SIPROTEC 4
Distance Protection
7SA522
V4.74 and higher
Manual
C53000-G1176-C155-9
Vorwort
Table of Contents
Introduction 1
Functions 2
Mounting and Commissioning 3
Technical Data 4
Ordering Information and Accesso-
riesOrdering Information A
Terminal Assignments B
Connection Examples C
Default Settings and Protocol-dependent
Functions D
Functions, Settings, Information E
Literature
Glossary
Index
i
i
NOTE
For your own safety, observe the warnings and safety instructions contained in this document, if available.
Disclaimer of liability
We have checked the text of this manual against the hard-
ware and software described. However, deviations from
the description cannot be completely ruled out, so that no
liability can be accepted for any errors or omissions
contained in the information given.
The information given in this document is reviewed regu-
larly and any necessary corrections will be included in
subsequent editions. We appreciate any suggestions for
improvement.
We reserve the right to make technical improvements
without notice
Document Version V04.71.00
Release date 05.2016
Copyright
Copyright © Siemens AG 2016. All rights reserved.
Dissemination or reproduction of this document, or evalua-
tion and communication of its contents, is not authorized
except where expressly permitted. Violations are liable for
damages. All rights reserved, particularly for the purposes
of patent application or trademark registration.
Registered Trademarks
SIPROTEC, SINAUT, SICAM and DIGSI are registered trade-
marks of Siemens AG. Other designations in this manual
might be trademarks whose use by third parties for their
own purposes would infringe the rights of the owner.
Vorwort
Purpose of this Manual
This manual describes the functions, operation, installation, and commissioning of devices 7SA522. In partic-
ular, one will find:
•Information regarding the configuration of the scope of the device and a description of the device func-
tions and settings → Chapter 2;
•Instructions for Installation and Commissioning → Chapter 3;
•Compilation of the Technical Data → Chapter 4;
•As well as a compilation of the most significant data for advanced users → Appendix A.
General information with regard to design, configuration, and operation of SIPROTEC 4 devices are set out in
the SIPROTEC 4 System Description /1/ SIPROTEC 4 System Description.
Target Audience
Protection-system engineers, commissioning engineers, persons entrusted with the setting, testing and main-
tenance of selective protection, automation and control equipment, and operating personnel in electrical
installations and power plants.
Applicability of this Manual
This manual applies to: SIPROTEC 4 Distance Protection 7SA522; Firmware-Version V4.74 and higher.
Indication of Conformity
This product complies with the directive of the Council of the European Communities on the
approximation of the laws of the Member States relating to electromagnetic compatibility
(EMC Council Directive 2004/108/EC) and concerning electrical equipment for use within
specified voltage limits (Low-voltage directive 2006/95 EC).
This conformity is proved by tests conducted by Siemens AG in accordance with the Council
Directives in agreement with the generic standards EN61000-6-2 and EN 61000-6-4 for the
EMC directive, and with the standard EN 60255-27 for the low-voltage directive. The device
has been designed and produced for industrial use.
The product conforms with the international standard of the series IEC 60255 and the German
standard VDE 0435.
Additional Standards IEEE Std C37.90 (see Chapter 4, “Technical Data”)
[ul-schutz-110602-kn, 1, --_--]
SIPROTEC 4, 7SA522, Manual 3
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Additional Support
For questions about the SIPROTEC 4 system, please contact your Siemens sales partner.
Our Customer Support Center provides a 24-hour service.
Phone: +49 (180) 524-8437
Fax: +49 (180) 524-2471
e-mail: support.ic@siemens.com
Training Courses
Enquiries regarding individual training courses should be addressed to our Training Center:
Siemens AG
Siemens Power Academy TD
Humboldt Street 59 59
90459 Nuremberg
Phone: +49 (911) 433-7415
Fax: +49 (911) 433-5482
Internet: www.siemens.com/energy/power-academy
e-mail: poweracademy.ic-sg@siemens.com
Notes on Safety
This document is not a complete index of all safety measures required for operation of the equipment (module
or device). However, it comprises important information that must be followed for personal safety, as well as
to avoid material damage. Information is highlighted and illustrated as follows according to the degree of
danger:
!
DANGER
GEFAHR bedeutet, dass Tod oder schwere Verletzungen eintreten werden, wenn die angegebenen
Maßnahmen nicht getroffen werden.
²Beachten Sie alle Hinweise, um Tod oder schwere Verletzungen zu vermeiden.
²Danger indicates that death, severe personal injury or substantial material damage will result if proper
precautions are not taken.
!
WARNING
WARNING means that death or severe injury may result if the measures specified are not taken.
²Comply with all instructions, in order to avoid death or severe injuries.
!
CAUTION
CAUTION means that medium-severe or slight injuries can occur if the specified measures are not taken.
²Comply with all instructions, in order to avoid moderate or minor injuries.
i
i
NOTE
indicates information on the device, handling of the device, or the respective part of the instruction manual
which is important to be noted.
Vorwort
4 SIPROTEC 4, 7SA522, Manual
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Typographic and Symbol Conventions
The following text formats are used when literal information from the device or to the device appear in the
text flow:
Parameter Names
Designators of configuration or function parameters which may appear word-for-word in the display of the
device or on the screen of a personal computer (with operation software DIGSI), are marked in bold letters in
monospace type style. The same applies to titles of menus.
1234A
Parameter addresses have the same character style as parameter names. Parameter addresses contain the
suffix A in the overview tables if the parameter can only be set in DIGSI via the option Display additional
settings.
Parameter Options
Possible settings of text parameters, which may appear word-for-word in the display of the device or on the
screen of a personal computer (with operation software DIGSI), are additionally written in italics. The same
applies to the options of the menus.
Indications
Designators for information, which may be output by the relay or required from other devices or from the
switch gear, are marked in a monospace type style in quotation marks.
Deviations may be permitted in drawings and tables when the type of designator can be obviously derived
from the illustration.
The following symbols are used in drawings:
Device-internal logical input signal
Device-internal logical output signal
Internal input signal of an analog quantity
External binary input signal with number (binary input,
input indication)
External binary output signal with number
(example of a value indication)
External binary output signal with number (device indication) used as
input signal
Example of a parameter switch designated FUNCTION with address
1234 and the possible settings Ein and Aus
Besides these, graphical symbols are used in accordance with IEC 60617-12 and IEC 60617-13 or similar.
Some of the most frequently used are listed below:
Analog input variable
AND-gate operation of input values
OR-gate operation of input values
Exclusive OR gate (antivalence): output is active, if only one of the
inputs is active
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Coincidence gate: output is active, if both inputs are active or inactive
at the same time
Dynamic inputs (edge-triggered) above with positive, below with
negative edge
Formation of one analog output signal from a number of analog input
signals
Limit stage with setting address and parameter designator (name)
Timer (pickup delay T, example adjustable) with setting address and
parameter designator (name)
Timer (dropout delay T, example non-adjustable)
Dynamic triggered pulse timer T (monoflop)
Static memory (SR flipflop) with setting input (S), resetting input (R),
output (Q) and inverted output (Q), setting input dominant
Static memory (RS-flipflop) with setting input (S), resetting input (R),
output (Q) and inverted output (Q), resetting input dominant
Vorwort
6 SIPROTEC 4, 7SA522, Manual
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Table of Contents
Vorwort.........................................................................................................................................................3
1 Introduction................................................................................................................................................15
1.1 Overall Operation..............................................................................................................16
1.2 Application Scope............................................................................................................. 19
1.3 Characteristics.................................................................................................................. 21
2 Functions.................................................................................................................................................... 27
2.1 General.............................................................................................................................28
2.1.1 Functional Scope......................................................................................................... 28
2.1.1.1 Konfiguration des Funktionsumfangs .................................................................... 28
2.1.1.2 Setting Notes......................................................................................................... 28
2.1.1.3 Settings................................................................................................................. 30
2.1.2 Power System Data 1...................................................................................................32
2.1.2.1 Setting Notes......................................................................................................... 33
2.1.2.2 Settings................................................................................................................. 37
2.1.3 Change Group............................................................................................................. 38
2.1.3.1 Purpose of the Setting Groups................................................................................ 38
2.1.3.2 Setting Notes......................................................................................................... 39
2.1.3.3 Settings................................................................................................................. 39
2.1.3.4 Information List..................................................................................................... 39
2.1.4 Power System Data 2...................................................................................................39
2.1.4.1 Setting Notes......................................................................................................... 39
2.1.4.2 Settings................................................................................................................. 48
2.1.4.3 Information List..................................................................................................... 50
2.2 Distance Protection .......................................................................................................... 52
2.2.1 Distance protection, general settings........................................................................... 52
2.2.1.1 Erdfehlererkennung............................................................................................... 52
2.2.1.2 Calculation of the Impedances................................................................................55
2.2.1.3 Setting Notes......................................................................................................... 62
2.2.1.4 Settings................................................................................................................. 66
2.2.1.5 Information List..................................................................................................... 68
2.2.2 Distance protection with quadrilateral characteristic (optional).................................... 70
2.2.2.1 Functional Description........................................................................................... 71
2.2.2.2 Setting Notes......................................................................................................... 76
2.2.2.3 Settings................................................................................................................. 83
2.2.3 Distance protection with MHO characteristic (optional)................................................ 85
2.2.3.1 Functional Description........................................................................................... 85
2.2.3.2 Setting Notes......................................................................................................... 92
2.2.3.3 Settings................................................................................................................. 95
2.2.4 Tripping Logic of the Distance Protection..................................................................... 96
2.2.4.1 Functional Description........................................................................................... 96
2.2.4.2 Setting Notes....................................................................................................... 101
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2.3 Power swing detection (optional)....................................................................................102
2.3.1 Allgemeines.............................................................................................................. 102
2.3.2 Funktionsbeschreibung............................................................................................. 102
2.3.3 Setting Notes.............................................................................................................105
2.3.4 Settings.....................................................................................................................106
2.3.5 Information List.........................................................................................................106
2.4 Protection data interfaces and communication topology (optional)..................................107
2.4.1 Functional Description...............................................................................................107
2.4.2 Setting Notes.............................................................................................................110
2.4.3 Settings.....................................................................................................................112
2.4.4 Information List.........................................................................................................113
2.5 Remote signals via protection data interface (optional)....................................................115
2.5.1 Functional Description...............................................................................................115
2.5.2 Information List.........................................................................................................115
2.6 Teleprotection for distance protection............................................................................. 117
2.6.1 General..................................................................................................................... 117
2.6.2 Functional Description...............................................................................................118
2.6.3 Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT).....................118
2.6.4 Direct Underreach Transfer Trip................................................................................. 122
2.6.5 Permissive Overreach Transfer Trip (POTT)................................................................. 123
2.6.6 Unblocking Scheme...................................................................................................126
2.6.7 Blocking Scheme....................................................................................................... 130
2.6.8 Transient Blocking..................................................................................................... 133
2.6.9 Measures for Weak or Zero Infeed..............................................................................133
2.6.10 Setting Notes.............................................................................................................135
2.6.11 Settings.....................................................................................................................137
2.6.12 Information List.........................................................................................................137
2.7 Earth fault overcurrent protection in earthed systems (optional)......................................139
2.7.1 Functional Description...............................................................................................139
2.7.2 Setting Notes.............................................................................................................153
2.7.3 Settings.....................................................................................................................162
2.7.4 Information List.........................................................................................................166
2.8 Teleprotection for earth fault overcurrent protection (optional)....................................... 168
2.8.1 General..................................................................................................................... 168
2.8.2 Directional Comparison Pickup...................................................................................169
2.8.3 Directional Unblocking Scheme..................................................................................172
2.8.4 Directional Blocking Scheme......................................................................................176
2.8.5 Transient Blocking..................................................................................................... 179
2.8.6 Measures for Weak or Zero Infeed..............................................................................179
2.8.7 Setting Notes.............................................................................................................180
2.8.8 Settings.....................................................................................................................183
2.8.9 Information List.........................................................................................................183
2.9 Measures for Weak and Zero Infeed.................................................................................185
2.9.1 Echo function............................................................................................................ 185
2.9.1.1 Functional Description......................................................................................... 185
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2.9.2 Classical Tripping.......................................................................................................186
2.9.2.1 Functional Description......................................................................................... 186
2.9.2.2 Setting Notes....................................................................................................... 189
2.9.3 Tripping According to French Specification.................................................................190
2.9.3.1 Functional Description......................................................................................... 190
2.9.3.2 Setting Notes....................................................................................................... 192
2.9.4 Tables on Classical Tripping and Tripping according to French Specification................194
2.9.4.1 Settings............................................................................................................... 194
2.9.4.2 Information List................................................................................................... 195
2.10 External direct and remote tripping................................................................................. 196
2.10.1 Functional Description...............................................................................................196
2.10.2 Setting Notes.............................................................................................................197
2.10.3 Settings.....................................................................................................................197
2.10.4 Information List.........................................................................................................197
2.11 Overcurrent protection (optional)....................................................................................198
2.11.1 General..................................................................................................................... 198
2.11.2 Functional Description...............................................................................................198
2.11.3 Setting Notes.............................................................................................................205
2.11.4 Settings.....................................................................................................................210
2.11.5 Information List.........................................................................................................212
2.12 Instantaneous high-current switch-on-to-fault protection (SOTF)..................................... 213
2.12.1 Functional Description...............................................................................................213
2.12.2 Setting Notes.............................................................................................................214
2.12.3 Settings.....................................................................................................................214
2.12.4 Information List.........................................................................................................214
2.13 Automatic reclosure function (optional).......................................................................... 215
2.13.1 Functional Description...............................................................................................215
2.13.2 Setting Notes.............................................................................................................231
2.13.3 Settings.....................................................................................................................237
2.13.4 Information List.........................................................................................................240
2.14 Synchronism and voltage check (optional).......................................................................242
2.14.1 Functional Description...............................................................................................242
2.14.2 Setting Notes.............................................................................................................248
2.14.3 Settings.....................................................................................................................252
2.14.4 Information List.........................................................................................................254
2.15 Under and over-voltage protection (optional).................................................................. 255
2.15.1 Overvoltage Protection.............................................................................................. 255
2.15.2 Undervoltage Protection............................................................................................ 261
2.15.3 Setting Notes.............................................................................................................265
2.15.4 Settings.....................................................................................................................269
2.15.5 Information List.........................................................................................................271
2.16 Frequency protection (optional)...................................................................................... 274
2.16.1 Functional Description...............................................................................................274
2.16.2 Setting Notes.............................................................................................................276
2.16.3 Settings.....................................................................................................................278
2.16.4 Information List.........................................................................................................278
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2.17 Fault locator................................................................................................................... 280
2.17.1 Functional Description...............................................................................................280
2.17.2 Setting Notes.............................................................................................................282
2.17.3 Settings.....................................................................................................................283
2.17.4 Information List.........................................................................................................283
2.18 Circuit breaker failure protection (optional)..................................................................... 284
2.18.1 Functional Description...............................................................................................284
2.18.2 Setting Notes.............................................................................................................294
2.18.3 Settings.....................................................................................................................297
2.18.4 Information List.........................................................................................................298
2.19 Monitoring Functions......................................................................................................300
2.19.1 Measurement Supervision......................................................................................... 300
2.19.1.1 Hardware Monitoring...........................................................................................300
2.19.1.2 Software Monitoring............................................................................................ 302
2.19.1.3 Monitoring External Transformer Circuits..............................................................302
2.19.1.4 Monitoring the Phase Angle of the Positive Sequence Power.................................307
2.19.1.5 Malfunction Reaction........................................................................................... 310
2.19.1.6 Setting Notes....................................................................................................... 312
2.19.1.7 Settings............................................................................................................... 313
2.19.1.8 Information List................................................................................................... 314
2.19.2 Trip circuit supervision...............................................................................................315
2.19.2.1 Functional Description......................................................................................... 315
2.19.2.2 Setting Notes....................................................................................................... 318
2.19.2.3 Settings............................................................................................................... 318
2.19.2.4 Information List................................................................................................... 318
2.20 Function Control and Circuit Breaker Test ....................................................................... 320
2.20.1 Function Control........................................................................................................320
2.20.1.1 Line Energization Recognition.............................................................................. 320
2.20.1.2 Detection of the Circuit Breaker Position............................................................... 323
2.20.1.3 Open Pole Detektor.............................................................................................. 326
2.20.1.4 Pickup Logic for the Entire Device ........................................................................ 328
2.20.1.5 Tripping Logic of the Entire Device....................................................................... 329
2.20.2 Circuit breaker trip test.............................................................................................. 333
2.20.2.1 Functional Description......................................................................................... 333
2.20.2.2 Setting Notes....................................................................................................... 334
2.20.2.3 Information List................................................................................................... 334
2.20.3 Device....................................................................................................................... 334
2.20.3.1 Trip-Dependent Indications.................................................................................. 335
2.20.3.2 Switching Statistics.............................................................................................. 336
2.20.3.3 Setting Notes....................................................................................................... 336
2.20.3.4 Settings............................................................................................................... 336
2.20.3.5 Information List................................................................................................... 336
2.20.4 Ethernet EN100-Module............................................................................................ 338
2.20.4.1 Functional Description......................................................................................... 338
2.20.4.2 Setting Notes....................................................................................................... 338
2.20.4.3 Information List................................................................................................... 338
2.21 Auxiliary Functions .........................................................................................................339
2.21.1 Commissioning Aids.................................................................................................. 339
2.21.1.1 Functional Description......................................................................................... 339
2.21.1.2 Setting Notes....................................................................................................... 342
2.21.2 Processing of Messages............................................................................................. 342
2.21.2.1 Functional Description......................................................................................... 342
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2.21.3 Statistics....................................................................................................................345
2.21.3.1 Functional Description......................................................................................... 346
2.21.3.2 Setting Notes....................................................................................................... 346
2.21.3.3 Information List................................................................................................... 346
2.21.4 Measurement............................................................................................................347
2.21.4.1 Functional Description......................................................................................... 347
2.21.4.2 Information List................................................................................................... 349
2.21.5 Oscillographic Fault Records...................................................................................... 350
2.21.5.1 Functional Description .........................................................................................350
2.21.5.2 Setting Notes....................................................................................................... 351
2.21.5.3 Settings............................................................................................................... 351
2.21.5.4 Information List................................................................................................... 352
2.21.6 Demand Measurement Setup.....................................................................................352
2.21.6.1 Long-Term Average Values...................................................................................352
2.21.6.2 Setting Notes....................................................................................................... 352
2.21.6.3 Settings............................................................................................................... 352
2.21.6.4 Information List................................................................................................... 353
2.21.7 Min/Max Measurement Setup.................................................................................... 353
2.21.7.1 Reset................................................................................................................... 353
2.21.7.2 Setting Notes....................................................................................................... 353
2.21.7.3 Settings............................................................................................................... 353
2.21.7.4 Information List................................................................................................... 353
2.21.8 Set Points (Measured Values).....................................................................................355
2.21.8.1 Limit value monitoring......................................................................................... 355
2.21.8.2 Setting Notes....................................................................................................... 356
2.21.8.3 Information List................................................................................................... 356
2.21.9 Energy.......................................................................................................................356
2.21.9.1 Energy Metering.................................................................................................. 356
2.21.9.2 Setting Notes....................................................................................................... 357
2.21.9.3 Information List................................................................................................... 357
2.22 Command Processing .....................................................................................................358
2.22.1 Control Authorization................................................................................................ 358
2.22.1.1 Type of Commands.............................................................................................. 358
2.22.1.2 Sequence in the Command Path...........................................................................358
2.22.1.3 Interlocking......................................................................................................... 359
2.22.1.4 Information List................................................................................................... 362
2.22.2 Control Device...........................................................................................................362
2.22.2.1 Information List................................................................................................... 362
2.22.3 Process Data..............................................................................................................363
2.22.3.1 Functional Description......................................................................................... 363
2.22.3.2 Information List................................................................................................... 363
2.22.4 Protocol.....................................................................................................................364
2.22.4.1 Information List................................................................................................... 364
3 Mounting and Commissioning................................................................................................................. 365
3.1 Mounting and Connections............................................................................................. 366
3.1.1 Configuration Information......................................................................................... 366
3.1.2 Hardware Modifications.............................................................................................370
3.1.2.1 General................................................................................................................370
3.1.2.2 Disassembly.........................................................................................................371
3.1.2.3 Switching Elements on Printed Circuit Boards....................................................... 374
3.1.2.4 Schnittstellenmodule........................................................................................... 387
3.1.2.5 Reassembly..........................................................................................................390
3.1.3 Mounting.................................................................................................................. 390
3.1.3.1 Panel Flush Mounting...........................................................................................390
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3.1.3.2 Rack and Cubicle Mounting.................................................................................. 392
3.1.3.3 Panel Mounting....................................................................................................394
3.2 Checking Connections.....................................................................................................395
3.2.1 Checking Data Connections of Serial Interfaces.......................................................... 395
3.2.2 Checking the Protection Data Communication............................................................397
3.2.3 Checking the System Connections............................................................................. 398
3.3 Commissioning............................................................................................................... 400
3.3.1 Test Mode / Transmission Block..................................................................................401
3.3.2 Checking the Time Synchronisation Interface............................................................. 401
3.3.3 Testing the System Interface......................................................................................401
3.3.4 Checking the switching states of the binary Inputs/Outputs........................................403
3.3.5 Checking the Communication Topology.....................................................................405
3.3.6 Test Mode for Teleprotection Scheme with Protection Data Interface..........................410
3.3.7 Checking for Breaker Failure Protection......................................................................410
3.3.8 Current, Voltage, and Phase Rotation Testing............................................................. 412
3.3.9 Directional Check with Load Current.......................................................................... 413
3.3.10 Polarity Check for the Voltage Input U4.......................................................................414
3.3.11 Polarity Check for the Current Input Ι4 ....................................................................... 415
3.3.12 Measuring the Operating Time of the Circuit Breaker..................................................419
3.3.13 Testing of the Teleprotection System with Distance Protection................................... 420
3.3.14 Testing of the Teleprotection System with Earth-fault Protection................................ 422
3.3.15 Check of the Signal Transmission for Breaker Failure Protection and/or End Fault
Protection................................................................................................................. 423
3.3.16 Check of the Signal Transmission for Internal and External Remote Tripping............... 424
3.3.17 Testing User-defined Functions..................................................................................424
3.3.18 Trip and Close Test with the Circuit Breaker................................................................424
3.3.19 Switching Test of the Configured Operating Equipment............................................. 424
3.3.20 Triggering Oscillographic Recording for Test...............................................................425
3.4 Final Preparation of the Device........................................................................................427
4 Technical Data.......................................................................................................................................... 429
4.1 General...........................................................................................................................430
4.1.1 Analogue Inputs and Outputs.................................................................................... 430
4.1.2 Auxiliary voltage........................................................................................................430
4.1.3 Binary Inputs and Outputs......................................................................................... 431
4.1.4 Communication Interfaces.........................................................................................432
4.1.5 Electrical Tests...........................................................................................................436
4.1.6 Mechanical Tests....................................................................................................... 438
4.1.7 Climatic Stress Tests.................................................................................................. 438
4.1.8 Deployment Conditions............................................................................................. 439
4.1.9 Certifications............................................................................................................. 439
4.1.10 Construction..............................................................................................................439
4.2 Distance Protection......................................................................................................... 441
4.3 Power Swing Detection (with impedance pickup) (optional)............................................ 444
4.4 Distance Protection Teleprotection Schemes....................................................................445
4.5 Earth Fault Protection (optional)......................................................................................446
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4.6 Earth Fault Protection Teleprotection Schemes (optional)................................................ 455
4.7 Weak-infeed Tripping (classical)...................................................................................... 456
4.8 Weak-infeed Tripping (French Specification)....................................................................457
4.9 Protection Data Interface and Communication Topology (optional)..................................458
4.10 External Direct and Remote Tripping................................................................................461
4.11 Time Overcurrent Protection........................................................................................... 462
4.12 Instantaneous High-current Switch-onto-fault Protection.................................................465
4.13 Automatic Reclosure (optional)....................................................................................... 466
4.14 Synchronism and Voltage Check (optional)......................................................................467
4.15 Voltage Protection (optional).......................................................................................... 468
4.16 Frequency Protection (optional)...................................................................................... 471
4.17 Fault Locator...................................................................................................................472
4.18 Circuit Breaker Failure Protection (optional).....................................................................473
4.19 Monitoring Functions......................................................................................................474
4.20 Transmission of Binary Information (optional)................................................................. 476
4.21 User-defined Functions (CFC).......................................................................................... 477
4.22 Additional Functions....................................................................................................... 481
4.23 Dimensions.....................................................................................................................484
4.23.1 Housing for Panel Flush Mounting or Cubicle Mounting (Size1/2)................................ 484
4.23.2 Housing for Panel Flush Mounting or Cubicle Mounting (Size 1/1)................................485
4.23.3 Panel Surface Mounting (Housing Size 1/2)................................................................. 486
4.23.4 Dimensions of a device for panel surface mounting (size 1/1)...................................... 486
A Ordering Information and AccessoriesOrdering Information.................................................................. 487
A.1 Ordering Information...................................................................................................... 488
A.2 Accessories..................................................................................................................... 492
B Terminal Assignments..............................................................................................................................495
B.1 Panel Flush Mounting or Cubicle Mounting......................................................................496
B.2 Housing for Panel Surface Mounting................................................................................505
C Connection Examples............................................................................................................................... 515
C.1 Current Transformer Examples........................................................................................ 516
C.2 Voltage Transformer Examples........................................................................................ 520
D Default Settings and Protocol-dependent Functions............................................................................... 523
D.1 LEDs............................................................................................................................... 524
D.2 Binary Input.................................................................................................................... 525
D.3 Binary Output................................................................................................................. 526
D.4 Function Keys................................................................................................................. 527
D.5 Default Display................................................................................................................528
D.6 Pre-defined CFC Charts....................................................................................................529
D.7 Protocol-dependent Functions.........................................................................................530
E Functions, Settings, Information..............................................................................................................531
E.1 Functional Scope............................................................................................................ 532
E.2 Settings.......................................................................................................................... 534
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E.3 Information List.............................................................................................................. 558
E.4 Group Alarms..................................................................................................................620
E.5 Measured Values.............................................................................................................621
Literature.................................................................................................................................................. 627
Glossary.................................................................................................................................................... 629
Index.........................................................................................................................................................639
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Overall Operation
The digital Distance Protection 7SA522 is equipped with a powerful microprocessor system. This provides fully
digital processing of all functions in the device, from the acquisition of the measured values to the output of
commands to the circuit breakers. The following figure shows the basic structure of the 7SA522.
Analog Inputs
The measuring inputs (MI) convert the currents and voltages coming from the instrument transformers and
adapt them to the level appropriate for the internal processing of the device. The device has 4 current and 4
voltage inputs. Three current inputs are provided for measurement of the phase currents, a further measuring
input (I4) may be configured to measure the earth current (residual current from the current transformer star-
point), the earth current of a parallel line (for parallel line compensation) or the star-point current of a power
transformer (for earth fault direction determination).
[hwstruktur7sa522-020402-wlk, 1, en_GB]
Figure 1-1 Hardware structure of the digital Distance Protection 7SA522
A voltage measuring input is provided for each phase-earth voltage. A further voltage input (U4) may option-
ally be used to measure either the displacement voltage (e-n voltage), or the additiona voltage of synchronism
1.1
Introduction
1.1 Overall Operation
16 SIPROTEC 4, 7SA522, Manual
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and voltage check or any other voltage UX (for overvoltage protection). The analog signals are then routed to
the input amplifier group IA.
