Panel Flush Mounting or Cubicle Installation(Size 1/1 x 19”) 402

for Panel Surface Mounting (Size 1/1) 404for Panel Surface Mounting (Size 1/3 x 19") 403for Panel Surface Mounting (Size 1/3 x 19”) 403

I

Information List 545Initiation of Reclosing 190Inrush Restraint 371Installation 266Insulation Tests 353Interface Cable 424Interface Modules 313Interface modules 423Interlocking 255Intermittent Ground Fault Protection 387Intermittierender Erdfehlerschutz 170Interoperability List 503Inverse Time Element (46-TOC) 105Inverse Time-Overcurrent Protection 43, 360IRIG B 399

K

k–factor 134Kühlmitteltemperatur 136

L

Life contact 303Limit Values 247Load 333Location of Ground Connections 160Long-Term Mean Value 397

M

Manual Close Mode 50, 78, 82Measured Values 395Measured Values Monitoring 140Measured Values Supervision 397

Measurements 242Measuring Transducer Inputs 346Mechanical Stress Tests 355Memory Components 140Message Processing 239Microcomputer System 4Min/Max Report 397Minimum and Maximum Values 247MODBUS 8Monitoring Functions 11, 140Monitoring of feedback information 262Motor Starting Protection 112, 379Motor Starting Recognition 138Mounting Rail for 19"-Racks 424Multi-Shot Reclosing 180

N

Negative Sequence Current Protection 10Negative Sequence Protection 104, 373No Trip – No Flag 23Nominal Frequency 26Nominal rated values 34Note (definition) iiNumerical Values 18

O

Open Breaker Times 191Operating Hours Counter 398Operating Software 424Ordering Data 410Ordering Information 410Overcurrent 38Overcurrent Protection 38Over-Frequency 381Overview of the masking features 541Overvoltage Protection 95, 101Overvoltage protection 100

P

Panel Flush Mounting 426, 432, 456Panel Installation 401Panel Surface Mounting 271, 428, 437Parameter names iiiParameter options iiiPC Front Interface 349PC Operating Interface at Front 318

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Index

Phase Rotation 26, 235, 331Pickup voltages of BI 6 and BI 7 307Pickup voltages of BI1 to BI5 303Pickup voltages of BI1 to BI7 295, 297Pickup voltages of BI18 to BI15 312Pickup voltages of BI21 to BI24 299Pickup voltages of BI8 to BI20 301Polarity Check 337Polarity of Current Transformers 27Power Supply 5, 346Power System Data 1 26Power System Data 2 34Pre-Defined CFC Charts 500Probing 141Processor Printed Circuit Boards C-CPU-2 288, 290PROFIBUS 7, 351Profibus–Interface 316Protective Functions 6Protocol 505Protocol-dependent functions 505

Q

Qualified personnel (definition) iii

R

Rack mounting and cubicle mounting 268Reactance Setting 35Rear Service–/Modem– Interface 350Reassembly of Device 317Recognition of Running Condition 36Recording of Event and Fault Data 7Reference Voltages 140Regionalization 16Reset Time Characteristics

As Per ANSI 365, 375Restarting limit 115Reverse Interlocking Bus Protection 49Reverse Interlocking for Looped Lines 73Reverse Interlocking Scheme 332RS232 350RS485 350RTD 226

S

SCADA Interface 351

Schalten bei asynchronen Netzbedingungen 213Schalten bei synchronen Netzbedingungen 213Sensitive Ground Fault Detection 11, 155, 384Serial Interfaces 4, 281Service Conditions 356Set points 244Setting Groups 33Setting groups

Changeover 277Short Circuit Links 423SIMATIC CFC 4 425Single-Shot Reclosing 180Software Monitoring 141Start Inhibit for Motors 10, 380Starting Time Monitoring for Motors 10Static Blocking 181Statistical Counters 237Statistics 398Switching Authority 259Switching elements on the printed circuit boards 302Switching Mode 260, 261Symbol conventions iiiSynchrones Schalten 212Synchronisierfunktion 210System (SCADA) Interface 318

T

Temperature Detection 391Temperature meter 320Temperature unit 26Temperaturerfassung 226Termination 304, 315Testing the Reverse Interlocking Scheme 332Text Values 18Thermal Overload Protection 10, 130, 382Thermobox 226, 320Time Constant 135Time Stamping 398Time synchronization interface 5, 320Time-Overcurrent Protection 9Triggering Oscillographic Recordings 342Trip and Close Command Duration 29Trip Circuit Monitor 398Trip Log 236, 398Trip Time Characteristics

As Per ANSI 364, 374As Per IEC 360, 374

Typographic conventions iii

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Index

U

UL-listing 349, 357Unbalanced Load 104Under-Frequency 381Undervoltage Protection 96, 100Units of Length 27User Specified Curves 69, 79, 82

V

Vibration and Shock Stress 355Voltage Inputs 346Voltage Protection 10, 94, 372Voltage Rotation 143Voltage Symmetry 142Voltage transformer m.c.b. 423

VT’s Nominal Values 28VT’s Ratios 28

W

Warning (definition) iiWatchdog 141Waveform Capture 247, 398

Z

Zone Controlled/ Field Interlocking 261Zone Sequence Coordination 186Zone Sequencing 193

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Index

594 7SJ62/63/64 ManualC53000-G1140-C147–1

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Corrections

To

Siemens AG

Dept. PTD PA D DM

D–13623 Berlin

Germany

Dear reader,

printing errors can never be entirely eliminated:therefore, should you come across any when read-ing this manual, kindly enter them in this form to-gether with any comments or suggestions for im-provement that you may have.

From

Name:

Company/Dept.:

Address:

Phone no.: Fax no.:

Corrections/Suggestions

7SJ62/63/64 ManualC53000-G1140-C147-1

Page 610: Manual 7SJ62-63-64 v44

Subject to technical alteration

Copying of this document and giving it to others and the useor communication of the contents thereof, are forbidden with-out express authority. Offenders are liable to the payment ofdamages. All rights are reserved in the event of the grant ofa patent or the registration of a utility model or design.

Order-no.: C53000-G1140-C147-1Available from: LZF Fürth-BislohePrinted in Germany/Imprimé en AllemagneAG 0302 0.2 FO 610 Am

Siemens Aktiengesellschaft


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