The input amplifier group IA provides high-resistance termination for the analog input quantities. It comprises
filters that are optimized for measured value processing with regard to bandwidth and processing speed.
The AD analog digital converter group contains analog/digital converters and memory components for data
transfer to the microcomputer system.
Microcomputer System
Apart from processing the measured values, the microcomputer system µC also executes the actual protection
and control functions. This especially includes:
•Filtering and conditioning of the measured signals
•Continuous monitoring of the measured quantities
•Monitoring of the pickup conditions for the individual protection functions
•Monitoring of limit values and time sequences
•Control of signals for logical functions
•Reaching trip and close command decisions
•Recording of messages, fault data and fault values for analysis
•Administration of the operating system and its functions, e.g. data storage, realtime clock, communica-
tion, interfaces, etc.
The information is provided via output amplifier OA.
Binary Inputs and Outputs
Binary inputs from and outputs to the computer system are routed via the I/O modules (inputs and outputs).
The computer system obtains information from the system (e.g remote resetting) or from the external equip-
ment (e.g. blocking commands). Outputs are commands that are issued to the switching devices and
messages for remote signaling of important events and states.
Front Elements
LEDs and an LC display provide information on the function of the device and indicate events, states and
measured values.
Integrated control and numeric keys in conjunction with the LCD facilitate local communication with the
device. Thus, all information of the device, e.g. configuration and setting parameters, operating and fault
messages, and measured values can be retrieved or changed (see also chapter 2 and SIPROTEC 4 System
Description).
Devices with control functions also allow control of switchgear from the front panel.
Serial Interfaces
The serial operator interface in the front cover enables communication with a personal computer when using
the DIGSI operating program. This allows all device functions to be handled conveniently.
The serial service interface can also be used for communication with a personal computer using DIGSI. This
port is especially well suited for a permanent connection of the devices to the PC or for operation via a
modem.
All device data can be transmitted to a control center through the serial system interface. Various protocols
and physical arrangements are available for this interface to suit a particular application.
An additional interface is provided for time synchronization of the internal clock through external synchroniza-
tion sources.
Further communication protocols can be realized via additional interface modules.
Introduction
1.1 Overall Operation
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Protection Data Interfaces (optional)
Depending on the version, there are one or two protection data interfaces available. Via these interfaces, the
data for the teleprotection scheme and further information such as closing of the local circuit breaker and
other externally coupled trip commands and binary information can be transmitted to other ends.
Power Supply
The functional units described are powered by a power supply, PS, with adequate power in the different
voltage levels. Brief supply voltage dips which may occur during short circuits in the auxiliary voltage supply of
the substation, are usually bridged by a capacitor (see also Technical Data, Section 4.1 General).
Introduction
1.1 Overall Operation
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Application Scope
The digital distance protection SIPROTEC 4 7SA522 is a selective and extremely fast protection for overhead
lines and cables with single- and multi-ended infeeds in radial, ring or any type of meshed systems at any
voltage levels. The network neutral can be earthed, compensated or isolated.
The device incorporates the functions which are normally required for the protection of an overhead line
feeder and is therefore capable of universal application. It may also be applied as time-graded back-up protec-
tion to all types of comparison protection schemes used on lines, transformers, generators, motors and
busbars at all voltage levels.
The devices located at the ends of the protected zone exchange measuring information via teleprotection
functions with conventional connections (contacts) or via optional protection data interfaces using dedicated
communication links (usually fibre optic cables) or a communication network. If the 7SA522 devices are
equipped with one protection data interface, they can be used for a protection object with two ends. Lines
with three terminals ("T" type feeders) require at least one device with two protection data interfaces
(7SA522).
Protection Functions
The basic function of the device is the recognition of the distance to the fault with distance protection meas-
urement. In particular for complex multiphase faults, the distance measurement is designed with multiple
measuring elements. Different pickup schemes enable adaptation to system conditions and the user's protec-
tion philosophy. The network neutral can be isolated, compensated or earthed (with or without earth current
limiting). The use on long, heavily-loaded lines is possible with or without series compensation.
The distance protection may be supplemented by teleprotection using various signal transmission schemes
(for fast tripping on 100 % of the line length). In addition, an earth fault protection for high resistance earth
faults (ordering option) is available. It may be directional or non-directional and may also be incorporated in
signal transmission schemes. On lines with weak or no infeed at one line end, it is possible to achieve fast
tripping at both line ends by means of the signal transmission schemes. When switching onto a fault along the
line, an undelayed trip signal can be emitted.
In the event of a failure of the measured voltages due to a fault in the secondary circuits (e.g. trip of the
voltage transformer mcb or a blown fuse), the device can automatically revert to emergency operation with an
integrated overcurrent protection, until such time as the measured voltage returns. Alternatively, the time
delayed overcurrent protection may be used as back-up time delayed overcurrent protection, i.e. it functions
independently and in parallel to the distance protection.
Depending on the version ordered, most short-circuit protection functions may also trip single-pole. They may
operate in co-operation with an integrated automatic reclosure (optional ordering feature) with which single-
pole, three-pole or single- and three-pole automatic reclosures as well as multi-shot automatic reclosure are
possible on overhead lines. Before reclosure after three-pole tripping, the valid status for reclosure can be
checked by the device through voltage and/or synchronism check (optional ordering feature). It is possible to
connect an external automatic reclosure and/or synchronism check, as well as double protection with one or
two automatic reclosure functions.
In addition to the previously mentioned fault protection functions, additional protection functions are avail-
able: - functions such as multistage overvoltage, undervoltage and frequency protection, circuit breaker failure
protection and protection against effects of power swings (simultaneously active as power swing blocking for
the distance protection).To assist in localizing the fault as fast as possible after an incident, a fault location
with optional load compensation for improved accuracy is incorporated in the device..
Digital Transmission of Protection Data (optional)
If the distance protection is to be complemented by digital teleprotection schemes, the data required for this
purpose can be transmitted via the protection data interface by employing a digital communication link.
Communication via the protection data interfaces can be used for transmitting additional information, e.g.
measured values, binary commands and other information can be transmitted.
With more than two devices (= ends of the protected object) and when using optional protection data inter-
faces, the communication can be built up as a ring. This enables a redundant operation in case a communica-
tion line fails. The devices will automatically find the remaining healthy communication lines. But even with
two ends, communication lines can be doubled to create redundancies.
1.2
Introduction
1.2 Application Scope
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Control Functions
The device is equipped with control functions which operate, close and open, switchgear devices via control
keys, the system interface, binary inputs and a PC with DIGSI software. The status of the primary equipment
can be transmitted to the device via auxiliary contacts connected to binary inputs. The present status (or posi-
tion) of the primary equipment can be displayed on the device, and used for interlocking or plausibility moni-
toring. The number of the devices to be switched is limited by the binary inputs and outputs available in the
device or the binary inputs and outputs allocated for the switch position feedbacks. Depending on the mode
of operation, one binary input (single point indication) or two binary inputs (double point indication) can be
used. The capability of switching primary equipment can be restricted by appropriate settings for the
switching authority (remote or local), and by the operating mode (interlocked/non-interlocked, with or
without password validation). Interlocking conditions for switching (e.g. switchgear interlocking) can be
established using the integrated userdefined logic.
Indications and Measured Values; Fault Recording
The operational indications provide information about conditions in the power system and the device. Meas-
urement quantities and values that are calculated can be displayed locally and communicated via the serial
interfaces.
Device messages can be assigned to a number of LEDs on the front panel (programmable), can be externally
processed via output contacts (programmable), linked with user-definable logic functions and/or issued via
serial interfaces (see Communication below).
During a fault (system fault) important events and changes in conditions are saved in fault logs. Instantaneous
fault values are also saved in the device and may be analyzed at a later time.
Communication
Serial interfaces are available for the communication with operating, control and memory systems.
A 9-pin DSUB socket on the front panel is used for local communication with a personal computer. By means
of the SIPROTEC 4 operating software DIGSI, all operational and evaluation tasks can be executed via this oper-
ator interface, such as specifying and modifying configuration parameters and settings, configuring userspe-
cific logic functions, retrieving operational and fault messages and measured values, reading out and
displaying fault recordings, inquiring device conditions and measured values, issuing control commands.
To establish an extensive communication with other digital operating, control and memory components the
device may be provided with further interfaces depending on the order variant.
The service interface can be operated via the RS232 or RS485 interface and also allows communication via
modem. For this reason, remote operation is possible via PC and the DIGSI operating software, e.g. to operate
several devices via a central PC.
The system interface is used for central communication between the device and a control center. It can be
operated through the RS232, the RS485 or the FO port. Several standardized protocols are available for data
transmission. An EN 100 module allows integrating the devices into 100 MBit Ethernet communication
networks of the process control and automation system, using IEC 61850 protocols. In parallel to the link with
the process control and automation system, this interface can also handle DIGSI communication and inter-
relay communication using GOOSE messaging.
Another interface is provided for the time synchronization of the internal clock via external synchronization
sources (IRIG-B or DCF77).
Other interfaces provide for communication between the devices at the ends of the protected object. These
protection data interfaces have been mentioned above in the protection functions.
The operator and service interface allow operation of the device remotely or locally, using a standard browser.
This can be used during commissioning, maintenance and also during operation of the devices at all ends of
the protected object using a communication network. For this application, a special tool, the “WEB Monitor”, is
provided. This tool has been optimized for distance protection.
Introduction
1.2 Application Scope
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Characteristics
General Features
•Powerful 32-bit microprocessor system
•Complete digital processing of measured values and control, from the sampling and digitizing of the
measure quantities up to the closing and tripping commands to the circuit breakers
•Complete galvanic separation and interference immunity of the internal processing circuits from the
measurement, control, and power supply circuits by analog input transducers, binary inputs and outputs
and the DC/DC or AC/DC converters
•Complete scope of functions which is normally required for the protection of a line feeder
•digital protection data transmission, may be used for teleprotection with permanent monitoring of
disturbance, fault or transfer time deviations in the communication network with automatic runtime re-
adjustment
•Distance protection system realizable for up to three ends
•Simple device operation using the integrated operator panel or a connected personal computer with
operator guidance
•Storage of fault indications and instantaneous values for fault recording
Distance Protection
•Protection for all types of faults in systems with earthed, compensated or isolated starpoint
•Selectable polygonal tripping characteristic or MHO characteristic
•Reliable differentiation between load and short-circuit conditions also in long, high-loaded lines
•High-sensitivity in the case of a system with week in-feed, extreme stability against load jumps and
power swings
•Optimum adaptation to the line parameters by means of the polygonal tripping characteristic with
diverse configuration parameters and “load trapezoid” (elimination of the possible load impedance)
•6 measuring systems for each distance zone
•7 distance zones, selectable as forward, reverse or non-directional, one of which may be used as a
controlled overreach zone
•10 time stages for the distance zones
•Direction determination (with polygon) or polarisation (with MHO-circle) is done with unfaulted loop
(quadrature) voltages and voltage memory, thereby achieving unlimited directional sensitivity, which is
not affected by capacitive voltage transformer transients
•Suitable for lines with series compensation
•Insensitive to current transformer saturation
•Compensation against the influence of a parallel line can be implemented
•Shortest tripping time is approx. 17 ms (for fN = 50 Hz) or 15 ms (for fN = 60 Hz)
•Phase segregated tripping (in conjunction with single-pole or single- and three-pole auto-reclosure)
•Non-delayed tripping following switch onto fault is possible
•Seperate earth impedance compensation setting pair (RE/RL and XE/XL) for zone 1 and other zones
Power Swing Supplement (optionally for impedance pickup)
•Power swing detection with dZ/dt measurement from three measuring systems
•Power swing detection up to 10 Hz swing frequency
1.3
Introduction
1.3 Characteristics
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•remains in service also during single-pole dead times
•settable power swing programs
•prevention of undesired tripping by the distance protection during power swings
•Tripping for out-of-step conditions can be configured
Teleprotection Supplement
•Different schemes which may be set
•Permissive Underreach Transfer Trip = PUTT (via a separately settable overreach zone)
•Comparison schemes (Permissive Overreach Transfer Trip = POTT or blocking schemes, with separate
overreach zone)
•Suitable for lines with two or three ends
•Phase segregated transmission possible in lines with two ends
•Optional signal exchange of the devices via dedicated communication connections (in general optical
fibres) or a communication network, in this case a phase segregated transmission with two or three line
ends and continuous monitoring of the communication paths and the signal propagation delay with
automatic re-adjustment takes place
Earth Fault Protection (optional)
•Time overcurrent protection with a maximum of three definite time stages (DT) and one inverse time
stage (IDMT) for high resistance earth faults in earthed systems
•For inverse-time overcurrent protection a selection from various characteristics based on several stand-
ards is possible
•The inverse time stage can additionally be set as fourth definite time stage
•High-sensitivity (depending on the version from 3 mA is possible)
•Phase current restraint against error currents due to tolerances in the current transformer measurement
•Second harmonic inrush restraint
•Optional earth fault protection with an inverse tripping time dependent on zero sequence voltage or zero
sequence power
•Each stage can be set to be non-directional or directional in the forward or reverse direction
•Single-pole tripping enabled by integrated phase selector
•Direction determination with automatic selection of the larger of zero sequence voltage or negative
sequence voltage (U0, ΙY or U2), with zero sequence system quantities (Ι0, U0), with zero sequence current
and transformer starpoint current (Ι0, ΙY), with negative sequence system quantities (Ι2, U2) or with zero
sequence power (Ι0 · 3U0)
•One or more stages may function in conjunction with a signal transmission supplement; also suited for
lines with three ends
•Instantaneous tripping by any stage when switching onto a fault
Transmission of Information (only with Digital Protection Data Transmission)
•Transmission of the measured values from all ends of the protected object
•Transmission of four commands to all ends
•Transmission of twenty-four additional binary signals to all ends
Introduction
1.3 Characteristics
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Tripping at Line Ends with no or Weak Infeed
•Possible in conjunction with teleprotection schemes
•Allows fast tripping at both line ends, even if there is no or only weak infeed available at one line end
•Phase segregated tripping and single-pole automatic reclosure is possible (version with single-phase trip-
ping)
External Direct and Remote Tripping
•Tripping at the local line end from an external device via a binary input
•Tripping of the remote line end by internal protection functions or an external device via a binary input
(with teleprotection)
Time Overcurrent Protection
•Optional as emergency function in the case of measured voltage failure, or as backup function inde-
pendent of the measured voltage
•Two definite time stages (DT) and one inverse time stage (IDMT), each for phase currents and earth
current
•For inverse-time overcurrent protection select from various characteristics based on several standards
•Blocking capability e.g. for reverse interlocking with any stage
•Instantaneous tripping by any stage when switching onto a fault
•Additional stage, e.g. stub protection, for fast tripping of faults between the current transformer and line
isolator (when the isolator switching status feedback is available); particularly well suited to substations
with 11/2 circuit breaker arrangements.
Instantaneous High-Current Switch-onto-Fault Protection
•Fast tripping for all faults on total line length
•Selectable for manual closure or following each closure of the circuit breaker
•with integrated line energisation detection
Automatic reclosure function (optional)
•For reclosure after 1-pole, 3-pole or 1-pole and 3-pole tripping
•Single or multiple reclosure (up to eight reclosure attempts)
•With separate action time setting for the first 4 reclose attempts, optionally without action times
•With separate dead times after 1-pole and 3-pole tripping, separate for the first four reclosure attempts
•Controlled optionally by protection pickup with separate dead times after 1-pole , 2-pole or 3-pole pickup
•Optionally with adaptive dead time, reduced dead time and dead line check
Synchronism and voltage check (optional)
•Verification of the synchronous conditions before reclosing after three-pole tripping
•Fast measurement of the voltage difference Udiff, the phase angle difference φdiff and the frequency
difference fdiff
•Alternatively, check of the de-energized state before reclosing
•Closing at asynchronous system conditions with consideration of the CB closing time to achieve system
re-connection when voltages are in phase
•Settable minimum and maximum voltage
Introduction
1.3 Characteristics
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•Verification of the synchronous conditions or de-energized state before manual closing of the circuit
breaker is possible with separate setting thresholds and states
•Phase angle compensation for voltage measurement behind a transformer
•Measuring voltages optionally phase-phase or phase-earth
Voltage Protection (optional)
•Overvoltage and undervoltage detection with different stages
•Two overvoltage stages for the phase-earth voltages
•Two overvoltage stages for the phase-phase voltages
•Two overvoltage stages for the positive sequence voltage, optionally with compounding
•Two overvoltage stages for the negative sequence voltage
•Two overvoltage stages for the zero sequence voltage or any other single-phase voltage
•Settable dropout to pickup ratios
•Two undervoltage stages for the phase-earth voltages
•Two undervoltage stages for the phase-phase voltages
•Two undervoltage stages for the positive sequence voltage
•Settable current criterion for undervoltage protection functions
Frequency Protection (optional)
•Monitoring on underfrequency (f<) and/or overfrequency (f>) with 4 frequency limits and delay times
that are independently adjustable
•Very insensitive to harmonics and abrupt phase angle changes
•Large frequency range (approx. 25 Hz to 70 Hz)
Fault Location
•Initiated by trip command or dropout of the pickup
•Computation of the distance to fault with dedicated measured value registers
•Fault location output in Ohm, kilometers or miles and % of line length
•Parallel line compensation can be selected
•Taking into consideration the load current in case of single-phase earth faults fed from both sides (config-
urable)
•Output of the fault location in the BCD code or as analog value (depending on the options ordered)
Circuit Breaker Failure Protection (optional)
•With definite time current stages for monitoring the current flow through every pole of the circuit
breaker
•Separate pickup thresholds for phase and earth currents
•Independent timers for single-pole and three-pole tripping
•Start by trip command of every internal protection function
•Start by external trip functions possible
•Single-stage or two-stage
•Short dropout and overshoot times
Introduction
1.3 Characteristics
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User-defined Logic Functions (CFC)
•Freely programmable combination of internal and external signals for the implementation of user-
defined logic functions
•All typical logic functions
•Time delays and limit value inquiries
Commissioning; operation (only with digital transmission of protection data)
•Display of magnitude and phase angle of local and remote measured values
•Display of measured values of the communication link, such as transmission delay and availability
Command Processing
•Switchgear can be switched on and off manually via local control keys, the programmable function keys
on the front panel, via the system interface (e.g. by SICAM or LSA), or via the operator interface (using a
personal computer and the operating software DIGSI)
•Feedback on switching states via the circuit breaker auxiliary contacts (for commands with feedback)
•Monitoring of the circuit breaker position and of the interlocking conditions for switching operations.
Monitoring Functions
•Availability of the device is greatly increased because of self-monitoring of the internal measurement
circuits, power supply, hardware and software
•Monitoring of the current and voltage transformer secondary circuits by means of summation and
symmetry checks
•Trip circuit supervision
•Checking for the load impedance, the measured direction and the phase sequence
•Monitoring of the signal transmission of the optional digital communication path
Additional Functions
•Battery buffered real time clock, which may be synchronised via a synchronisation signal (e.g. DCF77,
IRIGB via satellite receiver), binary input or system interface
•Continuous calculation and display of measured quantities on the front display. Indication of measured
values of the remote end or of all ends (for devices with protection data interfaces)
•Fault event memory (trip log) for the last eight network faults (faults in the power system), with real time
stamps
•Fault recording and data transfer for fault recording for a maximum time range of 30 seconds
•Switching statistics: Counting of the trip and close commands issued by the device, as well as recording
of the fault current data and accumulation of the interrupted fault currents
•Communication with central control and memory components possible via serial interfaces (depending
on the options ordered), optionally via RS232, RS485, modem connection or fibre optic cable
•Commissioning aids such as connection and direction checks as well as circuit breaker test functions
•The WEB monitor (installed on a PC or a laptop) widely supports the testing and commissioning proce-
dure by providing a graphic presentation of the protection system with phasor diagrams. All currents and
voltages from all ends of the system are displayed on the screen provided that the devices are connected
via protection data interfaces.
Introduction
1.3 Characteristics
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Functions
This chapter describes the individual functions of the SIPROTEC 4 device 7SA522. It shows the setting possibili-
ties for each function in maximum configuration. Guidelines for establishing setting values and, where
required, formulae are given.
Based on the following information, it can also be determined which of the provided functions should be
used.
2.1 General 28
2.2 Distance Protection 52
2.3 Power swing detection (optional) 102
2.4 Protection data interfaces and communication topology (optional) 107
2.5 Remote signals via protection data interface (optional) 115
2.6 Teleprotection for distance protection 117
2.7 Earth fault overcurrent protection in earthed systems (optional) 139
2.8 Teleprotection for earth fault overcurrent protection (optional) 168
2.9 Measures for Weak and Zero Infeed 185
2.10 External direct and remote tripping 196
2.11 Overcurrent protection (optional) 198
2.12 Instantaneous high-current switch-on-to-fault protection (SOTF) 213
2.13 Automatic reclosure function (optional) 215
2.14 Synchronism and voltage check (optional) 242
2.15 Under and over-voltage protection (optional) 255
2.16 Frequency protection (optional) 274
2.17 Fault locator 280
2.18 Circuit breaker failure protection (optional) 284
2.19 Monitoring Functions 300
2.20 Function Control and Circuit Breaker Test 320
2.21 Auxiliary Functions 339
2.22 Command Processing 358
2
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General
A few seconds after the device is switched on, the default display appears on the LCD.
Configuration settings can be entered by using a PC and the DIGSI operating software and transferred via the
operator interface on the front panel of the device or via the service interface. The procedure is described in
detail in the SIPROTEC 4 System Description. Entry of password no. 7 (parameter set) is required to modify
configuration settings. Without the password, the settings may be read, but may not be modified and trans-
mitted to the device.
The function parameters, i.e. function options, threshold values, etc., can be changed via the front panel of
the device, or via the operator or service interface from a personal computer using DIGSI. The level 5 password
(individual parameters) is required.
Functional Scope
Konfiguration des Funktionsumfangs
The 7SA522 device contains a series of protection and additional functions. The hardware and firmware is
designed for this scope of functions. Additionally, the command functions can be matched to the system
conditions. Furthermore, individual functions may be enabled or disabled during configuration, or interaction
between functions may be adjusted.
Example for the configuration of scope of functions:
A substation has feeders with overhead lines and transformers. Fault location is to be performed on the over-
head lines only. In the devices for the transformer feeders this function is therefore set to „Disabled“.
The available protection functions and additional functions can be configured as Enabled or Disabled. For
some functions, a choice between several options is possible which are described below.
Functions configured as Disabled are not processed by the 7SA6. There are no indications, and corre-
sponding settings (functions, limit values) are not displayed during setting.
i
i
NOTE
The functions and default settings available depend on the device version ordered.
Setting Notes
Configuring the functional scope
The scope of functions with the available options is set in the Functional Scope dialog box to match plant
requirements.
Most settings are self-explanatory. Besonderheiten are described below.
Special Cases
For communication of the protection signals, each device may feature one or two protection data interfaces
(depending on the ordered version). Determine at address 145 whether to use protection data interface 1
with setting STATE PROT I 1 or interface 2 at address 146 with setting STATE PROT I 2. A protected
object with two ends requires at least one protection data interface for each relay. If there are more ends, it
must be ensured that all associated devices are connected directly or indirectly (via other devices). Subsection
2.4 Protection data interfaces and communication topology (optional) “Protection Data Topology” provides
more information.
If use of the setting group changeover function is desired, address 103 Grp Chge OPTION should be set to
Enabled. In this case, up to four different groups of settings may be changed quickly and easily during device
operation (see also Section 2.1.3). With the setting Disabled only one parameter group is available.
Address 110 Trip mode is only valid for devices that can trip single-pole or three-pole. Set 1-/3pole to
enable also single-pole tripping, i.e. if you want to utilise single-pole or single-pole/three-pole automatic reclo-
2.1
2.1.1
2.1.1.1
2.1.1.2
Functions
2.1 General
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sure. This requires that an internal automatic reclosure function exists or that an external reclosing device is
used. Furthermore, the circuit breaker must be capable of single-pole tripping.
i
i
NOTE
If you have changed address 110, save your changes first via OK and reopen the dialog box since the other
setting options depend on the selection in address 110.
Depending on the distance protection model, you can select the tripping characteristic. This setting is made in
address 112 for the phase-phase measuring units Phase Distance and in address 113 for the phase-earth
measuring units Earth Distance. You can select between the polygonal tripping characteristic Quadri-
lateral and the MHO characteristic. Sections 2.2.3 Distance protection with MHO characteristic (optional)
and 2.2.2 Distance protection with quadrilateral characteristic (optional) provide a detailed overview of the
characteristics and measurement methods. The two adresses can be set seperately and differently. If the
device is to be used only for phase-earth loops or only for phase-phase loops, set the function that is not
required to Disabled. If only one of the characteristic options is available in the device, the relevant setting
options are hidden.
To complement the distance protection by teleprotection schemes, you can select the desired scheme at
address 121 Teleprot. Dist.. You can select the underreach transfer trip with overreach zone PUTT
(Z1B), the teleprotection scheme POTT, the unblocking scheme UNBLOCKING and the blocking scheme
BLOCKING. If the device features a protection data interface for communication via digital transmission lines,
set SIGNALv.ProtInt here. The procedures are described in detail in Section 2.2.1 Distance protection,
general settings. If you do not want to use teleprotection in conjunction with distance protection, set Disa-
bled.
If a pickup of zone Z1 of the distance protection shall be possible only after exceeding an additional current
threshold value, set the parameter 119 Iph>(Z1) to Enabled. Select the setting Disabled if the additional
threshold value is not required.
The power swing supplement (see also Subsection 2.3 Power swing detection (optional)) is activated by
setting address 120 Power Swing = Enabled.
With address 125 Weak Infeed you can select a supplement to the teleprotection schemes. Set Enabled to
apply the classical scheme for echo and weak infeed tripping. The setting Logic no. 2 switches this func-
tion to the French specification. This setting is available in the device variants for the region France (only
version 7SA522*-**D** or 10th digit of order number = D).
At address 126 Back-Up O/C you can set the characteristic group that the time overcurrent protection uses
for operation. In addition to the definite time overcurrent protection, you can configure an inverse time over-
current protection depending on the ordered version. The latter operates either according to an IEC character-
istic (TOC IEC) or an ANSI characteristic (TOC ANSI). The various characteristic curves are illustrated in the
Technical Data. With the device version for the region Germany (10th digit of ordering code = A), the third
definite time overcurrent stage is only availabe if the setting TOC IEC /w 3ST is active. You can also disable
the time overcurrent protection (Disabled).
At address 131 Earth Fault O/C you can set the characteristic group which the earth fault protection uses
for operation. In addition to the definite time overcurrent protection, which covers up to three phases, an
inverse-time earth fault protection function may be configured depending on the ordered version. The latter
operates either according to an IEC characteristic (TOC IEC) or an ANSI characteristic (TOC ANSI) or
according to a logarithmic-inverse characteristic (TOC Logarithm.). If an inverse-time characteristic is not
required, the stage usually designated “inverse time” can be used as the fourth definite time stage (Definite
Time). Alternatively, it is possible to select an earth fault protection with inverse-time characteristic U0
inverse (only for region Germany, 10th digit of the ordering code = A) or a zero sequence power protection
Sr inverse (only for region France, 10th digit of ordering code = D). For the characteristics please refer to
the Technical Data. You can also disable the earth fault protection (Disabled).
When using the earth fault protection, it can be complemented by teleprotection schemes. Select the desired
scheme at address 132 Teleprot. E/F. You can select the direction comparison scheme
Dir.Comp.Pickup, the unblocking scheme UNBLOCKING and the blocking scheme BLOCKING. The proce-
dures are described in detail in Section 2.8 Teleprotection for earth fault overcurrent protection (optional). If
the device features a protection data interface for communication via a digital link, set SIGNALv.ProtInt
here. If you do not want to use teleprotection in conjunction with earth fault protection set Disabled.
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 29
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Address 145 P. INTERFACE 1 and, where required, address 146 STATE PROT I 2 is also valid for commu-
nication of the teleprotection for earth fault protection via teleprotection interface, as described above.
If the device features an automatic reclosing function, address 133 and 134 are of importance. Automatic
reclosure is only permitted for overhead lines. It must not be used in any other case. If the protected object
consists of a combination of overhead lines and other equipment (e.g. overhead line in unit with a trans-
former or overhead line/cable), reclosure is only permissible if it can be ensured that it can only take place in
the event of a fault on the overhead line. If no automatic reclosing function is desired for the feeder at which
7SA522 operates, or if an external device is used for reclosure, set address 133 Auto Reclose to Disabled.
Otherwise set the number of desired reclosing attempts there. You can select 1 AR-cycle to 8 AR-cycles.
You can also set ADT (adaptive dead times); in this case the behaviour of the automatic reclosure function is
determined by the cycles of the remote end. The number of cycles must however be configured at least in one
of the line ends which must have a reliable infeed. The other end — or other ends, if there are more than two
line ends — may operate with adaptive dead time. Section 2.13 Automatic reclosure function (optional)
provides detailed information on this topic.
The AR control mode at address 134 allows a total of four options. On the one hand, it can be determined
whether the auto reclose cycles are carried out according to the fault type detected by the pickup of the
starting protection function(s) (only for three-pole tripping) or according to the type of trip command. On the
other hand, the automatic reclosure function can be operated with or without action time.
The setting AUS und Twirk / AUS ohne TwirkTrip without T-action ... (default setting = Trip with T-
action ... ) is preferred if single-pole or single-pole/three-pole auto reclose cycles are provided for and possible.
In this case, different dead times (for every AR cycle) are possible after single-pole tripping and after three-
pole tripping. The tripping protection function determines the type of tripping: Single-pole or three-pole. The
dead time is controlled in dependence on this.
The setting Anr. und Twirk / Anr. ohne Twirk (Pickup with T-action) is only possible and visible if only
three-pole tripping is desired. This is the case when either the ordering number of the device model indicates
that it is only suited for three-pole tripping, or when only three-pole tripping is configured (address 110 Trip
mode = 3pole only, see above). In this case, different dead times can be set for the auto reclose cycles
following 1-, 2- and 3-phase faults. The decisive factor here is the pickup situation of the protection functions
at the instant the trip command disappears. This operating mode enables making the dead times dependent
on the type of fault also for three-pole reclosure cycles. Tripping is always three-pole.
The setting ... und Twirk with action time) provides an action time for each auto-reclose cycle. The action
time is started by a general pickup of all protection functions. If there is no trip command yet when the action
time has expired, the corresponding automatic reclosure cycle cannot be executed. Section 2.13 Automatic
reclosure function (optional) provides detailed information on this topic. This setting is recommended for
time-graded protection. If the protection function which is to operate with automatic reclosure, does not have
a general pickup signal for starting the action times, select ... ohne Twirk (without action time).
Address 137 U/O VOLTAGE allows activating the voltage protection function with a variety of undervoltage
and overvoltage protection stages. In particular, the overvoltage protection with the positive sequence system
of the measuring voltages provides the option to calculate the voltage at the other, remote line end via inte-
grated compounding. This is particularly useful for long transmission lines where no-load or low-load condi-
tions prevail and an overvoltage at the other line end (Ferranti effect) is to cause tripping of the local circuit
breaker. In this case set address 137 U/O VOLTAGE to Enabl. w. comp. (enabled with compounding). Do
not use compounding on lines with series capacitors!
For the fault location you can determine at address 138 Fault Locator, in addition to Enabled and Disa-
bled, that the fault distance is output in BCD code (4 bit units, 4 bit tens and 1 bit hundreds and “data valid”)
via binary outputs (with BCD-output). A corresponding number of output relays (No. 1143 to 1152) must
be made available and allocated for this purpose.
For the trip circuit supervision set at address 140 Trip Cir. Sup. the number of trip circuits to be moni-
tored: 1 trip circuit, 2 trip circuits or 3 trip circuits, unless you omit it (Disabled).
Settings
Addr. Parameter Setting Options Default Setting Comments
103 Grp Chge OPTION Disabled
Enabled
Disabled Setting Group Change Option
2.1.1.3
Functions
2.1 General
30 SIPROTEC 4, 7SA522, Manual
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Addr. Parameter Setting Options Default Setting Comments
110 Trip mode 3pole only
1-/3pole
3pole only Trip mode
112 Phase Distance Quadrilateral
MHO
Disabled
Quadrilateral Phase Distance
113 Earth Distance Quadrilateral
MHO
Disabled
Quadrilateral Earth Distance
119 Iph>(Z1) Disabled
Enabled
Disabled Additional Threshold Iph>(Z1)
120 Power Swing Disabled
Enabled
Disabled Power Swing detection
121 Teleprot. Dist. PUTT (Z1B)
POTT
UNBLOCKING
BLOCKING
SIGNALv.ProtInt
Disabled
Disabled Teleprotection for Distance prot.
122 DTT Direct Trip Disabled
Enabled
Disabled DTT Direct Transfer Trip
124 SOTF Overcurr. Disabled
Enabled
Disabled Instantaneous HighSpeed SOTF
Overcurrent
125 Weak Infeed Disabled
Enabled
Logic no. 2
Disabled Weak Infeed (Trip and/or Echo)
126 Back-Up O/C Disabled
TOC IEC
TOC ANSI
TOC IEC /w 3ST
TOC IEC Backup overcurrent
131 Earth Fault O/C Disabled
TOC IEC
TOC ANSI
TOC Logarithm.
Definite Time
U0 inverse
Sr inverse
Disabled Earth fault overcurrent
132 Teleprot. E/F Dir.Comp.Pickup
SIGNALv.ProtInt
UNBLOCKING
BLOCKING
Disabled
Disabled Teleprotection for Earth fault over-
curr.
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 31
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Setting Options Default Setting Comments
133 Auto Reclose 1 AR-cycle
2 AR-cycles
3 AR-cycles
4 AR-cycles
5 AR-cycles
6 AR-cycles
7 AR-cycles
8 AR-cycles
ADT
Disabled
Disabled Auto-Reclose Function
134 AR control mode Pickup w/ Tact
Pickup w/o Tact
Trip w/ Tact
Trip w/o Tact
Trip w/ Tact Auto-Reclose control mode
135 Synchro-Check Disabled
Enabled
Disabled Synchronism and Voltage Check
136 FREQUENCY Prot. Disabled
Enabled
Disabled Over / Underfrequency Protection
137 U/O VOLTAGE Disabled
Enabled
Enabl. w. comp.
Disabled Under / Overvoltage Protection
138 Fault Locator Enabled
Disabled
with BCD-output
Enabled Fault Locator
139 BREAKER FAILURE Disabled
Enabled
enabled w/ 3I0>
Disabled Breaker Failure Protection
140 Trip Cir. Sup. Disabled
1 trip circuit
2 trip circuits
3 trip circuits
Disabled Trip Circuit Supervision
145 P. INTERFACE 1 Enabled
Disabled
IEEE C37.94
Enabled Protection Interface 1 (Port D)
146 P. INTERFACE 2 Disabled
Enabled
IEEE C37.94
Disabled Protection Interface 2 (Port E)
147 NUMBER OF RELAY 2 relays
3 relays
2 relays Number of relays
Power System Data 1
The device requires some plant and power system data in order to be able to adapt its functions accordingly,
depending on the actual application. The data required include for instance rated data of the substation and
the measuring transformers, polarity and connection of the measured quantities, if necessary features of the
circuit breakers, and others. Furthermore, there are several function parameters associated with several func-
tions rather than one specific protection, control or monitoring function. The Power System Data 1 can only be
changed from a PC running DIGSI and are discussed in this section.
2.1.2
Functions
2.1 General
32 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Setting Notes
General
In DIGSI double-click on Settings to display the relevant selection. A dialog box with the tabs Transformers,
Power System and Breaker will open under Power System Data 1 in which you can configure the indi-
vidual parameters. The following subsections are structured in the same way.
Current Transformer Polarity
In address 201 CT Starpoint, the polarity of the wye-connected current transformers is specified (the
following figure also goes for only two current transformers). The setting determines the measuring direction
of the device (forward = line direction). A change in this setting also results in a polarity reversal of the earth
current inputs ΙE or ΙEE.
[polung-stromwandler-020313-kn, 1, en_GB]
Figure 2-1 Polarity of current transformers
Nominal Values of the Transformers
In the addresses 203 Unom PRIMARY and 204 Unom SECONDARY the device obtains information on the
primary and secondary rated voltage (phase-to-phase voltage) of the voltage transformers; in addresses 205
CT PRIMARY and 206 CT SECONDARY the primary and secondary rated current transformers are set.
It is important to ensure that the secondary CT nominal current matches the rated current of the device, other-
wise the device will be blocked. The nominal current is set with jumpers on the measuring module (see
3.1.2 Hardware Modifications).
Correct entry of the primary data is a prerequisite for the correct computation of operational measured values
with primary magnitude. If the settings of the device are performed with primary values using DIGSI, these
primary data are an indispensable requirement for the correct function of the device.
Voltage Connection
The device features four voltage measuring inputs, three of which are connected to the set of voltage trans-
formers. Various possibilities exist for the fourth voltage input U4.
2.1.2.1
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 33
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•Connection of the U4 input to the open delta winding Ue–n of the voltage transformer set:
Address 210 is then set to: U4 transformer = Udelta transf..
When connected to the e-n winding of a set of voltage transformers, the voltage transformation ratio of
the voltage transformers is usually:
The factor Uph/Udelta (secondary voltage, address 211 Uph / Udelta) must be set to 3/√3 = √3 ≈ 1.73.
For other transformation ratios, e.g. the formation of the displacement voltage via an interconnected
transformer set, the factor must be corrected accordingly. This factor is important if the 3U0> protection
stage is used and for monitoring the measured values and the scaling of the measured values and fault
recording values.
•Connection of the U4 input to perform the synchronism check:
Address 210 is then set to: U4 transformer = Usy2 transf..
If the voltage transformers for the protection functions Usy1 are located on the outgoing feeder side, the
U4 transformer has to be connected to a busbar voltage Usy2. Synchronisation is also possible if the
voltage transformers for the protection functions Usy1 are connected on busbar side, in which case the
additional U4 transformer must be connected to a feeder voltage.
If the transformation ratio differs, this can be adapted with the setting in address 215 Usy1/Usy2
ratio. In address 212 Usy2 connection, the type of voltage connected to measuring point Usy2 for
synchronism check is set. The device then automatically selects the voltage at measuring point Usy1. If the
two measuring points used for synchronism check — e.g. feeder voltage transformer and busbar voltage
transformer — are not separated by devices that cause a relative phase shift, then the parameter in
address 214 φ Usy2-Usy1 is not required. This parameter can only be changed in DIGSI at Display Addi-
tional Settings. If, however, a power transformer is connected in between, its vector group must be
adapted. The phase angle from Usy11 to Usy2 is evaluated with positive sense.
Example: (see also Figure 2-2)
Busbar 400 kV primary, 110 V secondary,
Feeder 220 kV primary, 100 V secondary,
Transformator 400 kV / 220 kV, vector group Dy(n) 5
The transformer vector group is defined from the high voltage side to the low voltage side. In this
example, the feeder transformers are those of the low voltage side of the transformer. Since the device
“looks” from the direction of the feeder transformers, the angle is 5 · 30° (according to the vector group)
negative, i.e. - 150°. A positive angle is obtained by adding 360°: Address 214: ϕ Usy2-Usy1 = 360° - 150°
= 210°.
Adresse 214: φ Usy2-Usy1 = 360° - 150° = 210°.
The busbar transformers supply 110 V secondary for primary operation at nominal value while the feeder
transformers supply 100 V secondary. Therefore, this difference must be balanced:
Address 215: Usy1/Usy2 ratio = 100 V/110 V = 0,91.
Functions
2.1 General
34 SIPROTEC 4, 7SA522, Manual
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[sammelschienespg-trafo-wlk-200802, 1, en_GB]
Figure 2-2 Busbar voltage measured via transformer
•Connection of the U4 input to any other voltage UX, which can be processed by the overvoltage protec-
tion function:
Address 210 is then set to: U4 transformer = Ux transformer.
•If the input U4 is not required, set:
Address 210 U4 transformer = Not connected.
Factor Uph / Udelta (address 211, see above) is also of importance in this case, as it is used for scaling
the measured data and fault recording data.
Current Connection
The device features four current measurement inputs, three of which are connected to the set of current
transformers. Various possibilities exist for the fourth current input Ι4:
•Connection of the Ι4 input to the earth current in the starpoint of the set of current transformers on the
protected feeder (normal connection):
Address 220 is then set to: I4 transformer = In prot. line and address 221 I4/Iph CT = 1.
•Connection of the Ι4 input to a separate earth current transformer on the protected feeder (e.g. a
summation CT or core balance CT):
Address 220 is then set to: I4 transformer = In prot. line and address 221 I4/Iph CT is set:
[uebersetzung-erd-phase-260702-wlk, 1, en_GB]
This is independent of whether the device has a normal measuring current input for Ι4 or a sensitive meas-
uring current input.
Example:
Phase current transformers 500 A / 5 A
Earth current transformer 60 A / 1 A
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 35
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[formel-strmwdl-parallelschlt-270702-wlk, 1, en_GB]
•Connection of the Ι4 input to the earth current of the parallel line (for parallel line compensation of the
distance protection and/or fault location):
Address 220 is then set to: I4 transformer = In paral. line and usually address 221 I4/Iph CT
= 1.
If the set of current transformers on the parallel line however has a different transformation ratio to
those on the protected line, this must be taken into account in address 221:
Address 220 is then set to: I4 transformer = In paral. line and address 221 I4/Iph CT = ΙN
paral. line / ΙN prot. line
Beispiel:
Current transformers on protected line 1200 A
Current transformers on parallel line 1500 A
[formel-strmwdl-parallelschlt-2tesbeisp-270702-wlk, 1, en_GB]
•Connection of the Ι4 input to the starpoint current of a transformer; this connection is occasionally used
for the polarisation of the directional earth fault protection:
Address 220 is then set to: I4 transformer = IY starpoint, and address 221 I4/Iph CT is
according to transformation ratio of the starpoint transformer to the transformer set of the protected
line.
•Wird der Ι4-Eingang nicht benötigt, so wird eingestellt:
Adresse 220 I4 transformer = Not connected,
Adresse 221 I4/Iph CT ist dann irrelevant.
Für die Schutzfunktionen wird in diesem Fall der Nullstrom aus der Summe der Phasenströme berechnet.
Rated frequency
The rated frequency of the power system is set at address 230 Rated Frequency. The factory presetting
according to the ordering code (MLFB) only needs to be changed if the device is applied in a region different
from the one indicated when ordering. You can set 50 Hz or 60 Hz
System Starpoint
The manner in which the system starpoint is earthed must be considered for the correct processing of earth
faults and double earth faults. Accordingly, set for address 207 SystemStarpoint = Solid Earthed,
Peterson-Coil or Isolated. For low-resistant earthed systems set Solid Earthed.
Phase Sequence
Use address 235 PHASE SEQ. to change the default setting (L1 L2 L3 for clockwise rotation) if your power
system has a permanent anti-clockwise phase sequence (L1 L3 L2).
Distance Unit
Address 236 Distance Unit determines the distance unit (km or Miles) for the fault location indications. If
the compounding function of the voltage protection is used, the overall line capacitance is calculated from the
line length and the capacitance per unit length. If compounding is not used and fault location is not available,
this parameter is of no consequence. Changing the distance unit will not result in an automatic conversion of
the setting values which depend on this distance unit. They have to be re-entered into their corresponding
valid addresses.
Functions
2.1 General
36 SIPROTEC 4, 7SA522, Manual
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Mode of the earth impedance (residual) compensation
Matching of the earth to line impedance is an essential prerequisite for the accurate measurement of the fault
distance (distance protection, fault locator) during earth faults. In address 237 Format Z0/Z1 the format for
entering the residual compensation is determined. It is possible to use either the ratio RE/RL, XE/XL or to
enter the complex earth (residual) impedance factor K0. The setting of the earth (residual) impedance factors
is done in the power system data 2 (refer to Section 2.1.4 Power System Data 2).
Single-pole tripping on an earth fault
Address 238 EarthFltO/C 1p specifies whether the earth-fault settings for single-pole tripping and blocking
in the single-pole dead time are accomplished together for all stages (setting stages together) or sepa-
rately (setting stages separat.). The actual settings are specified in the area of earth fault protection for
earthed systems (see section 2.7.2) with the irrelevant addresses hidden. This parameter can only be altered
with DIGSI under Additional Settings.
Closing time of the circuit breaker
The circuit breaker closing time T-CB close at address 239 is required if the device is to close also under
asynchronous system conditions, no matter whether for manual closing, for automatic reclosing after 3-pole
tripping, or both. The device will then calculate the time for the close command such that the voltages are
phase-synchronous the instant the breaker poles make contact.
Trip command duration
In address 240 the minimum trip command duration TMin TRIP CMD is set. It applies to all protection and
control functions which may issue a trip command. It also determines the duration of the trip pulse when a
circuit breaker test is initiated via the device. This parameter can only be altered in DIGSI at Display Additional
Settings.
In address 241 the maximum close command duration TMax CLOSE CMD is set. It applies to all close
commands issued by the device. It also determines the length of the close command pulse when a circuit
breaker test cycle is issued via the device. It must be long enough to ensure that the circuit breaker has
securely closed. There is no risk in setting this time too long, as the close command will in any event be termi-
nated following a new trip command from a protection function. This parameter can only be altered in DIGSI
at Display Additional Settings.
Circuit breaker test
7SA522 allows a circuit-breaker test during operation using a trip-and-close command entered on the front
panel or from DIGSI. The duration of the trip command is set as explained above. Address 242 T-CBtest-
dead determines the duration from the end of the trip command until the start of the close command for this
test. It should not be less than 0.1 s.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
201 CT Starpoint towards Line
towards Busbar
towards Line CT Starpoint
203 Unom PRIMARY 1.0 .. 1200.0 kV 400.0 kV Rated Primary Voltage
204 Unom SECONDARY 80 .. 125 V 100 V Rated Secondary Voltage (Ph-Ph)
205 CT PRIMARY 10 .. 5000 A 1000 A CT Rated Primary Current
206 CT SECONDARY 1A
5A
1A CT Rated Secondary Current
207 SystemStarpoint Solid Earthed
Peterson-Coil
Isolated
Solid Earthed System Starpoint is
2.1.2.2
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 37
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Addr. Parameter Setting Options Default Setting Comments
210 U4 transformer Not connected
Udelta transf.
Usy2 transf.
Ux transformer
Not connected U4 voltage transformer is
211 Uph / Udelta 0.10 .. 9.99 1.73 Matching ratio Phase-VT To Open-
Delta-VT
212 Usy2 connection L1-E
L2-E
L3-E
L1-L2
L2-L3
L3-L1
L1-L2 VT connection for Usy2
214A φ Usy2-Usy1 0 .. 360 ° 0 ° Angle adjustment Usy2-Usy1
215 Usy1/Usy2 ratio 0.50 .. 2.00 1.00 Matching ratio Usy1 / Usy2
220 I4 transformer Not connected
In prot. line
In paral. line
IY starpoint
In prot. line I4 current transformer is
221 I4/Iph CT 0.010 .. 5.000 1.000 Matching ratio I4/Iph for CT's
230 Rated Frequency 50 Hz
60 Hz
50 Hz Rated Frequency
235 PHASE SEQ. L1 L2 L3
L1 L3 L2
L1 L2 L3 Phase Sequence
236 Distance Unit km
Miles
km Distance measurement unit
237 Format Z0/Z1 RE/RL, XE/XL
K0
RE/RL, XE/XL Setting format for zero seq.comp.
format
238A EarthFltO/C 1p stages together
stages separat.
stages together Earth Fault O/C: setting for 1pole
AR
239 T-CB close 0.01 .. 0.60 sec 0.06 sec Closing (operating) time of CB
240A TMin TRIP CMD 0.02 .. 30.00 sec 0.10 sec Minimum TRIP Command Duration
241A TMax CLOSE CMD 0.01 .. 30.00 sec 0.10 sec Maximum Close Command Dura-
tion
242 T-CBtest-dead 0.00 .. 30.00 sec 0.10 sec Dead Time for CB test-autoreclo-
sure
Change Group
Purpose of the Setting Groups
Up to four different setting groups can be created for establishing the device's function settings. During opera-
tion, the user can locally switch between setting groups using the operator panel, binary inputs (if so config-
ured), the operator and service interface from a personal computer or via the system interface. For reasons of
safety, it is not possible to change between setting groups during a power system fault.
A setting group includes the setting values for all functions that have been selected during configuration
(Section 2.1.1.2 Setting Notes) as Enabled or an other active option. In 7SA522devices, four independent
setting groups (A to D) are available. Whereas setting values and options may vary, the selected scope of func-
tions is the same for all groups.
2.1.3
2.1.3.1
Functions
2.1 General
38 SIPROTEC 4, 7SA522, Manual
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Setting groups enable the user to save the corresponding settings for each application. When they are needed,
settings may be loaded quickly. All setting groups are stored in the relay. Only one setting group may be active
at a given time.
Setting Notes
General
If you do not want to change between several setting groups, then set only setting group A. Then, the rest of
this section is not applicable.
If multiple setting groups are desired, the setting group change option must be set to Grp Chge OPTION =
Enabled (Section 2.1.1.2 Setting Notes. address 103). Now the 4 setting groups A to D are available. They
are configured individually as required in the following. To find out how to proceed, how to copy and to reset
settings groups to the delivery state, and how to switch between setting groups during operation, please refer
to the SIPROTEC 4 System Description.
Two binary inputs enable changing between the 4 setting groups from an external source.
Settings
Addr. Parameter Setting Options Default Setting Comments
302 CHANGE Group A
Group B
Group C
Group D
Binary Input
Protocol
Group A Change to Another Setting Group
Information List
No. Information Type of
Informa-
tion
Comments
- P-GrpA act IntSP Setting Group A is active
- P-GrpB act IntSP Setting Group B is active
- P-GrpC act IntSP Setting Group C is active
- P-GrpD act IntSP Setting Group D is active
7 >Set Group Bit0 SP >Setting Group Select Bit 0
8 >Set Group Bit1 SP >Setting Group Select Bit 1
Power System Data 2
The general protection data (P.System Data 2) include settings associated with all functions rather than a
specific protection, monitoring or control function. In contrast to the P.System Data 1 as discussed before,
these can be changed over with the setting groups and can be configured via the operator panel of the device.
Setting Notes
Rating of the Protected Object
The rated primary voltage (phase-to-phase) and rated primary current (phases) of the protected equipment
are entered in the addresses 1103 FullScaleVolt. and 1104 FullScaleCurr.. These settings are
required for indication of operational measured values in percent. If these rated values match the primary VT's
and CT's, they correspond to the settings in address 203 and 205 (Section 2.1.2.1 Setting Notes).
2.1.3.2
2.1.3.3
2.1.3.4
2.1.4
2.1.4.1
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 39
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General Line Data
The settings of the line data in this case refer to the common data which is independent of the actual distance
protection grading.
The line angle (address 1105 Line Angle) may be derived from the line parameters. The following applies:
[formel-allg-ltgdaten-1-oz-310702, 1, en_GB]
where RL is the resistance and XL the reactance of the protected feeder. The line parameters may either apply
to the entire line length, or be per unit of line length as the quotient is independent of length. Furthermore, it
makes no difference whether the quotients are calculated with primary, or secondary values.
The line angle is of major importance, e.g. for earth impedance matching according to amount and angle or
for compounding in overvoltage protection.
Calculation Example:
110 kV overhead line 150 mm2 with the following data:
R'1 = 0,19 Ω/km
X'1 = 0,42 Ω/km
The line angle is computed as follows
[formel-allg-ltgdaten-2-oz-310702, 1, en_GB]
In address 1105 the setting Line Angle = 66°is entered.
Address 1211 Distance Angle specifies the angle of inclination of the R sections of the distance protection
polygons. In devices with MHO characteristic, this angle determines also the inclination of the MHO circles.
You can usually also set the line angle here as in address 1105.
The directional values (power, power factor, work and based on work: minimum, maximum, average and
threshold values), calculated in the operational measured values, are usually defined positive in the direction
towards the protected object. This requires that the connection polarity for the entire device was configured
accordingly in the Power System Data 1 (compare also “Polarity of Current Transformers”, address 201). But it
is also possible to define the “forward” direction for the protection functions and the positive direction for the
power etc. differently, e.g. so that the active power flow (from the line to the busbar) is indicated in the posi-
tive sense. Set under address 1107 P,Q sign the option reversed. If the setting is reversed (default), the
positive direction for the power etc. corresponds to the “forward” direction for the protection functions.
The reactance value X' of the protected line is entered as reference value x' at address 1110 in Ω/km if the
distance unit was set as kilometers (address 236, see section 2.1.2.1 Setting Notes at “Distance Unit”), or at
address 1112 in Ω/mile if miles were selected as distance unit. The corresponding line length is entered at
address 1111 Line Length in kilometers or at address 1113 in miles. If the distance unit in address 236 is
changed after the reactance per unit length in address 1112 or 1111 or the line length in address 1113 or
1110 have been entered, the line data have to be re-entered for the changed unit of length.
The capacitance value C' of the protected line is required for compounding in overvoltage protection. Without
compounding it is irrelevant.
It is entered as a reference value c' at address 1114 in μF/km if set to distance unit kilometers (address 236,
see Section 2.1.2.1 Setting Notes at “Distance Unit”), or at address 1115 in μF/mile if miles were set as
distance unit. If the distance unit is changed in address 236, then the relevant line data in the addresses from
1110 to 1115 have to be re-entered for the changed unit of length.
When entering the parameters with a personal computer running the DIGSI software, the values can also be
entered as primary values. If the nominal quantities of the primary transformers (U, Ι) are set to minimum,
primary values allow only a rough setting of the value parameters. In such cases it is preferable to set the
parameters in secondary quantities.
For conversion of primary values to secondary values the following applies in general:
Functions
2.1 General
40 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[formel-allg-ltgdaten-3-oz-310702, 1, en_GB]
Likewise, the following goes for the reactance setting of a line:
[formel-allg-ltgdaten-4-oz-310702, 1, en_GB]
where
NCT = Current transformer ratio
NVT = Transformation ratio of voltage transformer
The following applies for the capacitance per distance unit:
[formel-kapazitaetsbelag-wlk-190802, 1, en_GB]
Calculation Example:
110 kV overhead line 150 mm2 as above
R'1= 0.19 Ω/km
X'1= 0.42 Ω/km
C' = 0.008 µF/km
Current Transformer 600 A / 1 A
Voltage transformer 110 kV / 0.1 kV
The secondary per distance unit reactance is therefore:
[formel-allg-ltgdaten-5-oz-310702, 1, en_GB]
In address1110 the setting x' = 0,229 Ω/km is entered.
The secondary per distance unit capacitance is therefore:
[formel-kapazitaetsbelag-beispiel-wlk-190802, 1, en_GB]
In address 1114 the setting c' = 0,015 µF/km is entered.
Earth impedance ratio
Setting of the earth to line impedance ratio is an essential prerequisite for the accurate measurement of the
fault distance (distance protection, fault locator) during earth faults. This compensation is either achieved by
entering the resistance ratio RE/RL and the reactance ratio XE/XL or by entry of the complex earth (residual)
compensation factor K0. Which of these two entry options applies, was determined by the setting in address
237 Format Z0/Z1 (refer to Section 2.1.2.1 Setting Notes). Only the addresses applicable for this setting will
be displayed.
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 41
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Earth Impedance (Residual) Compensation with Scalar Factors RE/RL and XE/XL
When entering the resistance ratio RE/RL and the reactance ratio XE/XL the addresses 1116 to 1119 apply. They
are calculated separately, and do not correspond to the real and imaginary components of ZE/ZL. A computa-
tion with complex numbers is therefore not necessary! The ratios are obtained from system data using the
following formulas:
Resistance ratio: Reactance ratio:
With
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
These values can be applied either to the entire line or as per unit of length values since the quotients are
independent of length. Furthermore, it makes no difference whether the quotients are calculated with
primary, or secondary values.
Calculation Example
110 kV overhead line 150 mm2 with the data
R1/s = 0.19 Ω/km positive sequence impedance
X1/s = 0.42 Ω/km positive sequence impedance
R0/s = 0.53 Ω/km zero sequence impedance
X0/s = 1.19 Ω/km zero sequence impedance
where s = line length)
For earth impedance ratios, the following emerge:
[formel-erdimp-anpass-2-oz-310702, 1, en_GB]
The earth impedance (residual) compensation factor setting for the first zone Z1 may be different from that of
the remaining zones of the distance protection. This allows the setting of the exact values for the protected
line, while at the same time the setting for the back-up zones may be a close approximation even when the
following lines have substantially different earth impedance ratios (e.g. cable after an overhead line). Accord-
ingly, the settings for the address 1116 RE/RL(Z1) and 1117 XE/XL(Z1) are determined with the data of
the protected line, while the addresses 1118 RE/RL(> Z1) and 1119 XE/XL(> Z1) apply to the remaining
zones Z1B and Z2 up to Z6 (as seen from the relay location).
i
i
NOTE
When the addresses 1116 RE/RL(Z1) and 1118 RE/RL(> Z1) are set to about 2.0 or more, please keep
in mind that the zone reach in R direction should not be set higher than the value determined previously
(see Section 2.2.2.2 Setting Notes/margin heading Resistance Tolerance). If this is not observed, it may
happen that phase-toearth impedance loops are measured in an incorrect distance zone, which may lead to
loss of tripping coordination in the case of earth faults with fault resistances.
Functions
2.1 General
42 SIPROTEC 4, 7SA522, Manual
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Earth Impedance (Residual) Compensation with Magnitude and Angle (K0-Factor)
When the complex earth impedance (residual) compensation factor K0 is set, the addresses 1120 to 1123
apply. In this case it is important that the line angle is set correctly (address 1105, see margin heading
“General Line Data”) as the device needs the line angle to calculate the compensation components from the
K0. These earth impedance compensation factors are defined with their magnitude and angle which may be
calculated with the line data using the following equation:
[formel-erdimp-anpass-betr-wi-1-oz-310702, 1, en_GB]
Where
Z0= (complex) zero sequence impedance of the line
Z1= (complex) positive sequence impedance of the line
These values can be applied either to the entire line or as per unit of length values since the quotients are
independent of length. Furthermore, it makes no difference whether the quotients are calculated with
primary, or secondary values.
For overhead lines it is generally possible to calculate with scalar quantities as the angle of the zero sequence
and positive sequence system only differ by an insignificant amount. With cables however, significant angle
differences may exist as illustrated by the following example.
Calculation Example:
110 kV single-conductor oil-filled cable 3 · 185 mm2 Cu with the following data
Z1/s = 0.408 · ej73° Ω/km positive sequence impedance
Z0/s = 0.632 · ej18,4° Ω/km zero sequence impedance
(where s = line length
The calculation of the earth impedance (residual) compensation factor K0 results in:
[formel-erdimp-anpass-betr-wi-2-oz-310702, 1, en_GB]
[formel-erdimp-anpass-betr-wi-3-oz-310702, 1, en_GB]
The magnitude of K0 is therefore
[formel-erdimp-anpass-betr-wi-4-oz-310702, 1, en_GB]
When determining the angle, the quadrant of the result must be considered. The following table indicates the
quadrant and range of the angle which is determined by the signs of the calculated real and imaginary part of
K0.
Table 2-1 Quadrants and ranges of the angle K0
Real part Imaginary
part
tan φ(K0) Quadrant/range Calculation
+ + + I 0° ... +90° arc tan (|Im| / |Re|)
+ – – IV –90° ... 0° –arc tan (|Im| / |Re|)
Functions
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Real part Imaginary
part
tan φ(K0) Quadrant/range Calculation
– – + III –90° ... –180° arc tan (|Im| / |Re|) –180°
– + – II +90° ... +180° –arc tan (|Im| / |Re|) +180°
In this example the following result is obtained:
[formel-erdimp-anpass-betr-wi-5-oz-310702, 1, en_GB]
The magnitude and angle of the earth impedance (residual) compensation factors setting for the first zone Z1
and the remaining zones of the distance protection may be different. This allows the setting of the exact
values for the protected line, while at the same time the setting for the back-up zones may be a close approxi-
mation even when the following lines have substantially different earth impedance factors (e.g. cable after an
overhead line). Accordingly, the settings for the address 1120 K0 (Z1) and 1121 Angle K0(Z1)) are deter-
mined with the data of the protected line, while the addresses 1122 K0 (> Z1) and 1123 Angle K0(>
Z1) apply to the remaining zones Z1B and Z2 up to Z6 (as seen from the relay location).
i
i
NOTE
If a combination of values is set which is not recognized by the device, it operates with preset values K0 = 1
· e0°. The information
Dis.ErrorK0(Z1)
(No. 3654) or
DisErrorK0(>Z1)
(No. 3655) appears in the
event logs.
Parallel line mutual impedance (optional)
If the device is applied to a double circuit line (parallel lines) and parallel line compensation for the distance
and/or fault location function is used, the mutual coupling of the two lines must be considered. A prerequisite
for this is that the earth (residual) current of the parallel line has been connected to the measuring input Ι4 of
the device and that this was configured with the power system data (Section 2.1.2.1 Setting Notes) by setting
the appropriate parameters.
The coupling factors may be determined using the following equations:
Resistance ratio: Reactance ratio:
mit
R0M = Mutual zero sequence resistance (coupling resistance) of the line
X0M = Mutual zero sequence reactance (coupling reactance) of the line
R1= Positive sequence resistance of the line
X1= Positive sequence reactance of the line
These values can be applied either to the entire double circuit line length or based on a per unit of line length,
since the quotient is independent of length. Furthermore, it makes no difference whether the quotients are
calculated with primary, or secondary values.
These setting values only apply to the protected line and are entered in the addresses 1126 RM/RL Paral-
Line and 1127 XM/XL ParalLine.
For earth faults on the protected feeder there is in theory no additional distance protection or fault locator
measuring error when the parallel line compensation is used. The setting in address 1128 RATIO Par. Comp
is therefore only relevant for earth faults outside the protected feeder. It provides the current ratio ΙE/ΙEP for the
earth current balance of the distance protection (in Figure 2-3 for the device at location II), above which
compensation should take place. In general, a presetting of 85 % is sufficient. A more sensitive (larger) setting
has no advantage. Only in the case of a severe system asymmetry, or a very small coupling factor (XM/XL below
Functions
2.1 General
44 SIPROTEC 4, 7SA522, Manual
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approximately 0.4), may a smaller setting be useful. A more detailed explanation of parallel line compensation
can be found in Section 2.2.1 Distance protection, general settings under distance protection.
[reichw-paralltg-komp-oz-010802, 1, en_GB]
Figure 2-3 Distance with parallel line compensation at II
The current ratio may also be calculated from the desired distance of the parallel line compensation and vice
versa. The following applies (refer to Figure 2-3):
[formel-koppimp-paraltg-2-oz-010802, 1, en_GB]
Current transformer saturation
7SA522 contains a saturation detector which largely detects the measuring errors resulting from the satura-
tion of the current transformers and initiates a change of the measurement method of the distance protec-
tion. The threshold above which the saturation detector picks up can be set in address 1140 I-CTsat.
Thres.. This is the current level above which saturation may be present. The setting ∞ disables the saturation
detector. This parameter can only be altered in DIGSI at Display Additional Settings. If current transformer
saturation is expected, the following equation may be used as a thumb rule for this setting:
[formel-stromwdl-saettigung-oz-010802, 1, en_GB]
[formel-effkt-ueberstrfkt-wlk-090802, 1, en_GB]
PN= Nominal CT burden [VA]
Pi = Nominal CT internal burden [VA]
P' = Actual connected burden (protection device + connection cable)
i
i
NOTE
The parameter is only relevant for distance protection.
Circuit breaker status
Information regarding the circuit breaker position is required by various protection and supplementary func-
tions to ensure their optimal functionality. The device has a circuit breaker status recognition which processes
the status of the circuit breaker auxiliary contacts and contains also a detection based on the measured
currents and voltages for opening and closing (see also Section 2.20.1 Function Control).
In address 1130 the residual current PoleOpenCurrent is set, which will definitely not be exceeded when
the circuit breaker pole is open. If parasitic currents (e.g. through induction) can be excluded when the circuit
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 45
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breaker is open, this setting may be very sensitive. Otherwise this setting must be increased. Usually the
presetting is sufficient. This parameter can only be altered in DIGSI at Display Additional Settings.
The residual voltage PoleOpenVoltage, which will definitely not be exceeded when the circuit breaker pole
is open, is set in address 1131. Voltage transformers must be on the line side. The setting should not be too
sensitive because of possible parasitic voltages (e.g. due to capacitive coupling). It must in any event be set
below the smallest phase-earth voltage which may be expected during normal operation. Usually the preset-
ting is sufficient. This parameter can only be altered in DIGSI at Display Additional Settings.
The switch-on-to-fault activation (seal-in) time SI Time all Cl. (address 1132) determines the activation
period of the protection functions enabled during each energization of the line (e.g. fast tripping high-current
stage). This time is started by the internal circuit breaker switching detection when it recognizes energization
of the line or by the circuit breaker auxiliary contacts, if these are connected to the device via binary input to
provide information that the circuit breaker has closed. The time should therefore be set longer than the
circuit breaker operating time during closing plus the operating time of this protection function plus the circuit
breaker operating time during opening. This parameter can only be altered in DIGSI at Display Additional
Settings.
In address 1134 Line Closure the criteria for the internal recognition of line energization are determined.
only with ManCl means that only the manual close signal via binary input or the integrated control is eval-
uated as closure.
With the following 3 setting options, the manual close signal via binary input or the integrated control are
determined as closure always in addition.
I OR U or ManCl means that closure (message
Line closure
, no. 590 ) is detected if voltages and
currents exceed their corresponding pole open thresholds within the time SI Time all Cl. (address
1132).
CB OR I or M/C implies that either the currents or the states of the circuit breaker auxiliary contacts are
used to determine closure of the circuit breaker. If the voltage transformers are not situated on the line side,
the setting CB OR I or M/C must be used.
In the case of I or Man.Close only the currents or the manual close signal or the integrated control are
used to recognize closing of the circuit breaker.
Before each line energization detection, the breaker must be recognized as open for the settable time 1133 T
DELAY SOTF.
Address 1135 Reset Trip CMD determines under which conditions a trip command is reset. If CurrentO-
penPole is set, the trip command is reset as soon as the current disappears. It is important that the value set
in address 1130 PoleOpenCurrent (see above) is undershot. If Current AND CB is set, the circuit breaker
auxiliary contact must send a message that the circuit breaker is open. It is a prerequisite for this setting that
the position of the auxiliary contacts is allocated via a binary input.
For special applications, in which the device trip command does not always lead to a complete cutoff of the
current, the setting Pickup Reset can be chosen. In this case, the trip command is reset as soon as the
pickup of the tripping protection function drops off and - just as with the other setting options- the minimum
trip command duration (address 240) has elapsed. The setting Pickup Reset makes sense, for instance,
during the test of the protection equipment, when the system-side load current cannot be cut off and the test
current is injected in parallel to the load current.
While the time SI Time all Cl. (address 1132, refer above) is activated following each recognition of line
energization, SI Time Man.Cl (address 1150) is the time following manual closure during which special
influence of the protection functions is activated (e.g. increased reach of the distance protection). This param-
eter can only be altered in DIGSI at Display Additional Settings.
Functions
2.1 General
46 SIPROTEC 4, 7SA522, Manual
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i
i
NOTE
For CB Test and automatic reclosure the CB auxiliary contact status derived with the binary inputs >CB1 ...
(No. 366 to 371, 410 and 411) is relevant to indicate the CB switching status. The other binary inputs
>CB ... (No. 351 to 353, 379 and 380) are used for detecting the status of the line (address 1134) and for
reset of the trip command (address 1135). Address 1135 is also used by other protection functions, e.g. by
the echo function, energization in case of overcurrent etc. For use with one circuit breaker only, both
binary input functions, e.g. 366 and 351, can be allocated to the same physical input. For applications with
2 circuit breakers per feeder (1.5 circuit breaker systems or ring bus), the binary inputs >CB1... must be
connected to the correct circuit breaker. The binary inputs >CB... then need the correct signals for detecting
the line status. In certain cases, an additional CFC logic may be necessary.
Address 1136 OpenPoleDetect. defines the criteria for operating the internal open-pole detector (see also
Section 2.20.1 Function Control, Subsection Open-Pole Detector). When using the default setting w/ meas-
urement, all available data are evaluated that indicate single-pole dead time. The internal trip command and
pickup indications, the current and voltage measured values and the CB auxiliary contacts are used. To eval-
uate only the auxiliary contacts including the phase currents, set the address 1136 to Current AND CB. If
you do not wish to detect single-pole dead time, set OpenPoleDetect. to OFF.
For manual closure of the circuit breaker via binary inputs, it can be specified in address 1151 MAN. CLOSE
whether the integrated manual CLOSE detection checks the synchronism between the busbar voltage and the
voltage of the switched feeder. This setting does not apply for a close command via the integrated control
functions. If the synchronism check is desired, the device must either feature the integrated synchronism
check function or an external device for synchronism check must be connected.
If the internal synchronism check is to be used, the synchronism check function must be enabled; an addi-
tional voltage Usy2 for synchronism check has to be connected to the device and this must be correctly para-
meterised in the Power System Data (Section 2.1.2.1 Setting Notes, address 210 U4 transformer = Usy2
transf. and the associated factors).
If no synchronism check is to be performed with manual closing, set MAN. CLOSE = w/o Sync-check. If a
check is desired, set with Sync-check. To not use the MANUAL CLOSE function of the device, set MAN.
CLOSE to NO. This may be reasonable if the close command is output to the circuit breaker without involving
the 7SA522, and the relay itself is not desired to issue a close command.
For commands via the integrated control (on site, DIGSI, serial interface) address 1152 Man.Clos. Imp.
determines whether a close command via the integrated control regarding the MANUAL CLOSE handling for
the protection functions (like instantaneous re-opening when switching onto a fault) is to act like a MANUAL
CLOSE command via binary input. This address also informs the device to which switchgear this applies. You
can select from the switching devices which are available to the integrated control. Select the circuit breaker
which operates for manual closure and, if required, for automatic reclosure (usually Q0). If kein is set here, a
CLOSE command via the control will not generate a MANUAL CLOSE impulse for the protection function.
Three-pole coupling
Three-pole coupling is only relevant if single-pole auto-reclosures are carried out. If not, tripping is always
three-pole. The remainder of this margin heading is then irrelevant.
Address 1155 3pole coupling determines whether any multi-phase pickup leads to a three-pole tripping
command, or whether only multi-pole tripping decisions result in a three-pole tripping command. This setting
is only relevant for versions with single-pole and three-pole tripping and is only available there.
More information on the function is also given in Section 2.20.1 Function Control Pickup Logic for the Entire
Device.
With the setting with PICKUP every fault detection in more than one phase leads to three-pole coupling of
the trip outputs, even if only a single-phase earth fault is situated within the tripping region, and further faults
only affect the higher zones, or are located in the reverse direction. Even if a single-phase trip command has
already been issued, each further fault detection will lead to three-pole coupling of the trip outputs.
If, on the other hand, this address is set to with TRIP, three-pole coupling of the trip output (three-pole trip-
ping) only occurs when more than one pole is tripped. Therefore, if a single-phase fault occurs within the trip
zone and a further fault outside of it, single-pole tripping is possible. A further fault during the single-pole trip-
ping will only lead to a three-pole coupling, if it occurs within the trip zone.
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 47
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This parameter is valid for all protection functions of 7SA522 which are capable of single-pole tripping.
The difference made by this parameter becomes apparent when multiple faults are cleared, i.e. faults occur-
ring almost simultaneously at different locations in the network.
If, for example, two single-phase earth faults occur on different lines — these may also be parallel lines —
(Figure 2-4), the protection relays detect the fault type on all four line ends L1-L2-E, i.e. the pickup image
corresponds to a two-phase earth fault. If single pole tripping and reclosure is employed, it is therefore desir-
able that each line only trips and recloses single pole. This is possible with setting 1155 3pole coupling =
with TRIP. Each of the four devices detects a single-pole internal fault and can thus trip single-pole.
[mehrfachfehler-doppelltg-oz-010802, 1, en_GB]
Figure 2-4 Multiple fault on a double-circuit line
In some cases, however, three-pole tripping would be preferable for this fault scenario, for example in the
event that the double-circuit line is located in the vicinity of a large generator unit (Figure 2-5). This is because
the generator considers the two single-phase ground faults as one double-phase ground fault, with corre-
spondingly high dynamic load on the turbine shaft. With the setting 1155 3pole coupling = with
PICKUP, the two lines are switched off three-pole, since each device picks up as with L1-L2-E, i.e. as with a
multi-phase fault.
[generator-mehrfachfehler-doppelltg-oz-010802, 1, en_GB]
Figure 2-5 Multiple fault on a double-circuit line next to a generator
Address 1156 Trip2phFlt determines that the short-circuit protection functions perform only a single-pole
trip in case of isolated two-phase faults (clear of ground), provided that single-pole tripping is possible and
permitted. This allows a single-pole reclose cycle for this kind of fault. You can specify whether the leading
phase (1pole leading Ø), or the lagging phase (1pole lagging Ø) is tripped. The parameter is only
available in versions with single-pole and three-pole tripping. This parameter can only be altered using DIGSI
at Additional Settings. If this possibility is to be used, you have to bear in mind that the phase selection
should be the same throughout the entire network and that it must be the same at all ends of one line. More
information on the functions is also contained in Section 2.20.1 Function Control Pickup Logic of the Entire
Device. The presetting 3pole is usually used.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
1103 FullScaleVolt. 1.0 .. 1200.0 kV 400.0 kV Measurement: Full Scale
Voltage (100%)
1104 FullScaleCurr. 10 .. 5000 A 1000 A Measurement: Full Scale
Current (100%)
1105 Line Angle 10 .. 89 ° 85 ° Line Angle
2.1.4.2
Functions
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48 SIPROTEC 4, 7SA522, Manual
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Addr. Parameter C Setting Options Default Setting Comments
1107 P,Q sign not reversed
reversed
not reversed P,Q operational measured
values sign
1110 x' 1A 0.0050 .. 9.5000 Ω/km 0.1500 Ω/km x' - Line Reactance per
length unit
5A 0.0010 .. 1.9000 Ω/km 0.0300 Ω/km
1111 Line Length 0.1 .. 1000.0 km 100.0 km Line Length
1112 x' 1A 0.0050 .. 15.0000 Ω/mi 0.2420 Ω/mi x' - Line Reactance per
length unit
5A 0.0010 .. 3.0000 Ω/mi 0.0484 Ω/mi
1113 Line Length 0.1 .. 650.0 Miles 62.1 Miles Line Length
1114 c' 1A 0.000 .. 100.000 µF/km 0.010 µF/km c' - capacit. per unit line
len. µF/km
5A 0.000 .. 500.000 µF/km 0.050 µF/km
1115 c' 1A 0.000 .. 160.000 µF/mi 0.016 µF/mi c' - capacit. per unit line
len. µF/mile
5A 0.000 .. 800.000 µF/mi 0.080 µF/mi
1116 RE/RL(Z1) -0.33 .. 10.00 1.00 Zero seq. comp. factor
RE/RL for Z1
1117 XE/XL(Z1) -0.33 .. 10.00 1.00 Zero seq. comp. factor
XE/XL for Z1
1118 RE/RL(> Z1) -0.33 .. 10.00 1.00 Zero seq. comp.factor RE/
RL(> Z1)
1119 XE/XL(> Z1) -0.33 .. 10.00 1.00 Zero seq. comp.factor XE/
XL(> Z1)
1120 K0 (Z1) 0.000 .. 4.000 1.000 Zero seq. comp. factor K0
for zone Z1
1121 Angle K0(Z1) -180.00 .. 180.00 ° 0.00 ° Zero seq. comp. angle for
zone Z1
1122 K0 (> Z1) 0.000 .. 4.000 1.000 Zero seq.comp.factor
K0,higher zones >Z1
1123 Angle K0(> Z1) -180.00 .. 180.00 ° 0.00 ° Zero seq. comp. angle,
higher zones >Z1
1126 RM/RL ParalLine 0.00 .. 8.00 0.00 Mutual Parallel Line comp.
ratio RM/RL
1127 XM/XL ParalLine 0.00 .. 8.00 0.00 Mutual Parallel Line comp.
ratio XM/XL
1128 RATIO Par. Comp 50 .. 95 % 85 % Neutral current RATIO
Parallel Line Comp
1130A PoleOpenCurrent 1A 0.05 .. 1.00 A 0.10 A Pole Open Current
Threshold
5A 0.25 .. 5.00 A 0.50 A
1131A PoleOpenVoltage 2 .. 70 V 30 V Pole Open Voltage
Threshold
1132A SI Time all Cl. 0.01 .. 30.00 sec 0.05 sec Seal-in Time after ALL
closures
1133A T DELAY SOTF 0.05 .. 30.00 sec 0.25 sec minimal time for line open
before SOTF
1134 Line Closure only with ManCl
I OR U or ManCl
CB OR I or M/C
I or Man.Close
only with ManCl Recognition of Line
Closures with
1135 Reset Trip CMD CurrentOpenPole
Current AND CB
Pickup Reset
CurrentOpenPole RESET of Trip Command
Functions
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SIPROTEC 4, 7SA522, Manual 49
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Addr. Parameter C Setting Options Default Setting Comments
1136 OpenPoleDetect. OFF
Current AND CB
w/ measurement
w/ measurement open pole detector
1140A I-CTsat. Thres. 1A 0.2 .. 50.0 A; ∞ 20.0 A CT Saturation Threshold
5A 1.0 .. 250.0 A; ∞ 100.0 A
1150A SI Time Man.Cl 0.01 .. 30.00 sec 0.30 sec Seal-in Time after MANUAL
closures
1151 MAN. CLOSE with Sync-check
w/o Sync-check
NO
NO Manual CLOSE COMMAND
generation
1152 Man.Clos. Imp. (Einstellmöglichkeiten
anwendungsabhängig)
none MANUAL Closure Impulse
after CONTROL
1155 3pole coupling with PICKUP
with TRIP
with TRIP 3 pole coupling
1156A Trip2phFlt 3pole
1pole leading Ø
1pole lagging Ø
3pole Trip type with 2phase
faults
1211 Distance Angle 30 .. 90 ° 85 ° Angle of inclination,
distance charact.
Information List
No. Information Type of
Informa-
tion
Comments
301 Pow.Sys.Flt. OUT Power System fault
302 Fault Event OUT Fault Event
303 E/F Det. OUT E/Flt.det. in isol/comp.netw.
351 >CB Aux. L1 SP >Circuit breaker aux. contact: Pole L1
352 >CB Aux. L2 SP >Circuit breaker aux. contact: Pole L2
353 >CB Aux. L3 SP >Circuit breaker aux. contact: Pole L3
356 >Manual Close SP >Manual close signal
357 >Blk Man. Close SP >Block manual close cmd. from external
361 >FAIL:Feeder VT SP >Failure: Feeder VT (MCB tripped)
362 >FAIL:U4 VT SP >Failure: Usy4 VT (MCB tripped)
366 >CB1 Pole L1 SP >CB1 Pole L1 (for AR,CB-Test)
367 >CB1 Pole L2 SP >CB1 Pole L2 (for AR,CB-Test)
368 >CB1 Pole L3 SP >CB1 Pole L3 (for AR,CB-Test)
371 >CB1 Ready SP >CB1 READY (for AR,CB-Test)
378 >CB faulty SP >CB faulty
379 >CB 3p Closed SP >CB aux. contact 3pole Closed
380 >CB 3p Open SP >CB aux. contact 3pole Open
381 >1p Trip Perm SP >Single-phase trip permitted from ext.AR
382 >Only 1ph AR SP >External AR programmed for 1phase only
383 >Enable ARzones SP >Enable all AR Zones / Stages
385 >Lockout SET SP >Lockout SET
386 >Lockout RESET SP >Lockout RESET
410 >CB1 3p Closed SP >CB1 aux. 3p Closed (for AR, CB-Test)
411 >CB1 3p Open SP >CB1 aux. 3p Open (for AR, CB-Test)
2.1.4.3
Functions
2.1 General
50 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Information Type of
Informa-
tion
Comments
501 Relay PICKUP OUT Relay PICKUP
503 Relay PICKUP L1 OUT Relay PICKUP Phase L1
504 Relay PICKUP L2 OUT Relay PICKUP Phase L2
505 Relay PICKUP L3 OUT Relay PICKUP Phase L3
506 Relay PICKUP E OUT Relay PICKUP Earth
507 Relay TRIP L1 OUT Relay TRIP command Phase L1
508 Relay TRIP L2 OUT Relay TRIP command Phase L2
509 Relay TRIP L3 OUT Relay TRIP command Phase L3
510 Relay CLOSE OUT Relay GENERAL CLOSE command
511 Relay TRIP OUT Relay GENERAL TRIP command
512 Relay TRIP 1pL1 OUT Relay TRIP command - Only Phase L1
513 Relay TRIP 1pL2 OUT Relay TRIP command - Only Phase L2
514 Relay TRIP 1pL3 OUT Relay TRIP command - Only Phase L3
515 Relay TRIP 3ph. OUT Relay TRIP command Phases L123
530 LOCKOUT IntSP LOCKOUT is active
533 IL1 = VI Primary fault current IL1
534 IL2 = VI Primary fault current IL2
535 IL3 = VI Primary fault current IL3
536 Definitive TRIP OUT Relay Definitive TRIP
545 PU Time VI Time from Pickup to drop out
546 TRIP Time VI Time from Pickup to TRIP
560 Trip Coupled 3p OUT Single-phase trip was coupled 3phase
561 Man.Clos.Detect OUT Manual close signal detected
562 Man.Close Cmd OUT CB CLOSE command for manual closing
563 CB Alarm Supp OUT CB alarm suppressed
590 Line closure OUT Line closure detected
591 1pole open L1 OUT Single pole open detected in L1
592 1pole open L2 OUT Single pole open detected in L2
593 1pole open L3 OUT Single pole open detected in L3
Functions
2.1 General
SIPROTEC 4, 7SA522, Manual 51
C53000-G1176-C155-9, Edition 05.2016
Distance Protection
Distance protection is the main function of the device. It is characterized by high measuring accuracy and the
ability to adapt to the given system conditions. It is supplemented by a number of additional functions.
Distance protection, general settings
Erdfehlererkennung
Functional Description
Recognition of an earth fault is an important element in identifying the type of fault, as the determination of
the valid loops for measurement of the fault distance and the shape of the distance zone characteristics
substantially depend on whether the fault at hand is an earth fault or not. The 7SA522 has a stabilized earth
current measurement, a zero sequence current/negative sequence current comparison as well as a displace-
ment voltage measurement.
Furthermore, special measures are taken to avoid a pickup for single earth faults in an isolated or resonan-
tearthed system.
Earth Current 3Ι0
For earth current measurement, the fundamental component of the sum of the numerically filtered phase
currents is supervised to detect if it exceeds the set value (parameter 3I0> Threshold). It is stabilized
against spurious operation resulting from unsymmetrical operating currents and error currents in the secon-
dary circuits of the current transformer due to different degrees of current transformer saturation during
short-circuits without earth: the actual pick-up threshold automatically increases as the phase current
increases (Figure 2-6). The dropout threshold is approximately 95 % of the pickup threshold.
[erdstrom-ansprechkennl-270702-wlk, 1, en_GB]
Figure 2-6 Earth current stage: pickup characteristic
Negative Sequence Current 3Ι2
On long, heavily loaded lines, large currents could cause excessive restraint of the earth current measurement
(ref. Figure 2-6). To ensure secure detection of earth faults in this case, a negative sequence comparison stage
is additionally provided. In the event of a single-phase fault, the negative sequence current Ι2 has approxi-
mately the same magnitude as the zero sequence current Ι0. When the ratio zero sequence current / negative
sequence current exceeds a preset ratio, this stage picks up. For this stage a parabolic characteristic provides
restraint in the event of large negative sequence currents. Figure 2-7 illustrates this relationship. A release by
means of the negative sequence current comparison stage requires currents of at least 0.2·ΙN for 3Ι0 and 3Ι2.
2.2
2.2.1
2.2.1.1
Functions
2.2 Distance Protection
52 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[kennliniederi0i2stufe-270702-wlk, 1, en_GB]
Figure 2-7 Characteristic of the Ι0/Ι2 stage
Displacement Voltage 3U0
For the neutral displacement voltage recognition the displacement voltage (3·U0) is numerically filtered and
the fundamental frequency is monitored to recognize whether it exceeds the set threshold. The dropout
threshold is approximately 95 % of the pickup threshold. In earthed systems (3U0> Threshold) it can be
used as an additional criterion for earth faults. For earthed systems, the U0–criterion may be disabled by
applying the ∞ setting.
Logical Combination for Earthed Systems
The current and voltage criteria supplement each other, as the displacement voltage increases when the zero
sequence to positive sequence impedance ratio is large, whereas the earth current increases when the zero
sequence to positive sequence impedance ratio is smaller. Therefore, the current and voltage criteria for
earthed systems are normally ORed. However, the two criteria may also be ANDed (settable, see Figure 2-8).
Setting 3U0> Threshold to infinite makes this criterion ineffective.
If the device detects a current transformer saturation in any phase current, the voltage criterion is indeed
crucial to the detection of an earth fault since irregular current transformer saturation can cause a faulty
secondary zero-sequence current although no primary zero-sequence current is present.
If displacement voltage detection has been made ineffective by setting 3U0> Threshold to infinite, earth
fault detection with the current criterion is possible even if the current transformers are saturated.
The earth fault detection alone does not cause a general fault detection of the distance protection, but merely
controls the further fault detection modules. It is only alarmed in case of a general fault detection.
Functions
2.2 Distance Protection
SIPROTEC 4, 7SA522, Manual 53
C53000-G1176-C155-9, Edition 05.2016
[logik-der-erdfehlererkennung-240402-wlk, 1, en_GB]
Figure 2-8 Earth fault detection logic for earthed systems
Earth fault detection during single-pole open condition
In order to prevent undesired pickup of the earth fault detection caused by load currents during single-pole
open condition, a modified earth fault detection is used during single-pole open condition in earthed power
systems (Figure 2-9). In this case, the magnitudes of the currents and voltages are monitored in addition to
the angles between the currents.
[erdfehlererkennung-waehrend-einpoliger-abschaltung-wlk-260702, 1, en_GB]
Figure 2-9 Earth fault detection during single-pole open condition (example: single-pole dead time L1)
Logical Combination for Non-earthed Systems
In compensated or isolated networks, an earth pickup is only initiated after a pickup of the zero-sequence
current criterion. It should be considered that the zero-sequence voltage criterion with the parameter 1205
3U0> COMP/ISOL. is used for the confirmation of an earth pickup in case of double earth faults with current
transformer saturation.
The 3I0 threshold is reduced in case of asymmetrical phase-to-phase voltages in order to allow earth pickup
even in the case of double earth faults with very low zero sequence current. The zero-sequence voltage crite-
rion is not used solely as the distance measurement for phase-to-earth loops tends to overreach if the earth
current is missing. If the current transformer is saturated and the parameter 1205 is not set to ∞, an earth
fault detection by means of the I0 criterion alone is not possible and a verification of the pickup by means of
the U0 criterion is initiated.
The maximum asymmetry to be expected for a load current or a single earth fault can be set via parameter
1223 Uph-ph unbal.. Furthermore, in these systems, a simple earth fault is assumed initially and the pickup
is suppressed in order to avoid erroneous pickup as a result of the earth fault inception transients. After a
configurable delay time T3I0 1PHAS, the pickup is released again; this is necessary to ensure that the
distance protection is still able to detect a double earth fault with one base point on a dead-end feeder. If the
phase-tophase voltages are asymmetrical, this indicates a double earth fault and the pickup is released imme-
diately.
Functions
2.2 Distance Protection
54 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[symmetrieerkennung-st-090705, 1, en_GB]
Figure 2-10 Symmetry detection for phase-to-phase voltages
k= Setting value for parameter 1223
[erdfehlererk-isoliert-geloescht-st-090705, 2, en_GB]
Figure 2-11 Earth fault detection in isolated or resonant-earthed systems
Calculation of the Impedances
A separate measuring system is provided for each of the six possible impedance loops L1-E, L2-E, L3-E, L1-L2,
L2-L3, L3-L1. The phase-to-earth loops are evaluated when an earth fault detection is recognized and the
phase current exceeds a settable minimum value Minimum Iph>. The phase-to-phase loops are evaluated
when the phase current in both of the affected phases exceeds the minimum value Minimum Iph>.
A jump detector synchronizes all the calculations with the fault inception. If a further fault occurs during the
evaluation, the new measured values are immediately used for the calculation. The fault evaluation is there-
fore always done with the measured values of the current fault condition.
Phase-to-Phase Loops
To calculate the phase-to-phase loop, for instance during a two-phase short circuit L1-L2 (Figure 2-12), the
loop equation is:
2.2.1.2
Functions
2.2 Distance Protection
SIPROTEC 4, 7SA522, Manual 55
C53000-G1176-C155-9, Edition 05.2016
ΙL1 · ZL – ΙL2 · ZL = UL1-E – UL2-E
with
U, Ιthe (complex) measured quantities and
Z = R + jX the (complex) line impedance.
The line impedance is computed to be
[formel-leitungsimpedanz-wlk-260702, 1, en_GB]
[kurzschluss-einer-leiter-leiter-schleife-wlk-260702, 1, en_GB]
Figure 2-12 Two-phase fault clear of earth, fault loop
The calculation of the phase-to-phase loops does not take place as long as one of the concerned phases is
switched off (during single-pole dead time) to avoid an incorrect measurement with the undefined measured
values existing during this state. A state recognition (refer to Section 2.20.1 Function Control) provides the
corresponding blocking signal. A logic block diagram of the phase-to-phase measuring system is shown in
Figure Figure 2-13.
[logik-fuer-ein-leiter-leiter-messwerk-240402wlk, 1, en_GB]
Figure 2-13 Logic for a phase–phase measuring unit, shown by the example of the L1-L2 loop
Phase-to-Earth Loops
For the calculation of the phase-to-earth loop, for example during an L3-E short-circuit (Figure 2-14) it must be
noted that the impedance of the earth return path does not correspond to the impedance of the phase.
Functions
2.2 Distance Protection
56 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[kurzschluss-einer-leiter-erde-schleife-wlk-260702, 1, en_GB]
Figure 2-14 Single-phase earth fault, fault loop
In the faulted loop
[leitererdeschleifeanpasstfktrx-formel-wlk-040527, 1, en_GB]
the voltage UL3-E, the phase current ΙL3 and the earth current ΙE are measured. The impedance to the fault loca-
tion results from:
[leitererdeschleifer-formel-wlk-040527, 1, en_GB]
and
[leitererdeschleifex-formel-wlk-040527, 1, en_GB]
with
UL3-E = r.m.s.value of the short-circuit voltage
ΙL3 = r.m.s. value of the phase short-circuit current
ΙE= r.m.s. value of the earth short-circuit current
φU= phase angle of the short-circuit voltage
φL= phase angle of the phase short-circuit current
φE= phase angle of the earth short-circuit current
The factors RE/RL and XE/XL are dependent only on the line constants, and no longer on the distance to fault.
The calculation of the phase-to-earth loops does not take place as long as the concerned phase is switched off
(during single-pole dead time) to avoid an incorrect measurement with the now undefined measured values.
A state recognition provides the corresponding blocking signal. A logic block diagram of the phase-to-earth
measuring system is shown in Figure 2-15.
Functions
2.2 Distance Protection
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C53000-G1176-C155-9, Edition 05.2016
[logik-fuer-ein-leiter-erde-messwerk-240402wlk, 1, en_GB]
Figure 2-15 Logic of the phase-earth measuring system
Unfaulted Loops
The above considerations apply to the relevant short-circuited loop. All six loops are calculated for the impe-
dance pickup; the impedances of the unfaulted loops are also influenced by the short-circuit currents and
voltages in the short-circuited phases. During an L1-E fault for example, the short-circuit current in phase L1
also appears in the measuring loops L1-L2 and L3-L1. The earth current is also measured in loops L2-E and L3-
E. Combined with load currents which may flow, the unfaulted loops produce the so called „apparent impe-
dances“ which have nothing to do with the actual fault distance.
These “apparent impedances” in the unfaulted loops are usually larger than the short-circuit impedance of the
faulted loop because the unfaulted loop only carries a part of the fault current and always has a larger voltage
than the faulted loop. For the selectivity of the zones, they are usually of no consequence.
Apart from the zone selectivity, the phase selectivity is also important to achieve a correct identification of
the faulted phases, to alarm the faulted phases and especially to enable single-pole automatic reclosure.
Depending on the infeed conditions, close-in short-circuits may cause unfaulted loops to “see” the fault further
away than the faulted loop, but still within the tripping zone. This would cause three-pole tripping and there-
fore void the possibility of single-pole automatic reclosure. As a result power transfer via the line would be
lost.
In the 7SA522 this is avoided by the implementation of a “loop verification” function which operates in two
steps:
Initially, the calculated loop impedance and its components (phase or earth) are used to simulate a replica of
the line impedance. If this simulation returns a plausible line image, the corresponding loop pick-up is desig-
nated as a definitely valid loop.
If the impedances of more than one loop are now located within the range of the zone, the smallest is still
declared to be a valid loop. Furthermore, all loops with an impedance that does not exceed the smallest loop
impedance by more than 50 % are declared as being valid. Loops with larger impedance are eliminated. Those
loops which were declared valid in the initial stage cannot be eliminated by this stage, even if they have larger
impedances.
In this manner unfaulted “apparent impedances” are eliminated on the one hand, while on the other hand,
unsymmetrical multi-phase faults and multiple short-circuits are recognized correctly.
The loops that were designated as being valid are converted to phase information so that the fault detection
correctly alarms the faulted phases.
Double Faults in Earthed Systems
In systems with an effectively or low-resistant earthed starpoint, each connection of a phase with earth results
in a short-circuit condition which must be isolated immediately by the closest protection systems. Fault detec-
tion occurs in the faulted loop associated with the faulted phase.
With double earth faults, fault detection is generally in two phase-to-earth loops. If both earth loops are in the
same direction, a phase-to-phase loop may also pick up. It is possible to restrict the fault detection to particular
loops in this case. It is often desirable to block the phase-to-earth loop of the leading phase, as this loop tends
to overreach when there is infeed from both ends to a fault with a common earth fault resistance (Parameter
1221 2Ph-E faults = Block leading Ø). Alternatively, it is also possible to block the lagging phase-
Functions
2.2 Distance Protection
58 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
toearth loop (Parameter 2Ph-E faults = Block lagging Ø). All the affected loops can also be evaluated
(Parameter 2Ph-E faults = All loops), or only the phase-to-phase loop (Parameter 2Ph-E faults = Ø-
Ø loops only) or only the phase-to-earth loops (Parameter 2Ph-E faults = Ø-E loops only). All
these restrictions presuppose that the affected loops have the same direction.
In Table 2-2 the measured values used for the distance measurement in earthed systems during double earth
faults are shown.
Table 2-2 Evaluation of the measured loops for double earth faults in an earthed system in case both
earth faults are close to each other
Loop pickup Evaluated loop(s) Setting of parameter1221
L1-E, L2-E, L1-L2
L2-E, L3-E, L2-L3
L1-E, L3-E, L3-L1
L2-E, L1-L2
L3-E, L2-L3
L1-E, L3-L1
2Ph-E faults = Block
leading Ø
L1-E, L2-E, L1-L2
L2-E, L3-E, L2-L3
L1-E, L3-E, L3-L1
L1-E, L1-L2
L2-E, L2-L3
L3-E, L3-L1
2Ph-E faults = Block
lagging Ø
L1-E, L2-E, L1-L2
L2-E, L3-E, L2-L3
L1-E, L3-E, L3-L1
L1-E, L2-E, L1-L2
L2-E, L3-E, L2-L3
L1-E, L3-E, L3-L1
2Ph-E faults = All loops
L1-E, L2-E, L1-L2
L2-E, L3-E, L2-L3
L1-E, L3-E, L3-L1
L1-L2
L2-L3
L3-L1
2Ph-E faults = Ø-Ø loops
only
L1-E, L2-E, L1-L2
L2-E, L3-E, L2-L3
L1-E, L3-E, L3-L1
L1-E, L2-E
L2-E, L3-E
L1-E, L3-E
2Ph-E faults = Ø-E loops
only
During three-phase faults, usually all three phase-to-phase loops pick up In this case the three phase-to-phase
loops are evaluated. If earth fault detection also occurs, the phase-to-earth loops are also evaluated.
Double earth faults in non-earthed systems
In isolated or resonant-earthed networks a single-phase earth fault does not result in a short circuit current
flow. There is only a displacement of the voltage triangle (Figure 2-16). For the system operation this state is
no immediate danger. The distance protection must not pick up in this case even though the voltage of the
phase with the earth fault is equal to zero in the whole galvanically connected system. Any load currents will
result in an impedance value that is equal to zero. Accordingly, a single-phase pickup phase-to-earth is
prevented without earth current pickup in the 7SA522.
[erdschluss-im-nicht-geerdeten-netz-260702-wlk, 1, en_GB]
Figure 2-16 Earth fault in non-earthed neutral system
With the occurrence of earth faults — especially in large resonant-earthed systems — large fault inception
transient currents can appear that may evoke the earth current pickup. In case of an overcurrent pick-up there
may also be a phase current pickup. The 7SA522 features special measures against such spurious pickups.
Functions
2.2 Distance Protection
SIPROTEC 4, 7SA522, Manual 59
C53000-G1176-C155-9, Edition 05.2016
With the occurrence of a double earth fault in isolated or resonant-earthed systems it is sufficient to switch off
one of the faults. The second fault may remain in the system as a simple earth fault. Which of the faults is
switched off depends on the double earth fault preference which is set the same in the whole galvanically-
connected system. With7SA522 the following double earth fault preferences (Parameter 1220 PHASE PREF.
2phe) can be selected:
Acyclic L3 before L1 before L2 L3 (L1) ACYCLIC
Acyclic L1 before L3 before L2 L1 (L3) ACYCLIC
Acyclic L2 before L1 before L3 L2 (L1) ACYCLIC
Acyclic L1 before L2 before L3 L1 (L2) ACYCLIC
Acyclic L3 before L2 before L1 L3 (L2) ACYCLIC
Acyclic L2 before L3 before L1 L2 (L3) ACYCLIC
zyklisch L3 before L1 before L2 before L3 L3 (L1) CYCLIC
zyklisch L1 before L3 before L2 before L1 L1 (L3) CYCLIC
All loops are measured All loops
In all eight preference options, one earth fault is switched off according to the preference scheme. The second
fault can remain in the system as a simple earth fault. It can be detected with the Earth Fault Detection in
Nonearthed Systems (optional).
The 7SA522 also enables the user to switch off both fault locations of a double earth fault. Set the double
earth fault preference to All loops.
Table 2-3 lists all measured values used for the distance measuring in isolated or resonant-earthed systems.
Table 2-3 Evaluation of the Measuring Loops for Multi-phase Pickup in the Non-earthed Network
Loop pickup Evaluated loop(s) Setting of parameter 1220
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L1-E
L3-E
L3-E
PHASE PREF.2phe = L3 (L1)
ACYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L1-E
L3-E
L1-E
PHASE PREF.2phe = L1 (L3)
ACYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L2-E
L2-E
L1-E
PHASE PREF.2phe = L2 (L1)
ACYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L1-E
L2-E
L1-E
PHASE PREF.2phe = L1 (L2)
ACYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L2-E
L3-E
L3-E
PHASE PREF.2phe = L3 (L2)
ACYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L2-E
L2-E
L3-E
PHASE PREF.2phe = L2 (L3)
ACYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L1-E
L2-E
L3-E
PHASE PREF.2phe = L3 (L1)
CYCLIC
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L2-E
L3-E
L1-E
PHASE PREF.2phe = L1 (L3)
CYCLIC
Functions
2.2 Distance Protection
60 SIPROTEC 4, 7SA522, Manual
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Loop pickup Evaluated loop(s) Setting of parameter 1220
L1-E, L2-E, (L1-L2)
L2-E, L3-E, (L2-L3)
L1-E, L3-E, (L3-L1)
L1-E, L2-E
L2-E, L3-E
L3-E; L1-E
PHASE PREF.2phe = All loops
Parallel line measured value correction (optional)
During earth faults on parallel lines, the impedance values calculated by means of the loop equations are influ-
enced by the coupling of the earth impedance of the two conductor systems (Figure 2-17). This causes meas-
uring errors in the result of the impedance computation unless special measures are taken. A parallel line
compensation may therefore be activated. In this manner the earth current of the parallel line is taken into
consideration by the line equation and thereby allows for compensation of the coupling influence. The earth
current of the parallel line must be connected to the device for this purpose. The loop equation is then as
shown below, refer also to Figure 2-14.
ΙL3 · ZL – ΙE · ZE – ΙEP · (Z0M/3) = UL3-E
[messkorrparall-formel-wlk-040618, 1, en_GB]
where ΙEP is the earth current of the parallel line and the ratios R0M/3RL and X0M/3XL are constant line parame-
ters, resulting from the geometry of the double circuit line and the nature of the ground below the line. These
line parameters are input to the device — along with all the other line data — during the parameterisation.
[erdkurzschluss-auf-einer-doppelleitung-wlk-260702, 1, en_GB]
Figure 2-17 Earth fault on a double circuit line
Without parallel line compensation, the earth current on the parallel line will in most cases cause the reach
threshold of the distance protection to be shortened (underreach of the distance measurement). In some
cases — for example when the two feeders are terminated to different busbars, and the location of the earth
fault is on one of the remote busbars (at B in Figure 2-17) — an overreach may occur.
The parallel line compensation only applies to faults on the protected feeder. For faults on the parallel line, the
compensation may not be carried out, as this would cause severe overreach. The relay located in position II in
Figure 2-17 must therefore not be compensated.
Earth current balance is therefore additionally provided in the device, which carries out a cross comparison of
the earth currents in the two lines. The compensation is only applied to the line end where the earth current
of the parallel line is not substantially larger than the earth current in the line itself. In example in Figure 2-17,
the current ΙE is larger than ΙEP: compensation is applied at Ι by including ZM · ΙEP in the evaluation; at II
compensation is not applied.
Switching onto a fault
If the circuit breaker is manually closed onto a short circuit, the distance protection can issue an instantaneous
trip command. By setting parameters it may be determined which zone(s) is/are released following a manual
close (refer to the following figure). The line energization information (input “SOTF”) is derived from the state
recognition (see Section 2.20.1 Function Control, Detection of the Circuit Breaker Position).
Functions
2.2 Distance Protection
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[logikdia-zuschalten-auf-einen-fehler-240402-wlk, 1, en_GB]
Figure 2-18 Circuit breaker closure onto a fault
i
i
NOTE
When switching onto a three-pole fault with the MHO characteristic, there will be no voltage in the
memory or unfaulted loop voltage available. To ensure fault clearance when switching onto three-phase
close-up faults, please make sure that in conjunction with the configured MHO characteristic the instanta-
neous tripping function is always enabled.
Setting Notes
At address 1201 FCT Distance the distance protection function can be switched ON or OFF.
Minimum Current
The minimum current for fault detection Minimum Minimum Iph> (address 1202) is set somewhat (approx.
10 %) below the minimum short-circuit current that may occur.
Earth fault detection
In systems with earthed starpoint, the setting 3I0> Threshold (address 1203) is set somewhat below the
minimum expected earth fault current. 3Ι0 is defined as the sum of the phase currents |ΙL1 + ΙL2 + ΙL3|, which
equals the starpoint current of the set of current transformers. In non-earthed systems the setting value is
recommended to be below the earth current value for double earth faults.
The preset value 3I0>/ Iphmax = 0.10 (address 1207) is usually recommended for the slope of the 3Ι char-
acteristic. This setting can only be changed in DIGSI at Display Additional Settings.
Addresses 1204 and 1209 are only relevant for earthed power systems. In non-earthed systems, they are
hidden.
When setting 3U0> Threshold (address 1204), care must be taken that operational asymmetries do not
cause a pickup. 3U0 is defined as the sum of the phase-to-earth voltages |UL1-E + UL2-E + UL3-E|. If the U0 crite-
rion is not required, address 1204 is set to ∞.
In earthed power systems the earth fault detection can be complemented by a zero sequence voltage detec-
tion function. You can determine whether an earth fault is detected when a zero sequence current or a zero
sequence voltage threshold is exceeded or when both criteria are met. 3I0> OR 3U0> (default setting)
applies at address 1209 E/F recognition if only one of the two criteria is valid. Select 3I0> AND 3U0> to
activate both criteria for earth-fault detection. This setting can only be changed in DIGSI at Display Additional
2.2.1.3
Functions
2.2 Distance Protection
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Settings. If you want to detect only the earth current, set 3I0> OR 3U0> and also 3U0> Threshold
(address 1204) to ∞.
i
i
NOTE
Under no circumstances set address 1204 3U0> Threshold to∞, if you have set address 1209 E/F
recognition = 3I0> AND 3U0>, or earth-fault detection will no longer be possible.
In compensated or isolated networks, an earth pickup is only initiated after the pickup of the zero-sequence
current criterion. Use the zero-sequence voltage criterion with the parameter 1205 3U0> COMP/ISOL. for
the confirmation of an earth pickup in case of double earth faults with current transformer saturation.
If the current transformer is saturated and the parameter 1205 is not set to ∞, an earth fault detection by
means of the I0 criterion alone is not possible and a verification of the pickup by means of the U0 criterion is
initiated.
Address 1223 Uph-ph unbal. allows you to specify how great the asymmetries can become due to load and
single-pole earth fault conditions.
If the earth fault detection by the I0 criterion threatens to pick up due to fault inception transients following
the occurrence of a single earth fault, the detection can be delayed by means of a parameter T3I0 1PHAS
(address 1206).
Application with series-compensated lines
In applications for, or in the proximity of, series-compensated lines (lines with series capacitors) address 1208
SER-COMP. is set to YES, to ensure that the direction determination operates correctly in all cases. The influ-
ence of the series capacitors on the direction determination is described in Section 2.2.2 Distance protection
with quadrilateral characteristic (optional) under margin heading “Direction Determination in Case of Series-
compensated Lines”.
Start of Delay Times
As was mentioned in the description of the measuring methods, each distance zone generates an output
signal which is associated with the zone and the affected phase. The zone logic combines these zone fault
detections with possible further internal and external signals. The delay times for the distance zones can be
started either all together on general fault detection by the distance protection function, or individually at the
moment the fault enters the respective distance zone. Parameter Start Timers (address 1210) is set by
default to on Dis. Pickup. This setting ensures that all delay times continue to run together even if the
type of fault or the selected measuring loop changes, e.g. because an intermediate infeed is switched off. It is
also the preferred setting if other distance protection relays in the power system are working with this start
timing. Where grading of the delay times is especially important, for instance if the fault location shifts from
zone Z3 to zone Z2, the setting on Zone Pickup should be chosen.
Angle of inclination of the tripping characteristics
The shape of the tripping characteristic is among other factors influenced by the inclination angle Distance
Angle (address 1211). Details about the tripping characteristics can be found in Sub-section 2.2.2 Distance
protection with quadrilateral characteristic (optional) and 2.2.3 Distance protection with MHO characteristic
(optional)). Usually, the line angle is set here, i.e. the same value as in address 1105 Line Angle (Section
2.1.4.1 Setting Notes). Irrespective of the line angle it is, however, possible to select a different inclination
angle of the tripping characteristic.
Parallel line measured value correction (optional)
The mutual coupling between the two lines of a double-circuit configuration is only relevant to the 7SA522
when it is applied on a double-circuit line and when it is intended to implement parallel line compensation. A
prerequisite is that the earth current of the parallel line is connected to the Ι4 measuring input of the device
and this is entered in the configuration settings. In this case, address 1215 Paral.Line Comp has to be set
to YES (default setting).
The coupling factors were already set as part of the general protection data (Section 2.1.4.1 Setting Notes), as
was the reach of the parallel line compensation.
Functions
2.2 Distance Protection
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Double earth faults in effectively earthed systems
The loop selection for double earth faults is set at address 1221 2Ph-E faults (Phase-to-Phase Earth fault
detection). This parameter can only be altered in DIGSI at Display Additional Settings. In most cases, Block
leading Ø (blocking of the leading phase, default setting) is favourable because the leading phase-to-earth
loop tends to overreach, especially in conjunction with large earth fault resistance. In certain cases (fault
resistance phase-to-phase larger than phase-to-earth) the setting Block lagging Ø (blocking of the lagging
phase) may be more favourable. The evaluation of all affected loops with the setting All loops allows a
maximum degree of redundancy. It is also possible to evaluate Ø-Ø loops only. This ensures the highest
accuracy for 2-phase-to-earth faults. Finally it is possible to declare only the phase-to-earth loops as valid
(setting Ø-E loops only).
Double earth faults in non-earthed systems
In isolated or resonant-earthed systems it must be guaranteed that the preference for double earth faults in
whole galvanically-connected systems is consistent. The double earth fault preference is set in address 1220
PHASE PREF.2phe.
7SA522 also enables the user to detect all base points of a multiple earth fault. PHASE PREF.2phe = All
loops means that each earth fault base point is switched off independant of any preference. It can also be
combined with a different preference. For a transformer feeder, for example, any base point can be switched
off following occurrence of a double earth fault, whereas L1 (L3) ACYCLIC is consistently valid for the
remainder of the system.
If the earth fault detection threatens to pick up due to fault inception transients following the occurrence of a
single earth fault, the detection can be delayed via parameter T3I0 1PHAS (address 1206). Usually the
presetting (0.04 s) is sufficient. For large resonant-earthed systems the time delay should be increased. Set
parameter T3I0 1PHAS to ∞ if the earth current threshold can also be exceeded during steady-state condi-
tions. Then, even with high earth current, no single-phase pickup is possible anymore. Double earth faults are,
however, detected correctly and evaluated according to the preference mode.
i
i
NOTE
When testing a single earth fault by means of a test equipment, it must be made sure that the phase-to-
phase voltages fulfill the symmetry criterion.
Switching onto a fault
To determine the reaction of the distance protection during closure of the circuit breaker onto a fault, the
parameter in address 1232 SOTF zone is used. The setting Inactive, that there is no special reaction, i.e.
all distance stages operate according to their set zone parameters. The setting Zone Zone Z1B causes all
faults inside the overreaching zone Z1B (in the direction specified for this zone) to be cleared delay after the
closure of the circuit breaker. If Z1B undirect. is set, the zone Z1B is relevant, but it acts in both directions,
regardless of the operating direction set in address 1351 Op. mode Z1B. The setting in Zone Z1 causes all
faults inside the zone Z1 (in the direction specified for this zone) to be cleared without delay after the closure
of the circuit breaker. This setting is only useful if a delay time has been set for the zone Z1. If Z1 undirect.
is set, the zone Z1 is relevant, but it acts in both directions, regardless of the operating direction set in address
1301 Op. mode Z1. The setting PICKUP implies that the non-delayed tripping following line energization is
activated for all recognized faults in any zone (i.e. with general fault detection of the distance protection).
Load range
On long heavily loaded lines, the risk of encroachment of the load impedance into the tripping characteristics
of the distance protection may exist. To exclude the risk of unwanted fault detection by the distance protec-
tion during heavy load flow, a load trapezoid characteristic may be set for tripping characteristics with large R-
reaches, which excludes such unwanted fault detection by overload. This load area is considered in the
description of the tripping characteristics (see also Section 2.2.2 Distance protection with quadrilateral char-
acteristic (optional) and Section 2.2.3 Distance protection with MHO characteristic (optional)).
The R value R load (Ø-E) (address 1241) refers to the phase-to-earth loops, R load (Ø-Ø) (address
1243) to the phase-to-phase loops. The values are set somewhat (approx. 10 %) below the minimum expected
Functions
2.2 Distance Protection
64 SIPROTEC 4, 7SA522, Manual
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load impedance. The minimum load impedance appears when the maximum load current and minimum oper-
ating voltage exist.
For a 1-pole tripping, the setting of the load trapezoid characteristic for earth loops must consider the load
current in the earth path. This is very critical for double circuit lines (on a tower with significant coupling
between both lines). Due to the zero sequence mutual coupling, a significant amount of load current will flow
in the “zero sequence” path when the parallel line has a single pole open condition. The R setting for the
ground loops (or load encroachment setting) must take into account the ground current that flows when the
parallel line has a single pole open condition.
Calculation Example 1:
110 kV-overhead line 150 mm2, 3-pole tripping, with the following data:
maximum transmittable power
Pmax = 100 MVA corresponds to
Ιmax = 525 A
minimum operating voltage
Umin = 0,9 UN
Current Transformer 600 A/5 A
Voltage Transformer 110 kV/0.1 kV
The resultant minimum load impedance is therefore:
[formel-dis-lastber-1-oz-010802, 1, en_GB]
This value can be entered as a primary value when parameterizing with a PC and DIGSI. The conversion to
secondary values is
[formel-dis-lastber-2-oz-010802, 1, en_GB]
when applying a security margin of 10% the following is set:
R load (Ø-Ø) = 97,98 Ω primär = 10,69 Ω sekundär
R load (Ø-E) = 97,98 Ω primär = 10,69 Ω sekundär
The spread angle of the load trapezoid characteristic φ load (Ø-E) (address 1242) and φ load (Ø-Ø)
(address 1244) must be greater (approx. 5°) than the maximum arising load angle (corresponding to the
minimum power factor cosϕ).
Minimum power factor (example)
cos φmin = 0.63
φmax = 51°
Setting valueφ load (Ø-Ø) = φmax + 5° = 56°.
Calculation Example 2:
For applications with parallel line (zero sequence mutual coupling) and single pole tripping:
400 kV overhead line (220 km) on double tower with the following data:
Maximum power flow per circuit when both lines in service:
Pmax = 1200 MVA corresponds to
Ιmax = 1732 A
minimum operating voltage
Umin = 0,9 UN
Current Transformer 2000 A/5 A
Functions
2.2 Distance Protection
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Voltage Transformer 400 kV/0,1 kV
Setting parameter
RE/RL
1.54
The resulting minimum load impedance is therefore:
[min-lastimpedanz-091028, 1, en_GB]
This value applies for phase-to-phase measurement. The setting for ground loops must also consider the
condition when the parallel line has a single pole open condition. In this state, the load current on the “healthy
line” will increase in the phase with single pole open condition as well as in the ground path. To determine the
minimum load resistance in the ground loops during this state, the magnitude of the load current in the
ground path must be set. For the calculation, it is given as a ratio relative to the load current Ιmax calculated
above.
Ratio between ΙE on healthy line and Ιmax when parallel line has a single pole open condition:
[1pol-pause-091028, 1, en_GB]
This ratio depends on the line length as well as on the source and line impedances. If it is not possible to
determine this value from power system simulations, a value between 0.4 for long double lines (200 km) and
0.6 for short lines (25 km) may be assumed.
The resultant minimum load impedance for phase-to-earth loops is therefore:
[min-lastimp-l-e-091028, 1, en_GB]
This value may be entered as a primary value when parameterizing with a PC and DIGSI. Conversion to secon-
dary quantities is:
[umrechn-sek01-091028, 1, en_GB]
[umrechn-sek02-091028, 1, en_GB]
when applying a security margin of 10% the following is set:
R load (Ø-Ø) = 108 Ω primary = 10,8 Ω secondary
R load (Ø-E) = 53,5 Ω primary = 5,35 Ω secondary
The spread angle of the load trapezoid characteristicis calculated based on the minimum power factor in the
same manner as for single line (Calculation Example 1).
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
2.2.1.4
Functions
2.2 Distance Protection
66 SIPROTEC 4, 7SA522, Manual
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The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
1201 FCT Distance ON
OFF
ON Distance protection
1202 Minimum Iph> 1A 0.05 .. 4.00 A 0.10 A Phase Current threshold for
dist. meas.
5A 0.25 .. 20.00 A 0.50 A
1203 3I0> Threshold 1A 0.05 .. 4.00 A 0.10 A 3I0 threshold for neutral
current pickup
5A 0.25 .. 20.00 A 0.50 A
1204 3U0> Threshold 1 .. 100 V; ∞ 5 V 3U0 threshold zero seq.
voltage pickup
1205 3U0> COMP/ISOL. 10 .. 200 V; ∞ ∞ V 3U0> pickup (comp/ isol.
star-point)
1206 T3I0 1PHAS 0.00 .. 0.50 sec; ∞ 0.04 sec Delay 1ph-faults (comp/
isol. star-point)
1207A 3I0>/ Iphmax 0.05 .. 0.30 0.10 3I0>-pickup-stabilisation
(3I0> /Iphmax)
1208 SER-COMP. NO
YES
NO Series compensated line
1209A E/F recognition 3I0> OR 3U0>
3I0> AND 3U0>
3I0> OR 3U0> criterion of earth fault
recognition
1210 Start Timers on Dis. Pickup
on Zone Pickup
on Dis. Pickup Condition for zone timer
start
1211 Distance Angle 30 .. 90 ° 85 ° Angle of inclination,
distance charact.
1215 Paral.Line Comp NO
YES
YES Mutual coupling parall.line
compensation
1220 PHASE PREF.2phe L3 (L1) ACYCLIC
L1 (L3) ACYCLIC
L2 (L1) ACYCLIC
L1 (L2) ACYCLIC
L3 (L2) ACYCLIC
L2 (L3) ACYCLIC
L3 (L1) CYCLIC
L1 (L3) CYCLIC
All loops
L3 (L1) ACYCLIC Phase preference for 2ph-e
faults
1221A 2Ph-E faults Block leading Ø
Block lagging Ø
All loops
Ø-Ø loops only
Ø-E loops only
Block leading Ø Loop selection with 2Ph-E
faults
1223 Uph-ph unbal. 5 .. 50 % 25 % Max Uph-ph unbal. for 1ph
Flt. detection
1232 SOTF zone PICKUP
Zone Z1B
Z1B undirect.
Zone Z1
Z1 undirect.
Inactive
Inactive Instantaneous trip after
SwitchOnToFault
Functions
2.2 Distance Protection
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Addr. Parameter C Setting Options Default Setting Comments
1241 R load (Ø-E) 1A 0.100 .. 600.000 Ω; ∞ ∞ Ω R load, minimum Load
Impedance (ph-e)
5A 0.020 .. 120.000 Ω; ∞ ∞ Ω
1242 φ load (Ø-E) 20 .. 60 ° 45 ° PHI load, maximum Load
Angle (ph-e)
1243 R load (Ø-Ø) 1A 0.100 .. 600.000 Ω; ∞ ∞ Ω R load, minimum Load
Impedance (ph-ph)
5A 0.020 .. 120.000 Ω; ∞ ∞ Ω
1244 φ load (Ø-Ø) 20 .. 60 ° 45 ° PHI load, maximum Load
Angle (ph-ph)
1305 T1-1phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1-1phase, delay for single
phase faults
1306 T1-multi-phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1multi-ph, delay for multi
phase faults
1315 T2-1phase 0.00 .. 30.00 sec; ∞ 0.30 sec T2-1phase, delay for single
phase faults
1316 T2-multi-phase 0.00 .. 30.00 sec; ∞ 0.30 sec T2multi-ph, delay for multi
phase faults
1317A Trip 1pole Z2 NO
YES
NO Single pole trip for faults in
Z2
1325 T3 DELAY 0.00 .. 30.00 sec; ∞ 0.60 sec T3 delay
1335 T4 DELAY 0.00 .. 30.00 sec; ∞ 0.90 sec T4 delay
1345 T5 DELAY 0.00 .. 30.00 sec; ∞ 0.90 sec T5 delay
1355 T1B-1phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1B-1phase, delay for
single ph. faults
1356 T1B-multi-phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1B-multi-ph, delay for
multi ph. faults
1357 1st AR -> Z1B NO
YES
YES Z1B enabled before 1st AR
(int. or ext.)
1365 T6 DELAY 0.00 .. 30.00 sec; ∞ 1.50 sec T6 delay
Information List
No. Information Type of
Informa-
tion
Comments
3603 >BLOCK Distance SP >BLOCK Distance protection
3611 >ENABLE Z1B SP >ENABLE Z1B (with setted Time Delay)
3613 >ENABLE Z1Binst SP >ENABLE Z1B instantanous (w/o T-Delay)
3617 >BLOCK Z4-Trip SP >BLOCK Z4-Trip
3618 >BLOCK Z5-Trip SP >BLOCK Z5-Trip
3619 >BLOCK Z4 Ph-E SP >BLOCK Z4 for ph-e loops
3620 >BLOCK Z5 Ph-E SP >BLOCK Z5 for ph-e loops
3621 >BLOCK Z6-Trip SP >BLOCK Z6-Trip
3622 >BLOCK Z6 Ph-E SP >BLOCK Z6 for ph-e loops
3651 Dist. OFF OUT Distance is switched off
3652 Dist. BLOCK OUT Distance is BLOCKED
3653 Dist. ACTIVE OUT Distance is ACTIVE
3654 Dis.ErrorK0(Z1) OUT Setting error K0(Z1) or Angle K0(Z1)
3655 DisErrorK0(>Z1) OUT Setting error K0(>Z1) or Angle K0(>Z1)
3671 Dis. PICKUP OUT Distance PICKED UP
3672 Dis.Pickup L1 OUT Distance PICKUP L1
2.2.1.5
Functions
2.2 Distance Protection
68 SIPROTEC 4, 7SA522, Manual
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No. Information Type of
Informa-
tion
Comments
3673 Dis.Pickup L2 OUT Distance PICKUP L2
3674 Dis.Pickup L3 OUT Distance PICKUP L3
3675 Dis.Pickup E OUT Distance PICKUP Earth
3681 Dis.Pickup 1pL1 OUT Distance Pickup Phase L1 (only)
3682 Dis.Pickup L1E OUT Distance Pickup L1E
3683 Dis.Pickup 1pL2 OUT Distance Pickup Phase L2 (only)
3684 Dis.Pickup L2E OUT Distance Pickup L2E
3685 Dis.Pickup L12 OUT Distance Pickup L12
3686 Dis.Pickup L12E OUT Distance Pickup L12E
3687 Dis.Pickup 1pL3 OUT Distance Pickup Phase L3 (only)
3688 Dis.Pickup L3E OUT Distance Pickup L3E
3689 Dis.Pickup L31 OUT Distance Pickup L31
3690 Dis.Pickup L31E OUT Distance Pickup L31E
3691 Dis.Pickup L23 OUT Distance Pickup L23
3692 Dis.Pickup L23E OUT Distance Pickup L23E
3693 Dis.Pickup L123 OUT Distance Pickup L123
3694 Dis.Pickup123E OUT Distance Pickup123E
3701 Dis.Loop L1-E f OUT Distance Loop L1E selected forward
3702 Dis.Loop L2-E f OUT Distance Loop L2E selected forward
3703 Dis.Loop L3-E f OUT Distance Loop L3E selected forward
3704 Dis.Loop L1-2 f OUT Distance Loop L12 selected forward
3705 Dis.Loop L2-3 f OUT Distance Loop L23 selected forward
3706 Dis.Loop L3-1 f OUT Distance Loop L31 selected forward
3707 Dis.Loop L1-E r OUT Distance Loop L1E selected reverse
3708 Dis.Loop L2-E r OUT Distance Loop L2E selected reverse
3709 Dis.Loop L3-E r OUT Distance Loop L3E selected reverse
3710 Dis.Loop L1-2 r OUT Distance Loop L12 selected reverse
3711 Dis.Loop L2-3 r OUT Distance Loop L23 selected reverse
3712 Dis.Loop L3-1 r OUT Distance Loop L31 selected reverse
3713 Dis.Loop L1E<-> OUT Distance Loop L1E selected non-direct.
3714 Dis.Loop L2E<-> OUT Distance Loop L2E selected non-direct.
3715 Dis.Loop L3E<-> OUT Distance Loop L3E selected non-direct.
3716 Dis.Loop L12<-> OUT Distance Loop L12 selected non-direct.
3717 Dis.Loop L23<-> OUT Distance Loop L23 selected non-direct.
3718 Dis.Loop L31<-> OUT Distance Loop L31 selected non-direct.
3719 Dis. forward OUT Distance Pickup FORWARD
3720 Dis. reverse OUT Distance Pickup REVERSE
3741 Dis. Z1 L1E OUT Distance Pickup Z1, Loop L1E
3742 Dis. Z1 L2E OUT Distance Pickup Z1, Loop L2E
3743 Dis. Z1 L3E OUT Distance Pickup Z1, Loop L3E
3744 Dis. Z1 L12 OUT Distance Pickup Z1, Loop L12
3745 Dis. Z1 L23 OUT Distance Pickup Z1, Loop L23
3746 Dis. Z1 L31 OUT Distance Pickup Z1, Loop L31
3747 Dis. Z1B L1E OUT Distance Pickup Z1B, Loop L1E
3748 Dis. Z1B L2E OUT Distance Pickup Z1B, Loop L2E
Functions
2.2 Distance Protection
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No. Information Type of
Informa-
tion
Comments
3749 Dis. Z1B L3E OUT Distance Pickup Z1B, Loop L3E
3750 Dis. Z1B L12 OUT Distance Pickup Z1B, Loop L12
3751 Dis. Z1B L23 OUT Distance Pickup Z1B, Loop L23
3752 Dis. Z1B L31 OUT Distance Pickup Z1B, Loop L31
3755 Dis. Pickup Z2 OUT Distance Pickup Z2
3758 Dis. Pickup Z3 OUT Distance Pickup Z3
3759 Dis. Pickup Z4 OUT Distance Pickup Z4
3760 Dis. Pickup Z5 OUT Distance Pickup Z5
3762 Dis. Pickup Z6 OUT Distance Pickup Z6
3770 Dis.Time Out T6 OUT DistanceTime Out T6
3771 Dis.Time Out T1 OUT DistanceTime Out T1
3774 Dis.Time Out T2 OUT DistanceTime Out T2
3777 Dis.Time Out T3 OUT DistanceTime Out T3
3778 Dis.Time Out T4 OUT DistanceTime Out T4
3779 Dis.Time Out T5 OUT DistanceTime Out T5
3780 Dis.TimeOut T1B OUT DistanceTime Out T1B
3801 Dis.Gen. Trip OUT Distance protection: General trip
3802 Dis.Trip 1pL1 OUT Distance TRIP command - Only Phase L1
3803 Dis.Trip 1pL2 OUT Distance TRIP command - Only Phase L2
3804 Dis.Trip 1pL3 OUT Distance TRIP command - Only Phase L3
3805 Dis.Trip 3p OUT Distance TRIP command Phases L123
3811 Dis.TripZ1/1p OUT Distance TRIP single-phase Z1
3813 Dis.TripZ1B1p OUT Distance TRIP single-phase Z1B
3816 Dis.TripZ2/1p OUT Distance TRIP single-phase Z2
3817 Dis.TripZ2/3p OUT Distance TRIP 3phase in Z2
3818 Dis.TripZ3/T3 OUT Distance TRIP 3phase in Z3
3821 Dis.TRIP 3p. Z4 OUT Distance TRIP 3phase in Z4
3822 Dis.TRIP 3p. Z5 OUT Distance TRIP 3phase in Z5
3823 DisTRIP3p. Z1sf OUT DisTRIP 3phase in Z1 with single-ph Flt.
3824 DisTRIP3p. Z1mf OUT DisTRIP 3phase in Z1 with multi-ph Flt.
3825 DisTRIP3p.Z1Bsf OUT DisTRIP 3phase in Z1B with single-ph Flt
3826 DisTRIP3p Z1Bmf OUT DisTRIP 3phase in Z1B with multi-ph Flt.
3827 Dis.TRIP 3p. Z6 OUT Distance TRIP 3phase in Z6
3850 DisTRIP Z1B Tel OUT DisTRIP Z1B with Teleprotection scheme
Distance protection with quadrilateral characteristic (optional)
The 7SA522 distance protection has a polygonal tripping characteristic. Depending on which version was
ordered, an MHO circle tripping characteristic can be set. If both characteristics are available, they may be
selected separately for phase-phase loops and phase-earth loops. If only the MHO circle tripping characteristic
is used, please go to Section 2.2.3 Distance protection with MHO characteristic (optional).
2.2.2
Functions
2.2 Distance Protection
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Functional Description
Operating polygons
In total, there are six independent zones and one additional controlled zone for each fault impedance loop.
Figure 2-19 shows the shape of the polygons as example. Zone Z6 is not shown in Figure 2-19. The first zone
is shaded and forward directional. The third zone is reverse directional.
In general, the polygon is defined by means of a parallelogram which intersects the axes with the values R and
X as well as the tilt ϕDist. A load trapezoid with the setting RLoad and ϕLoad may be used to cut the area of the
load impedance out of the polygon. The axial coordinates can be set individually for each zone; ϕDist, RLoad and
ϕLoad are common for all zones. The parallelogram is symmetrical with respect to the origin of the R-X-coordi-
nate system; the directional characteristic however limits the tripping range to the desired quadrants (refer to
“Direction determination” below).
The R-reach may be set separately for the phase-to-phase faults and the phase-to-earth faults to achieve a
larger fault resistance coverage for earth faults if this is desired.
[polygonale-charakteristik-wlk-290702, 1, en_GB]
Figure 2-19 Polygonal characteristic (setting values are marked by dots)
For the first zone Z1, an additional settable tilt α exists, which may be used to prevent overreach resulting
from angle variance and/or two ended infeed to short-circuits with fault resistance. For Z1B and the higher
zones, this tilt does not exist.
Determination of direction
For each loop an impedance vector is also used to determine the direction of the short-circuit. Usually similar
to the distance calculation, ZL is used. However, depending on the “quality” of the measured values, different
computation techniques are used. Immediately after fault inception, the short-circuit voltage is disturbed by
transients. The voltage memorised prior to fault inception is therefore used in this situation. If even the
2.2.2.1
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steadystate short-circuit voltage (during a close-up fault) is too small for direction determination, an unfaulted
voltage is used. This voltage is in theory perpendicular to the actual short-circuit voltage for both phase-to-
earth loops as well as for phase-to-phase loops (Figure 2-20). This is taken into account when computing the
direction vector by means of a 90° rotation. Table 2-4 shows the allocation of the measured values to the six
fault loops for the determination of the fault direction.
[richtungsbstimng-kurzschlussfr-spg-290702-wlk, 1, en_GB]
Figure 2-20 Direction determination with unfaulted voltages (cross polarizing)
Table 2-4 Voltage and current values for the determination of fault direction
Loop Measuring
Current (Direc-
tion)
Actual short-circuit voltage Unfaulted voltage
L1-E ΙL1 UL1-E UL2 - UL3
L2-E ΙL2 UL2-E UL3 - UL1
L3-E ΙL3 UL3-E UL1 - UL2
L1-E1) ΙL1 - ΙE1) UL1-E UL2 - UL3
L2-E1) ΙL2 - ΙE1) UL2-E UL3 - UL1
L3-E1) ΙL3 - ΙE1) UL3-E UL1 - UL2
L1-L2 ΙL1 - ΙL2 UL1 - UL2 UL2-L3 - UL3-L1
L2-L3 ΙL2 - ΙL3 UL2 - UL3 UL3-L1 - UL1-L2
L3-L1 ΙL3 - ΙL1 UL3 - UL1 UL1-L2 - UL2-L3
1) with consideration of earth impedance compensation
If there is neither a current measured voltage nor a memorized voltage available which is sufficient for meas-
uring the direction, the relay selects the Forward direction. In practice this can only occur when the circuit
breaker closes onto a de-energized line, and there is a fault on this line (e.g. closing onto an earthed line).
Figure 2-21 shows the theoretical steady-state characteristic. In practice, the limits of the directional charac-
teristic when using memorized voltages is dependent on both the source impedance and the load transferred
across the line prior to fault inception. Accordingly the directional characteristic includes a safety margin with
respect to the borders of the first quadrant in the R–X diagram (Figure 2-21).
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[richtungskennlinie-r-x-diagramm-wlk-290702, 2, en_GB]
Figure 2-21 Directional characteristic in the R-X-diagram
Since each zone can be set to Forward, Reverse or Non-Directional, different (centrically mirrored)
directional characteristics are available for Forward and Reverse. A non-directional zone has no directional
characteristic. The entire tripping region applies here.
Characteristics of the Direction Determination
The theoretical steady-state directional characteristic shown in Figure 2-21 applies to faulted loop voltages. In
the case of quadrature voltages or memorized voltage, the position of the directional characteristic is
dependent on both the source impedance as well as the load transferred across the line prior to fault incep-
tion.
Figure 2-22 shows the directional characteristic using quadrature or memorized voltage as well as taking the
source impedance into account (no load transfer). As these voltages are equal to the corresponding generator
voltage E and they do not change after fault inception, the directional characteristic is shifted in the impe-
dance diagram by the source impedance ZS1 = E1/Ι1. For the fault location F1 (Figure 2-22a) the short-circuit
location is in the forward direction and the source impedance is in the reverse direction. For all fault locations,
right up to the device location (current transformers), a definite Forward decision is made (Figure 2-22b). If
the current direction is reversed, the position of the directional characteristic changes abruptly (Figure 2-22c).
A reversed current Ι2 now flows via the measuring location (current transformer) which is determined by the
source impedance ZS2 + ZL. When load is transferred across the line, the directional characteristic may addi-
tionally be rotated by the load angle.
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[richtungskennlinie-kurzschlussfr-gesp-spgn-wlk-290702, 1, en_GB]
Figure 2-22 Directional characteristic with quadrature or memorized voltages
Determination of direction in case of series-compensated lines
The directional characteristics and their displacement by the source impedance apply also for lines with series
capacitors. If a short-circuit occurs behind the local series capacitors, the short-circuit voltage however
reverses its direction until the protective spark gap has picked up (see Figure 2-23).
[richtgbest-serie-komp-ltgn-wlk-030903, 1, en_GB]
Figure 2-23 Voltage characteristic while a fault occurs after a series capacitor
a) without pickup of the protective spark gap
b) with pickup of the protective spark gap
The distance protection function would thus detect a wrong fault direction. The use of memorized voltages
however ensures that the direction is correctly detected Figure 2-24a).
Since the voltage prior to the fault is used to determine the direction, the peak displacement of the directional
characteristics in dependence of the source impedance and infeed conditions before the fault are displaced so
far that the capacitor reactance — which is always smaller than the series reactance — does not cause the
apparent direction reversal(Figure 2-24b).
If the short-circuit is located before the capacitor, from the relay location (current transformer) in reverse
direction, the peak displacement of the directional characteristics are shifted to the other direction
(Figure 2-24c). A correct determination of the direction is thus also ensured in this case.
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[richtgskennl-serie-komp-ltgn-wlk-030902, 1, en_GB]
Figure 2-24 Directional characteristics for series-compensated lines
Pickup and assignment to the polygons
The loop impedances calculated according to Sub-section 2.2.1 Distance protection, general settings are
assigned to the characteristics set for the distance zones. To avoid unstable signals at the boundaries of a
polygon, the characteristics have a hysteresis of approximately 5 %, i.e. as soon as it has been determined that
the fault impedance lies within a polygon, the boundaries are increased by 5 % in all directions.
As soon as the fault impedance of any loop is definitely within the operating polygon of a distance zone, the
affected loop is designated as “picked up”.
For each zone “pickup” signals are generated and converted to phase information, e.g. “Dis Z1 L1” (internal
message) for zone Z1 and phase L1; this means that each phase and each zone is provided with separate
pickup information; the information is then processed in the zone logic and by additional functions (e.g. tele-
protection logic, Section 2.6 Teleprotection for distance protection). The loop information is also converted to
phase-segregated information. Another condition for “pickup” of a zone is that the direction matches the
direction configured for this zone (refer also to Section 2.3 Power swing detection (optional)). Furthermore
the distance protection may not be blocked or switched off completely. Figure 2-25 shows these conditions.
[freigabelogik-fuer-eine-zone-beispiel-fuer-z1-wlk-240402, 1, en_GB]
Figure 2-25 Release logic for one zone (example for Z1)
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In total, the following zones are available:
Independent zones:
•1st zone (fast tripping zone) Z1 with X(Z1); R(Z1) Ø-Ø, RE(Z1) Ø-E, may be delayed by T1-1phase
or T1-multi-phase,
•2nd zone (backup zone) Z2 withX(Z2); R(Z2) Ø-Ø, RE(Z2) Ø-E, may be delayed by T2-1phase or.
T2-multi-phase,
•3rd zone (backup zone) Z3 with X(Z3); R(Z3) Ø-Ø, RE(Z3) Ø-E, may be delayed by T3 DELAY,
•4th zone (backup zone) Z4 with X(Z4); R(Z4) Ø-Ø, RE(Z4) Ø-E, may be delayed by T4 DELAY,
•5th zone (backup zone) Z5 with X(Z5)+ (forward) and X(Z5)- (reverse); R(Z5) Ø-Ø, RE(Z5) Ø-E,
may be delayed by T5 DELAY.
•6th zone (backup zone) Z6 with X(Z6)+ (forward) and X(Z6)- (reverse), R(Z6) Ø-Ø, RE(Z6) Ø-E,
may be delayed by T6 DELAY.
Dependent (controlled) zone:
•Overreaching zone Z1B with X(Z1B); R(Z1B) Ø-Ø, RE(Z1B) Ø-E, may be delayed by T1B-1phase or
T1B-multi-phase.
Setting Notes
Grading coordination chart
It is recommended to initially create a grading coordination chart for the entire galvanically interconnected
system. This diagram should reflect the line lengths with their primary reactances X in Ω/km. For the reach of
the distance zones, the reactances X are the deciding quantity.
The first zone Z1 is usually set to cover 85 % of the protected line without any trip time delay (i.e. T1 = 0.00 s).
The protection clears faults in this range without additional time delay, i.e. the tripping time is the relay basic
operating time.
The tripping time of the higher zones is sequentially increased by one time grading interval. The grading
margin must take into account the circuit breaker operating time including the spread of this time, the reset-
ting time of the protection equipment as well as the spread of the protection delay timers. Typical values are
0.2 s to 0.4 s. The reach is selected to cover up to approximately 80 % of the zone with the same set time
delay on the shortest neighbouring feeder (see Figure 2-29). Figure 2-26).
[reichweit-staffelpl-wlk-040818, 1, en_GB]
Figure 2-26 Setting the reach - example for device A
s1, s2 Protected line section
When using a personal computer and the DIGSI software to apply the settings, the values can be optionally
entered as primary or secondary values.
In the case of parameterization with secondary quantities, the values derived from the grading coordination
chart must be converted to the secondary side of the current and voltage transformers. In general:
[formel-dis-poly-staffelpl-1-oz-010802, 1, en_GB]
2.2.2.2
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Accordingly, the reach for any distance zone can be specified as follows:
[formel-dis-poly-staffelpl-2-oz-010802, 1, en_GB]
with
NCT = Current transformer ratio
NVT = Transformation ratio of voltage transformer
Calculation Example:
110 kV overhead line 150 mm2 with the following data:
s (Länge) = 35 km
R1/s = 0.19 Ω/km
X1/s = 0.42 Ω/km
R0/s = 0.53 Ω/km
X0/s = 1.19 Ω/km
Current Transformer 600 A/5 A
Voltage transformer 110 kV/0.1 kV
The following line data is calculated:
RL = 0.19 Ω/km · 35 km = 6.65 Ω
XL = 0.42 Ω/km · 35 km = 14.70 Ω
For the first zone, a setting of 85 % of the line length should be applied, which results in primary:
X1prim = 0.85 · XL = 0.85 · 14.70 Ω = 12.49 Ω
or secondary:
[formel-dis-poly-staffelpl-3-oz-010802, 1, en_GB]
Resistance tolerance
The resistance setting R allows a reserve for fault resistance which appears as an additional resistance at the
fault location and is added to the impedance of the line conductors. It comprises, for example, the resistance
in arcs, the earth distribution resistance of earth points and others. The setting must consider these fault resis-
tances, but should at the same time not be larger than necessary. On long heavily loaded lines, the setting
may extend into the load impedance range. Fault detection due to overload conditions is then prevented with
the load trapezoid. Refer to margin heading “Load range (only for impedance pickup)” in Subsection
2.2.1 Distance protection, general settings. The resistance tolerance may be separately set for the phase-to-
phase faults on the one hand and the phase-to earth faults on the other hand. It is therefore possible to allow
for a larger fault resistance for earth faults for example.
Most important for this setting on overhead lines, is the resistance of the fault arc. In cables on the other
hand, an appreciable arc can not exist. On very short cables, care must however be taken that an arc fault on
the local cable termination is inside the set resistance of the first zone.
The standard value for the arc voltage UArc is approx. 2.5 kV per meter of arc length.
Example:
A maximum arc voltage of 8 kV is assumed for phase-to-phase faults (line data as above). If the minimum
primary short-circuit current is assumed to be 1000 A this corresponds to 8 Ω primary. The resistance setting
for the first zone, including a safety margin of 20%, would be
primary:
R1prim = 0,5 · RLB · 1,2 = 0,5 · 8 Ω · 1,2 = 4,8 Ω
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or secondary:
[formel-dis-poly-resist-res-2-oz-010802, 1, en_GB]
Only half the arc resistance was applied in the equation, as it is added to the loop impedance and therefore
only half the arc resistance appears in the per phase impedance. Since an arc resistance is assumed to be
present in this case, infeed from the opposite end need not be considered.
The resistance RL of the line itself can be ignored with SIPROTEC 4 devices. It is taken into account by the
shape of the polygon, provided that the inclination angle of the polygon Distance Angle (address 1211) is
not set greater than the line angle Line Angle (address 1105).
A separate resistance tolerance can be set for earth faults. Figure 2-27 illustrates the relationships.
[resistanzmessung-bei-lichtbogenfehlern-oz-250604, 1, en_GB]
Figure 2-27 Resistance measurement of the distance protection in the presence of arc faults
The maximum arc resistance RArc must be determined for setting the distance zone in R direction. The
maximum arc fault resistance is attained when the smallest fault current at which an arc is still present flows
during an earth fault.
[formel-lichtbogr-wlk-040624, 1, en_GB]
The earth fault resistance measured by the distance protection then results from the formula below (it is
assumed that Ι1 and ΙE are in phase opposition):
[formel-resistanzef-wlk-040624, 1, en_GB]
with
RRE Resistance measured by the SIPROTEC distance protection
RL1 Line resistance up to the fault location
RArc Arc resistance
RE/RLSetting in the distance protection (address 1116 and 1118)
Ι2/Ι1Ratio between earth fault currents at the opposite end and the local end. For a correct R setting
of the distance zone, the most unfavourable case must be considered. This most unfavourable
case would be a maximum earth fault current at the opposite end and a minimum earth fault
current at the local end. Moreover, the currents considered are the r.m.s. values without phase
displacement. Where no information is available on the current ratio, a value of approx. “3” can
be assumed. On radial feeders with negligible infeed from the opposite end, this ratio is “0”.
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RTF Effective tower footing resistance of the overhead line system. Where no information is available
on the amount of tower footing resistance, a value of 3 Ω can be assumed for overhead lines
with earth wire (see also /5/ Digital Distance Protection: Basics and Applications; Edition: 2.
completely revised and extended version (May 14, 2008); Language: German).
The following recommended setting applies for the resistance tolerance of distance zone Z1:
[formel-einstempf-resistanz-wlk-040624, 1, en_GB]
with
R1E Setting in the distance protection RE(Z1) Ø-E, address 1304
1.2 Safety margin 20%
The resistance RL of the line itself can be ignored with SIPROTEC 4 devices. It is taken into account by the
shape of the polygon, provided that the inclination angle of the polygon Distance Angle (address 1211) is
not set greater than the line angle Line Angle (address 1105).
Example:
Arc length: 2 m
Minimum fault current: 1.0 kA
Effective tower footing resistance of the overhead line system: 3 Ω
with
Ι2/Ι1= 3
RE/RL= 0.6
Voltage transformer 110 kV/0.1 kV
Current transformer 600 A/5 A
The arc resistance would be:
[formel-beisp-rlb-wlk-040624, 1, en_GB]
and the tower footing resistances RTF = 3 Ω
As a result, the resistance must be set to
primary:
[formel-resistanzeinst-prim-beisp-wlk-040624, 1, en_GB]
or secondary:
[formel-resistanzeinst-sek-beisp-wlk-040624, 1, en_GB]
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In practice, the ratio between resistance and reactance setting is situated in the ranges shown below (see
also /5/ Digital Distance Protection: Basics and Applications; Edition: 2. completely revised and extended
version (May 14, 2008); Language: German):
Type of Line R/X Ratio of the Zone
Setting
Short underground cable lines (approx. 0.5 km to 3 km / 0.3 to 1.88 miles) 3 to 5
Longer underground cable lines (> 3 km / 1.88 miles) 2 to 3
Short overhead lines < 10 km (6.25 miles) 2 to 5
Overhead lines < 100 km (62.5 miles) 1 to 2
Long overhead lines between 100 km and 200 km (62.5 miles and 125 miles) 0,5 to 1
Long EHV lines > 200 km (125 miles) ≤ 0.5
i
i
NOTE
The following must be kept in mind for short lines with a high R/X ratio for the zone setting: The angle
errors of the current and voltage transformers cause a rotation of the measured impedance in the direction
of the R axis. If due to the polygon, RE/RL and XE/XL settings the loop reach in R direction is large in relation
to the X direction, there is an increased risk of external faults being shifted into zone Z1. A grading factor of
85 % should only be used up to R/X ≤ 1 (loop reach). For larger R/X settings, a reduced grading factor for
zone 1 can be calculated with the following formula (see also /5/ Digital Distance Protection: Basics and
Applications; Edition: 2. completely revised and extended version (May 14, 2008); Language: German).
The reduced grading factor is calculated from:
GF = Grading factor = reach of zone Z1 in relation to the line length
R = Loop reach in R direction for zone Z1 = R1 · (1+RE/RL)
X = Loop reach in X direction for zone Z1 = X1 · (1+XE/XL)
δU= Voltage transformer angle error (typical: 1°)
δI= Current transformer angle error (typical: 1°)
[formel-staffelfktr-wlk-040624, 1, en_GB]
In addition or as an alternative, it is also possible to use the setting 1307 Zone Reduction, to modify the
inclination of the zone Z1 polygon and thus prevent overreach (see Figure 2-19).
i
i
NOTE
On long lines with small R/X ratio, care must be taken to ensure that the R reach of the zone settings is at
least about half of the associated X setting. This is especially important for zone Z1 and overreach zone Z1B
in order to achieve the shortest possible tripping times.
Independent Zones Z1 to Z6
By means of the parameter MODE = Forward or Reverse or Non-Directional, each zone can be set
(address 1301 Op. mode Z1, 1311 Op. mode Z2, 1321 Op. mode Z3, 1331 Op. mode Z4, 1341 Op.
mode Z5 and 1361 Op. mode Z6). This allows any combination of graded zones - forward, reverse or non-
directional -, for example on transformers, generators, or bus couplers. For the fifth and sixth zone, you can
additionally set different reaches for forward and reverse. Zones that are not required are set to Inactive.
The values derived from the grading coordination chart are set for each of the required zones. The setting
parameters are grouped for each zone. For the first zone these are the parameters R(Z1) Ø-Ø (address 1302)
for the R intersection of the polygon applicable to phase-to-phase faults, X(Z1) (address 1303) for the X inter-
section (reach), RE(Z1) Ø-E (address 1304) for the R intersection applicable to phase-to-earth faults and
delay time settings.
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If a fault resistance at the fault location (arc, tower footing etc.) causes a voltage drop in the measured impe-
dance loop, the phase angle difference between this voltage and the measured loop current may shift the
determined fault location in X direction. Parameter 1307 Zone Reduction allows an inclination of the upper
limit of zone Z1 in the 1st quadrant (see Figure 2-19). This prevents spurious pickup of zone Z1 in the pres-
ence of faults outside the protected area. Since a detailed calculation in this context can only apply for one
specific system and fault condition, and a virtually unlimited number of complex calculations would be
required to determine the setting, we suggest a simplified but well-proven method here:
[spannungsabfall-am-fehlerort-oz-250604, 1, en_GB]
Figure 2-28 Equivalent circuit diagram for the recommended angle setting Zone Reduction.
The voltage drop at the fault location is:
UF = (ΙA + ΙB) · RF
If ΙA and ΙB have equal phase, then UF and ΙA have equal phase too. In this case the fault resistance RF does not
influence the measured X in the loop, and the Zone Reduction can be set to 0°.
In practice, ΙA and ΙB do not have equal phase; the difference results mostly from the phase difference between
UA and UB. This angle (also called load angle) is therefore used to determine the Zone Reduction angle.
[lastwinkelkennlinie-alpha-wlk-040625, 1, en_GB]
Figure 2-29 Recommended setting for 1307 Zone Reduction (this graphic applies for overhead lines
with a line angle of more than 60°. A smaller setting may be chosen for cables or protected
objects with a smaller angle)
The first step to determine the setting for 1307 Zone Reduction is to determine the maximum load angle
for normal operation (by computer simulation). If this information is not available, a value of about 20° can be
assumed for Western Europe. For other regions with less closely meshed systems, larger angles may have to
be chosen. The next step is to select from Figure 2-29 the curve that matches the load angle. With the set ratio
R1/X1 (zone Z1 polygon) the appropriate setting for 1307 Zone Reduction is then determined.
Example:
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With a load angle of 20° and a setting R/X = 2.5 (R1 = 25 Ω, X1 = 10 Ω), a setting of 10° is adequate for 1307
Zone Reduction.
Different delay times can be set for single- and multiple-phase faults in the first zone: T1-1phase (Address
1305) and T1-multi-phase (address 1306). The first zone is normally set to operate without additional
time delay.
For the remaining zones the following correspondingly applies:
X(Z2) (address 1313), R(Z2) Ø-Ø (address 1312), RE(Z2) Ø-E (address 1314);
X(Z3) (address 1323), R(Z3) Ø-Ø (address 1322), RE(Z3) Ø-E (address 1324);
X(Z4) (address 1333), R(Z4) Ø-Ø (address 1332), RE(Z4) Ø-E (address 1334);
X(Z5)+ (address1343) for forward direction, X(Z5)- (address 1346) for reverse direction, R(Z5) Ø-Ø
(address 1342), RE(Z5) Ø-E (address 1344);
X(Z6)+ (address 1363) for forward direction, X(Z6)- (address 1366) for reverse direction, R(Z6) Ø-Ø
(address 1362), RE(Z6) Ø-E (address 1364).
For the second zone, it is also possible to set separate delay times for single-phase and multi-phase faults. In
general, the delay times are set the same. If stability problems are expected during multi-phase faults, a
shorter delay time could be considered for T2-multi-phase (address 1316) while tolerating a longer delay
time for single-phase faults with T2-1phase (address 1315).
The zone timers for the remaining zones are set with the parameters T3 DELAY (address 1325), T4 DELAY
(address 1335), T5 DELAY (address 1345) and T6 DELAY (address 1365).
If the device is provided with the capability to trip single-pole, single-pole tripping is then possible in the zones
Z1 and Z2. While single-pole tripping usually applies to single-phase faults in Z1 (if the remaining conditions
for single-pole tripping are satisfied), this may also be selected for the second zone with address 1317 Trip
1pole Z2. Single pole tripping in zone 2 is only possible if this address is set to YES. The default setting is NO.
i
i
NOTE
For instantaneous tripping (undelayed) in the forward direction, the first zone Z1 should always be used, as
only the zone Z1 and Z1B are guaranteed to trip with the shortest operating time of the device. The further
zones should be used sequentially for grading in the forward direction.
If instantaneous tripping (undelayed) is required in the reverse direction, the zone Z3 should be used for
this purpose, as only this zone ensures instantaneous pickup with the shortest device operating time for
faults in the reverse direction. This setting is also recommended in teleprotection BLOCKING schemes.
With the binary input indications 3619
>BLOCK Z4 Ph-E
and 3620
>BLOCK Z5 Ph-E
and3622
>BLOCK
Z6 Ph-E
, the zones Z4, Z5 and Z6 can be blocked for phase-to-earth loops. To block these zones permanently
for phase-to-earth loops, these binary input indications must be set permanently to the logic value of 1 via
CFC.
Zone Z5 is preferably set as a non-directional final stage. It should include all other zones and also have suffi-
cient reach in reverse direction. This ensures adequate pickup of the distance protection in response to fault
conditions and correct verification of the short-circuit loops even under unfavourable conditions.
i
i
NOTE
Even if you do not need a non-directional distance stage, you should set Z5 according to the above aspects.
Setting T5 to infinite prevents that this stage causes a trip.
Controlled zone Z1B
The overreaching zone Z1B is a controlled zone. The normal zones Z1 to Z6 are not influenced by Z1B. There is
no zone switching, but rather the overreaching zone is activated or deactivated by the corresponding criteria.
In address 1351 Op. mode Z1B = Forward, it can also be switched to Reverse or Non-Directional. If
this stage is not required, it is set to Inactive (address 1351). The setting options are similar to those of
zone Z1: Address 1352 R(Z1B) Ø-Ø, address 1353 X(Z1B), address 1354 RE(Z1B) Ø-E. The delay times
for single-phase and multiple-phase faults can again be set separately: T1B-1phase (address 1355) and T1B-
multi-phase (address 1356). If parameter Op. mode Z1B is set to Forward or Reverse, a non-direc-
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tional trip is also possible in case of closure onto a fault if parameter 1232 SOTF zone is set to Z1B
undirect. (see also Section 2.2.1.3 Setting Notes).
Zone Z1B is often used in combination with automatic reclosure and/or teleprotection schemes. It can be acti-
vated internally by the teleprotection functions (see also Section 2.6 Teleprotection for distance protection) or
the integrated automatic reclosure (if available, see also Section 2.13 Automatic reclosure function
(optional)), or externally by a binary input. It is generally set to at least 120 % of the line length. On three-
terminal lines (“teed feeders”), it must be set to securely reach beyond the longest line section, even when
there is additional infeed via the tee point. The delay times are set in accordance with the type of application,
usually to zero or a very small delay. When used in conjunction with teleprotection comparison schemes, the
dependence on the fault detection must be considered (refer to margin heading “Distance Protection Prerequi-
sites” in Section 2.6.10 Setting Notes).
If the distance protection is used in conjunction with an external automatic recloser, it can be determined in
address 1357 1st AR -> Z1B which distance zone is released prior to starting the AR. Usually, the over-
reaching zone Z1B is used for the first cycle (1st AR -> Z1B = YES). This may be suppressed by changing
the setting of 1st AR -> Z1B to NO. In this case, the overreaching zone Z1B is not released before and
during the first automatic reclose cycle. Zone Z1 is always released. When using an external automatic
reclosing device, the setting only has an effect if the readiness of the automatic recloser is signalled via binary
input
>Enable ARzones
(No. 383).
The zones Z4, Z5 and Z6 can be blocked for phase-to-earth loops using a binary input message 3619
>BLOCK
Z4 Ph-E
, 3620
>BLOCK Z5 Ph-E
or 3622
>BLOCK Z6 Ph-E
. To block these zones permanently for phase-
to-earth loops, said binary inputs must be set to the logic value of 1 via CFC.
Minimum Current of Zone Z1
In earthed systems with parallel lines and single-side starpoint earthing, it can be necessary to enable tripping
of Z1 only above an increased phase current threshold value.For this purpose, you can define a separate
minimum current for the zone Z1 under address 1308 Iph>(Z1). The pickup of zone Z1 is in this case only
possible if the phase currents exceed this threshold value and are also above the threshold for enabling the
distance measurement (1202 Minimum Iph>, 1610 Iph>>, 1611 Iph>, 1616 Iphi>).
Parameter 1308 Iph>(Z1) is only visible and effective if the address 119 Iph>(Z1) is set to Enabled. The
use of a separate minimum current for Z1 is only recommended if the power system constellation has been
checked by calculations.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
1301 Op. mode Z1 Forward
Reverse
Non-Directional
Inactive
Forward Operating mode Z1
1302 R(Z1) Ø-Ø 1A 0.050 .. 600.000 Ω 1.250 Ω R(Z1), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 0.250 Ω
1303 X(Z1) 1A 0.050 .. 600.000 Ω 2.500 Ω X(Z1), Reactance
5A 0.010 .. 120.000 Ω 0.500 Ω
1304 RE(Z1) Ø-E 1A 0.050 .. 600.000 Ω 2.500 Ω RE(Z1), Resistance for ph-e
faults
5A 0.010 .. 120.000 Ω 0.500 Ω
1305 T1-1phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1-1phase, delay for single
phase faults
1306 T1-multi-phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1multi-ph, delay for multi
phase faults
1307 Zone Reduction 0 .. 45 ° 0 ° Zone Reduction Angle
(load compensation)
2.2.2.3
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Addr. Parameter C Setting Options Default Setting Comments
1308 Iph>(Z1) 1A 0.05 .. 20.00 A 0.20 A Minimum current for Z1
only Iph>(Z1)
5A 0.25 .. 100.00 A 1.00 A
1311 Op. mode Z2 Forward
Reverse
Non-Directional
Inactive
Forward Operating mode Z2
1312 R(Z2) Ø-Ø 1A 0.050 .. 600.000 Ω 2.500 Ω R(Z2), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 0.500 Ω
1313 X(Z2) 1A 0.050 .. 600.000 Ω 5.000 Ω X(Z2), Reactance
5A 0.010 .. 120.000 Ω 1.000 Ω
1314 RE(Z2) Ø-E 1A 0.050 .. 600.000 Ω 5.000 Ω RE(Z2), Resistance for ph-e
faults
5A 0.010 .. 120.000 Ω 1.000 Ω
1315 T2-1phase 0.00 .. 30.00 sec; ∞ 0.30 sec T2-1phase, delay for single
phase faults
1316 T2-multi-phase 0.00 .. 30.00 sec; ∞ 0.30 sec T2multi-ph, delay for multi
phase faults
1317A Trip 1pole Z2 NO
YES
NO Single pole trip for faults in
Z2
1321 Op. mode Z3 Forward
Reverse
Non-Directional
Inactive
Reverse Operating mode Z3
1322 R(Z3) Ø-Ø 1A 0.050 .. 600.000 Ω 5.000 Ω R(Z3), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 1.000 Ω
1323 X(Z3) 1A 0.050 .. 600.000 Ω 10.000 Ω X(Z3), Reactance
5A 0.010 .. 120.000 Ω 2.000 Ω
1324 RE(Z3) Ø-E 1A 0.050 .. 600.000 Ω 10.000 Ω RE(Z3), Resistance for ph-e
faults
5A 0.010 .. 120.000 Ω 2.000 Ω
1325 T3 DELAY 0.00 .. 30.00 sec; ∞ 0.60 sec T3 delay
1331 Op. mode Z4 Forward
Reverse
Non-Directional
Inactive
Non-Directional Operating mode Z4
1332 R(Z4) Ø-Ø 1A 0.050 .. 600.000 Ω 12.000 Ω R(Z4), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1333 X(Z4) 1A 0.050 .. 600.000 Ω 12.000 Ω X(Z4), Reactance
5A 0.010 .. 120.000 Ω 2.400 Ω
1334 RE(Z4) Ø-E 1A 0.050 .. 600.000 Ω 12.000 Ω RE(Z4), Resistance for ph-e
faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1335 T4 DELAY 0.00 .. 30.00 sec; ∞ 0.90 sec T4 delay
1341 Op. mode Z5 Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode Z5
1342 R(Z5) Ø-Ø 1A 0.050 .. 600.000 Ω 12.000 Ω R(Z5), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1343 X(Z5)+ 1A 0.050 .. 600.000 Ω 12.000 Ω X(Z5)+, Reactance for
Forward direction
5A 0.010 .. 120.000 Ω 2.400 Ω
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Addr. Parameter C Setting Options Default Setting Comments
1344 RE(Z5) Ø-E 1A 0.050 .. 600.000 Ω 12.000 Ω RE(Z5), Resistance for ph-e
faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1345 T5 DELAY 0.00 .. 30.00 sec; ∞ 0.90 sec T5 delay
1346 X(Z5)- 1A 0.050 .. 600.000 Ω 4.000 Ω X(Z5)-, Reactance for
Reverse direction
5A 0.010 .. 120.000 Ω 0.800 Ω
1351 Op. mode Z1B Forward
Reverse
Non-Directional
Inactive
Forward Operating mode Z1B (over-
rreach zone)
1352 R(Z1B) Ø-Ø 1A 0.050 .. 600.000 Ω 1.500 Ω R(Z1B), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 0.300 Ω
1353 X(Z1B) 1A 0.050 .. 600.000 Ω 3.000 Ω X(Z1B), Reactance
5A 0.010 .. 120.000 Ω 0.600 Ω
1354 RE(Z1B) Ø-E 1A 0.050 .. 600.000 Ω 3.000 Ω RE(Z1B), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 0.600 Ω
1355 T1B-1phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1B-1phase, delay for
single ph. faults
1356 T1B-multi-phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1B-multi-ph, delay for
multi ph. faults
1357 1st AR -> Z1B NO
YES
YES Z1B enabled before 1st AR
(int. or ext.)
1361 Op. mode Z6 Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode Z6
1362 R(Z6) Ø-Ø 1A 0.050 .. 600.000 Ω 15.000 Ω R(Z6), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 3.000 Ω
1363 X(Z6)+ 1A 0.050 .. 600.000 Ω 15.000 Ω X(Z6)+, Reactance for
Forward direction
5A 0.010 .. 120.000 Ω 3.000 Ω
1364 RE(Z6) Ø-E 1A 0.050 .. 600.000 Ω 15.000 Ω RE(Z6), Resistance for ph-e
faults
5A 0.010 .. 120.000 Ω 3.000 Ω
1365 T6 DELAY 0.00 .. 30.00 sec; ∞ 1.50 sec T6 delay
1366 X(Z6)- 1A 0.050 .. 600.000 Ω 4.000 Ω X(Z6)-, Reactance for
Reverse direction
5A 0.010 .. 120.000 Ω 0.800 Ω
Distance protection with MHO characteristic (optional)
The distance protection 7SA522 has a polygonal trip characteristic. Depending on which version was ordered
(10th digit of the order number ≠ A), it is possible to set to an MHO characteristic. If both characteristics are
available, they may be selected separately for phase-to-phase loops and phase-to-earth loops. If only the
polygonal tripping characteristic is used, please read Section 2.2.2 Distance protection with quadrilateral char-
acteristic (optional).
Functional Description
Basic characteristic
One MHO characteristic is defined for each distance zone, which represents the tripping characteristic of the
corresponding zone. In total there are six independent and one additional controlled zone for each fault impe-
dance loop. The basic shape of an MHO characteristic is shown in Figure 2-30 as an example of a zone.
2.2.3
2.2.3.1
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2.2 Distance Protection
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The MHO characteristic is defined by the line of its diameter which intersects the origin of the coordinate
system and the magnitude of the diameter which corresponds to the impedance Zr which determines the
reach, and by the angle of inclination. The angle of inclination is set in address 1211 Distance Angle and
corresponds normally to the line angle ϕLine. A load trapezoid with the setting RLoad and ϕLoad may be used to
cut the area of the load impedance out of the characteristic. The reach Zr may be separately set for each zone;
the inclination angle ϕDist as well as the load impedance parameters RLoad, and ϕLoadare common to all zones. As
the characteristic intersects the origin of the coordinate system, a separate directional characteristic is not
required.
[grundform-der-mho-kreis-charakteristik-240402-wlk, 1, en_GB]
Figure 2-30 Basic shape of an MHO characteristic
Polarised MHO characteristic
As is the case with all characteristics that pass through the origin of the coordinate system, the MHO charac-
teristic boundary around the origin itself is also not defined as the measured voltage is zero or too small to be
evaluated in this case. For this reason, the MHO characteristic is polarized. The polarization determines the
lower zenith of the circle, i.e. the lower intersection of the diameter line with the circumference. The upper
zenith which is determined by the reach setting Zr remains unchanged. Immediately after fault inception, the
shortcircuit voltage is disturbed by transients; the voltage memorized prior to fault inception is therefore used
for polarization. This causes a displacement of the lower zenith by an impedance corresponding to the memo-
rized voltage (refer to Figure 2-31). When the memorized short-circuit voltage is too small, an unfaulted
voltage is used. In theory, this voltage is perpendicular to the voltage of the faulted loop for both phase-to-
earth loops as well as phase-to-phase loops. This is taken into account by the calculation by means of a 90°
rotation. The unfaulted loop voltage also causes a displacement of the lower zenith of the MHO characteristic.
Functions
2.2 Distance Protection
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[polar-mho-kreis-041102-wlk, 1, en_GB]
Figure 2-31 Polarized MHO characteristic
Properties of the MHO Characteristic
As the quadrature or memorized voltage (without load transfer) equals the corresponding generator voltage E
and does not change after fault inception (refer also to Figure 2-32), the lower zenith is shifted in the impe-
dance diagram by the polarization quantity k·ZS1 = k·E1/Ι1. The upper zenith is still defined by the setting value
Zr. For the fault location F1 (Figure 2-32a), the short-circuit is in the forward direction and the source impe-
dance is in the reverse direction. All fault locations right up to the device mounting location (current trans-
formers) are clearly inside the MHO characteristic (Figure 2-32b). If the current is reversed, the zenith of the
circle diameter changes abruptly (Figure 2-32c). A reversed current Ι2 which is determined by the source impe-
dance ZS2 + ZL now flows via the measuring location (current transformer) . The zenith Zr remains unchanged;
it now is the lower boundary of the circle diameter. In conjunction with load transport via the line, the zenith
vector may additionally be rotated by the load angle.
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[moh-kreis-kurzschl-frmd-gesp-spg-wlk041102, 1, en_GB]
Figure 2-32 Polarized MHO characteristic with quadrature or memorized voltages
Selecting Polarization
Incorrect directional decisions may be reached with short lines resulting in tripping or blocking in spite of a
reverse fault. This occurs because their zone reach is set very small. Therefore their loop voltages are also very
small, resulting in the phase angle comparison between difference voltage and loop voltage being insuffi-
ciently accurate. If phase angle comparison is performed using a polarization voltage consisting of a loop
voltage component recorded before the fault and a component of the current loop voltage, these problems
may be avoided. The following equation shows the polarization voltage UP for a Ph-E loop:
UP = (1 – kPre) · UL-E + kPre · UPh-EMemorized
The evaluation (factor kPre) of the prefault voltage may be set separately for Ph-E and Ph-Ph loops. In general
the factor is set to 15 %. The memory polarization is only performed if the RMS value of the corresponding
memorized voltage for Ph-E loops is greater than a 40 % of the nominal voltage UN (address 204) and greater
than a 70 % of UN for Ph-Ph loops.
If there is no prefault voltage due to a sequential fault or energization onto a fault, the memorized voltage can
only be used for a limited time for reasons of accuracy. For single-pole faults and two-pole faults without earth
path component, a voltage which is not involved in the fault may be used for polarisation. This voltage is
rotated by 90° in comparison with the fault-accurate voltage (cross polarization). The polarisation voltage UP is
a mixed voltage which consists of the valid voltage and the corresponding unfaulted voltages. The following
equation shows the polarization voltage UP for a Ph-E loop:
UP = (1 – kCross) · UL-E + kCross · UL-EUnfaulted
The cross polarisation is used if no memorized voltage is available. The evaluation (factor kCross) of the voltage
may be set separately for Ph-E and Ph-Ph loops. In general the factor is set to 15 %.
i
i
NOTE
When switching onto a three-pole fault with the MHO characteristic, there is no memory voltage or
unfaulted loop voltage available. To ensure fault clearance when switching onto three-pole close-up faults,
please make sure that in conjunction with the configured MHO characteristic the instantaneous tripping
function is always enabled.
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2.2 Distance Protection
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Determination of direction in case of series-compensated lines
If a short-circuit occurs behind the local series capacitor, the short-circuit voltage however is inverted until the
protective spark gap PSG has picked up (see the following Figure).
[richtgbest-serie-komp-ltgn-wlk-030903, 1, en_GB]
Figure 2-33 Voltage characteristic while a fault occurs after a series capacitor
a) without pickup of the protective spark gap
b) with pickup of the protective spark gap
As the polarization voltage of the MHO characteristic consists of the currently measured voltage and the
voltage measured before the occurrence of the fault, it is possible that the distance protection function would
detect a wrong fault direction. To prevent spurious trippings or erroneous pickups, a memory voltage propor-
tion of up to 80 % could be necessary. This, however, would lead to a considerable increase of the MHO char-
acteristic. This increase is usually not acceptable.
Therefore an additional measurement with exclusively memorized voltage is performed for applications with
series compensation. This ensures a correct direction measurement at any time (see Figure 2-34) and the
MHO distance zones are not increased more than necessary.
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2.2 Distance Protection
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[mho-serienkomp-ltg-20101119, 1, en_GB]
Figure 2-34 Use of the MHO characteristic for series compensated lines
The direction measurement is performed at 100 % by means of memorized voltage. A zone pickup is only
possible if this measurement confirms that the direction of the short-circuit corresponds to the parameterized
direction of the zone.
The distance measurement itself is performed by means of the usual polarization voltage UP and is performed
in the forward direction as well as in the reverse direction. This ensures a pickup even in cases in which the
series capacitor usually causes the inversion of the direction result.
Assignment to tripping zones and zone pickup
The assignment of measured values to the tripping zones of the MHO characteristic is done for each zone by
determining the angles between two difference phasors ΔZ1 and ΔZ2 (Figure 2-35). These phasors result from
the difference between the two zeniths of the circle diameter and the fault impedance. The zenith Zr corre-
sponds to the set value for the zone under consideration (Zr and ϕMHO as shown in Figure 2-30), the zenith k·ZS
corresponds to the polarization magnitude. Therefore the difference phasors are
ΔZ1 = ZF – Zr
ΔZ2 = ZF – k·ZS
Im Grenzfall liegt ZF auf der Kreisperipherie. Dann ist der Winkel zwischen den beiden Differenzzeigern 90°
(Thales-Satz). Innerhalb der Kennlinie ist der Winkel größer, außerhalb kleiner als 90°.
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2.2 Distance Protection
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[messgroessen-moh-kreis-wlk-041102, 1, en_GB]
Figure 2-35 Phasor diagram of the MHO characteristic measured values
For each distance zone an MHO characteristic can be defined by means of the parameter Zr. For each zone it
may also be determined whether it operates forwards or reverse. In reverse direction the MHO characteristic
is mirrored in the origin of the coordinate system. As soon as the fault impedance of any loop is confidently
measured inside the MHO characteristic of a distance zone, the affected loop is designated as “picked up”. The
loop information is also converted to phase-segregated information. Another condition for pickup is that the
distance protection may not be blocked or switched off completely. Figure 2-36 shows these conditions.
The zones and phases of such a valid pickup, e.g. “Dis. Z1 L1” for zone Z1 and phase L1 are processed by the
zone logic and the supplementary functions (e.g. teleprotection logic).
[freigabelogikeinerzonebeispiel-fuer-z1-mho-111202-wlk, 1, en_GB]
Figure 2-36 Release logic of a zone (example for Z1)
*) forward and reverse only affect the measured quantities and not the logic
In total, the following zones are available:
Independent zones:
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•1st zone (fast tripping zone) Z1 with ZR(Z1); may be delayed withT1-1phase bzw. T1-multi-phase,
•2nd zone (backup zone) Z2 with ZR(Z2); may be delayed with T2-1phase bzw. T2-multi-phase,
•3rd zone (backup zone) Z3 with ZR(Z3); may be delayed with T3 DELAY,
•4th zone (backup zone) Z4 with ZR(Z4); may be delayed with T4 DELAY,
•5th Zone (backup zone) Z5 with ZR(Z5); may be delayed with T5 DELAY,
•6th Zone (backup zone) Z6 with ZR(Z6); may be delayed with T6 DELAY.
Dependent (controlled) zone:
•Overreaching zone Z1B with ZR(Z1B); may be delayed with T1B-1phase bzw. T1B-multi-phase.
Setting Notes
General
The function parameters for the MHO characteristic only apply if during the configuration of the scope of func-
tions the MHO characteristic was selected for phase-to-phase measurement (address 112) and/or phase-
toearth measurement (address 113).
Grading coordination chart
It is recommended to initially create a grading coordination chart for the entire galvanically interconnected
system. This diagram should reflect the line lengths with their primary impedances Z in Ω/km. For the reach of
the distance zones, the impedances Z are the deciding quantities.
The first zone Z1 is usually set to cover 85% of the protected line without any trip time delay (i.e. T1 = 0.00 s).
The protection clears faults in this range without additional time delay, i.e. the tripping time is the relay basic
operating time.
The tripping time of the higher zones is sequentially increased by one time grading interval. The grading
margin must take into account the circuit breaker operating time including the spread of this time, the reset-
ting time of the protection equipment as well as the spread of the protection delay timers. Typical values are
0.2 s to 0.4 s. The reach is selected to cover up to approximately 80 % of the zone with the same set time
delay on the shortest neighbouring feeder (Figure 2-26).
[reichweit-staffelpl-wlk-040818, 1, en_GB]
Figure 2-37 Setting the reach - example for device A
s1, s2 Protected line section
When using a personal computer and DIGSI to apply the settings, these can be optionally entered as primary
or secondary values.
In the case of parameterization with secondary quantities, the values derived from the grading coordination
chart must be converted to the secondary side of the current and voltage transformers. In general:
[formel-dis-poly-staffelpl-1-oz-010802, 1, en_GB]
Accordingly, the reach for any distance zone can be specified as follows:
2.2.3.2
Functions
2.2 Distance Protection
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[formelreichweitediszoneallg-240402wlk, 1, en_GB]
with
NCT = Current transformer ratio
NVT = Transformation ratio of voltage transformers
On long, heavily loaded lines, the MHO characteristic may extend into the load impedance range. This is of no
consequence as the pickup by overload is prevented by the load trapezoid. Refer to margin heading “Load
Area” in Section 2.2.1 Distance protection, general settings.
Calculation Example::
110 kV overhead line 150 mm2 with the following data:
s (length) = 35 km
R1/s = 0,19 Ω/km
X1/s = 0,42 Ω/km
R0/s = 0,53 Ω/km
X0/s = 1,19 Ω/km
Current Transformer 600 A/5 A
Voltage Transformer 110 kV/0,1 kV
The following line data is calculated:
RL = 0,19 Ω/km · 35 km = 6,65 Ω
XL = 0,42 Ω/km · 35 km = 14,70 Ω
For the first zone, a setting of 85 % of the line length should be applied, which results inprimary:
X1prim = 0,85 · XL = 0,85 · 14,70 Ω = 12,49 Ω
or secondary:
[formel-dis-poly-staffelpl-3-oz-010802, 1, en_GB]
Independent Zones Z1 up to Z6
With the parameter MODE Forward or Reverse, each zone can be set (address 1401 Op. mode Z1, 1411
Op. mode Z2, 1421 Op. mode Z3, 1431 Op. mode Z4, 1441 Op. mode Z5 and 1461 Op. mode Z6).
This allows any combination of forward or reverse graded zones. Zones that are not required are set Inac-
tive.
The values derived from the grading coordination chart are set for each of the required zones. The setting
parameters are grouped for each zone. For the first zone these are the parameters ZR(Z1) (address 1402)
specifying the impedance of the upper zenith of the MHO characteristic from the origin (reach), as well as the
relevant delay time settings.
Different delay times can be set for single- and multiple-phase faults in the first zone: T1-1phase (address
1305) and T1-multi-phase (address 1306). The first zone is normally set to operate without additional
time delay.
For the remaining zones the following correspondingly applies:
ZR(Z2) (address 1412)
ZR(Z3) (address 1422)
ZR(Z4) (address 1432)
ZR(Z5) (address 1442)
ZR(Z6) (address 1462)
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For the second zone it is also possible to set separate delay times for single-phase and multi-phase faults. In
general the delay times are set the same. If stability problems are expected during multi-phase faults, a shorter
delay time could be considered for T2-multi-phase (address 1316) while tolerating a longer delay time for
single-phase faults with T2-1phase (address 1315).
The zone timers for the remaining zones are set with the parameters T3 DELAY (address 1325), T4 DELAY
(address 1335), T5 DELAY (address 1345), and T6 DELAY (address 1365).
If the device is provided with the capability to trip single-pole, single-pole tripping is then possible in the zones
Z1 and Z2. While single-pole tripping usually applies to single-phase faults in Z1 (if the remaining conditions
for single-pole tripping are satisfied), this may also be selected for the second zone with address 1317 Trip
1pole Z2. Single pole tripping in zone 2 is only possible if this address is set to Yes. The default setting is No.
i
i
NOTE
For instantaneous tripping (undelayed) in the forward direction, the first zone Z1 should always be used, as
only the Z1 and Z1B are guaranteed to trip with the shortest operating time of the device. The further
zones should be used sequentially for grading in the forward direction.
If instantaneous tripping (undelayed) is required in the reverse direction, the zone Z3 should be used for
this purpose, as only this zone ensures instantaneous pickup with the shortest device operating time for
faults in the reverse direction. This setting is also recommended in teleprotection BLOCKING schemes.
With the binary input indications No. 3619
>BLOCK Z4 Ph-E
, No. 3620
>BLOCK Z5 Ph-E
and No. 3622
>BLOCK Z6 Ph-E
, the zones Z4, Z5, and Z6 for phase-to-earth loops may be blocked. To block these zones
permanently for phase-to-earth loops, these binary input indications must be set permanently to the logic
value of 1 via CFC.
Controlled zone Z1B
The overreaching zone Z1B is a controlled zone. It does not influence the normal zones Z1 to Z6. There is no
zone switching, but rather the overreaching zone is activated or deactivated by the corresponding criteria. It
can also be set in address 1451 Op. mode Z1B to Forward or Reverse. If this stage is not required, it is set
to Inactive (address 1451). The setting options are similar to those of zone Z1: Address 1452 ZR(Z1B).
The delay times for single-phase and multiple-phase faults can again be set separately: T1B-1phase (address
1355) and T1B-multi-phase (address 1356).
Zone Z1B is often used in combination with automatic reclosure and/or teleprotection schemes. It can be acti-
vated internally by the teleprotection functions (see also Section 2.6 Teleprotection for distance protection) or
the integrated automatic reclosure (if available, see also Section 2.13 Automatic reclosure function
(optional)), or externally by a binary input. It is generally set to at least 120 % of the line length. On three-
terminal lines (“teed feeders”), it must be set to securely reach beyond the longest line section, even when
there is additional infeed via the tee-off point. The delay times are set in accordance with the type of applica-
tion, usually to zero or a very small delay. When used in conjunction with teleprotection comparison schemes,
the dependence on the fault detection must be considered (refer to margin heading “Distance Protection
Prerequisites” in Section 2.6.10 Setting Notes.
If the distance protection is used in conjunction with the internal or an automatic recloser, it may be deter-
mined in address 1357 1st AR -> Z1B which distance zone is released prior to starting the AR. Usually the
overreaching zone Z1B is used for the first cycle (1st AR -> Z1B = YES). This may be suppressed by
changing the setting of 1st 1st AR -> Z1B to NO. In this case, overreaching zone Z1B is not released before
and during the first automatic reclose cycle. Zone Z1 is always released. When using an external automatic
reclose device, the setting only has an effect if the readiness of the automatic recloser is signalled via binary
input
>Enable ARzones
(No. 383).
Polarization
The degree of polarization with a fault-accurate memory voltage can be set in address 1471
Mem.Polariz.PhE for phase-to-earth loops, and in address 1473 Mem.Polariz.P-P for phase-to-phane
loops. For polarization with an unfaulted valid voltage (cross-polarization), the evaluation factor can be set
separately for phase-to-earth and phase-to-phase loops under address 1472 CrossPolarizPhE and 1474
CrossPolarizP-P. This setting can only be changed using DIGSI at Additional Settings.
Functions
2.2 Distance Protection
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These parameters have an impact on the expansion of the characteristics dependent on the source impe-
dance. If these parameters are set to zero, the basic characteristic is displayed without any expansion.
Minimum Current of Zone Z1
In earthed systems with parallel lines without zero-sequence system infeed at the opposite line end, it may be
necessary to allow a tripping of Z1 only when exceeding an increased phase current threshold. For this
purpose, you can define a separate minimum current for the zone Z1 in address 1308 Iph>(Z1). A pickup of
zone Z1 is only possible if the phase currents have exceeded this threshold value. This parameter is only avail-
able if address 119 Iph>(Z1) is set to Enabled.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
1305 T1-1phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1-1phase, delay for single
phase faults
1306 T1-multi-phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1multi-ph, delay for multi
phase faults
1308 Iph>(Z1) 1A 0.05 .. 20.00 A 0.20 A Minimum current for Z1
only Iph>(Z1)
5A 0.25 .. 100.00 A 1.00 A
1315 T2-1phase 0.00 .. 30.00 sec; ∞ 0.30 sec T2-1phase, delay for single
phase faults
1316 T2-multi-phase 0.00 .. 30.00 sec; ∞ 0.30 sec T2multi-ph, delay for multi
phase faults
1317A Trip 1pole Z2 NO
YES
NO Single pole trip for faults in
Z2
1325 T3 DELAY 0.00 .. 30.00 sec; ∞ 0.60 sec T3 delay
1335 T4 DELAY 0.00 .. 30.00 sec; ∞ 0.90 sec T4 delay
1345 T5 DELAY 0.00 .. 30.00 sec; ∞ 0.90 sec T5 delay
1355 T1B-1phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1B-1phase, delay for
single ph. faults
1356 T1B-multi-phase 0.00 .. 30.00 sec; ∞ 0.00 sec T1B-multi-ph, delay for
multi ph. faults
1357 1st AR -> Z1B NO
YES
YES Z1B enabled before 1st AR
(int. or ext.)
1365 T6 DELAY 0.00 .. 30.00 sec; ∞ 1.50 sec T6 delay
1401 Op. mode Z1 Forward
Reverse
Inactive
Forward Operating mode Z1
1402 ZR(Z1) 1A 0.050 .. 200.000 Ω 2.500 Ω ZR(Z1), Impedance Reach
5A 0.010 .. 40.000 Ω 0.500 Ω
1411 Op. mode Z2 Forward
Reverse
Inactive
Forward Operating mode Z2
1412 ZR(Z2) 1A 0.050 .. 200.000 Ω 5.000 Ω ZR(Z2), Impedance Reach
5A 0.010 .. 40.000 Ω 1.000 Ω
1421 Op. mode Z3 Forward
Reverse
Inactive
Reverse Operating mode Z3
2.2.3.3
Functions
2.2 Distance Protection
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Addr. Parameter C Setting Options Default Setting Comments
1422 ZR(Z3) 1A 0.050 .. 200.000 Ω 5.000 Ω ZR(Z3), Impedance Reach
5A 0.010 .. 40.000 Ω 1.000 Ω
1431 Op. mode Z4 Forward
Reverse
Inactive
Forward Operating mode Z4
1432 ZR(Z4) 1A 0.050 .. 200.000 Ω 10.000 Ω ZR(Z4), Impedance Reach
5A 0.010 .. 40.000 Ω 2.000 Ω
1441 Op. mode Z5 Forward
Reverse
Inactive
Inactive Operating mode Z5
1442 ZR(Z5) 1A 0.050 .. 200.000 Ω 10.000 Ω ZR(Z5), Impedance Reach
5A 0.010 .. 40.000 Ω 2.000 Ω
1451 Op. mode Z1B Forward
Reverse
Inactive
Forward Operating mode Z1B
(extended zone)
1452 ZR(Z1B) 1A 0.050 .. 200.000 Ω 3.000 Ω ZR(Z1B), Impedance Reach
5A 0.010 .. 40.000 Ω 0.600 Ω
1461 Op. mode Z6 Forward
Reverse
Inactive
Inactive Operating mode Z6
1462 ZR(Z6) 1A 0.050 .. 200.000 Ω 15.000 Ω ZR(Z6), Impedance Reach
5A 0.010 .. 40.000 Ω 3.000 Ω
1471A Mem.Polariz.PhE 0.0 .. 100.0 % 15.0 % Voltage Memory polariza-
tion (phase-e)
1472A CrossPolarizPhE 0.0 .. 100.0 % 15.0 % Cross polarization (phase-
e)
1473A Mem.Polariz.P-P 0.0 .. 100.0 % 15.0 % Voltage Memory polariza-
tion (ph-ph)
1474A CrossPolarizP-P 0.0 .. 100.0 % 15.0 % Cross polarization (phase-
phase)
Tripping Logic of the Distance Protection
Functional Description
General Device Pickup
As soon as any one of the distance zones has determined with certainty that the fault is inside its tripping
range, the signal
Dis. PICKUP
(general fault detection of the distance protection) is generated. This signal is
alarmed and made available for the initialization of internal and external supplementary functions. (e.g. tele-
protection signal transmission, automatic reclosure).
Zone logic of the independent zones Z1 up to Z6
As was mentioned in the description of the measuring methods, each distance zone generates an output
signal which is associated with the zone and the affected phase. The zone logic combines these zone fault
detections with possible further internal and external signals. The delay times for the distance zones can be
started either all together on general fault detection by the distance protection function, or individually at the
moment the fault enters the respective distance zone. Parameter Start Timers (address 1210) is set by
default to on Dis. Pickup. This setting ensures that all delay times continue to run together even if the
type of fault or the selected measuring loop changes, e.g. because an intermediate infeed is switched off. It is
also the preferred setting if other distance protection relays in the power system are working with this start
2.2.4
2.2.4.1
Functions
2.2 Distance Protection
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timing. Where grading of the delay times is especially important, for instance if the fault location shifts from
zone Z3 to zone Z2, the setting on Zone Pickup should be chosen. The simplified zone logic is shown in
Figure 2-38 for zone 1, Figure 2-39 for zone 2 and Figure 2-40 for zone 3. Zones Z4, Z5 and Z6 function
according to Figure 2-41.
In the case of zones Z1, Z2 and Z1B single-pole tripping is possible for single-phase faults if the device version
includes the single-pole tripping option. Therefore the event output in these cases is provided for each pole.
Different trip delay times can be set for single-phase and multiple-phase faults in these zones. In further
zones, the tripping is always three-pole.
i
i
NOTE
The binary input
>1p Trip Perm
(No. 381) must be activated to enable single-pole tripping. The internal
automatic reclosure function may also grant the single-pole permission. The binary input is usually
controlled from an external automatic reclosure device.
The trip delay times of the zones can be bypassed. The grading times are started either via zone pickup or
general pickup of the distance protection function. The undelayed release results from the line energization
logic. This logic may be externally initiated via the circuit breaker close signal derived from the circuit breaker
control switch or from an internal line energization detection. Zones Z4, Z5 and Z6 may be blocked by external
criteria (No. 3617
>BLOCK Z4-Trip
, no. 3618
>BLOCK Z5-Trip
, no. 3621
>BLOCK Z6-Trip
) blockiert
werden.
[ausloeselogik-fuer-die-1-zone-240402wlk, 1, en_GB]
Figure 2-38 Tripping logic for the 1st zone
Functions
2.2 Distance Protection
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[ausloeselogik-fuer-die-2-zone-240402wlk, 1, en_GB]
Figure 2-39 Tripping logic for the 2nd zone
[ausloeselogik-fuer-die-3-zone-240402wlk, 1, en_GB]
Figure 2-40 Tripping logic for the 3rd zone
[ausloeselogik-fuer-die-4-und-5-zone-dargestellt-fuer-z4-240402wlk, 1, en_GB]
Figure 2-41 Tripping logic for the 4th, 5th, and 6th zone, shown for Z4
Functions
2.2 Distance Protection
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Zone logic of the controlled zone Z1B
The controlled zone Z1B is usually applied as an overreaching zone. The logic is shown in Figure 2-42. It may
be activated via various internal and external functions. The binary inputs for external activation of Z1B of the
distance protection are
>ENABLE Z1B
and
>Enable ARzones
. The former can, for example, be from an
external teleprotection device, and only affects Z1B of the distance protection. The latter can also be
controlled, e.g. by an external automatic reclosure device. In addition, it is possible to use zone Z1B as a rapid
autoclosure stage that only operates for single-pole faults, for example, if only single-pole automatic reclose
cycles are to be executed.
It is possible for the 7SA522 to trip single-pole during two-phase faults without earth connection in the over-
reaching zone when single-pole automatic reclosure is used.
As the device features an integrated teleprotection function, release signals from this function may activate
zone Z1B provided that the internal teleprotection signal transmission function has been configured to one of
the available schemes with parameter 121 Teleprot. Dist., i.e., the function has not been set to Disa-
bled). If the integrated AR function is activated, zone Z1B can be released in the first AR cycle provided that
parameter 1357 1st AR -> Z1B is set accordingly.
If the distance protection is operated with one of the teleprotection schemes described in Section 2.6 Telepro-
tection for distance protection, the signal transmission logic controls the overreaching zone, i.e. it determines
whether a non-delayed trip (or delayed with T1B) is permitted in the event of faults in the overreaching zone
(i.e. up to the reach limit of zone Z1B) at both line ends. Whether the automatic reclosure device is ready for
reclosure or not is irrelevant since the teleprotection function ensures the selectivity over 100% of the line
length and fast tripping.
If, however, the signal transmission is switched off or the transmission path is disturbed, the internal auto-
matic reclosure circuit can determine whether the overreaching zone (Z1B in the distance protection) is
released for fast tripping. If no reclosure is expected (e.g. circuit breaker not ready) the normal grading of the
distance protection (i.e. fast tripping only for faults in zone Z1) must apply to retain selectivity.
Fast tripping before reclosure is also possible with multiple reclosures. Appropriate links between the output
signals (e.g. 2nd reclosure ready: No. 2890,
AR 2.CycZoneRel
) and the inputs for enabling/releasing
nondelayed tripping of the protection functions can be established via the binary inputs and outputs (No. 383,
>Enable ARzones
) or the integrated user-definable logic functions (CFC).
Functions
2.2 Distance Protection
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[ausloeselogik-fuer-gesteuerte-zone-z1b-240402wlk, 1, en_GB]
Figure 2-42 Tripping logic for the controlled zone Z1B
Tripping logic
In the actual tripping logic, the output signals generated by the individual zones are combined to form the
output signals
Dis.Gen. Trip
,
Dis.Trip 1pL1
,
Dis.Trip 1pL2
,
Dis.Trip 1pL3
,
Dis.Trip 3p
.
The single-pole information implies that only a single-pole tripping will take place. Furthermore, the zone that
initiated the tripping is identified; if single-pole tripping is possible, this is also signalled as shown in the zone
logic diagrams (Figure 2-38 to Figure 2-42). The actual generation of the commands for the tripping (output)
relay is executed within the tripping logic of the entire device.
Functions
2.2 Distance Protection
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Setting Notes
The trip delay times of the distance stages and intervention options which are also processed in the tripping
logic of the distance protection were already considered with the zone settings. Further setting options which
affect the tripping are described as part of the tripping logic of the device.
2.2.4.2
Functions
2.2 Distance Protection
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Power swing detection (optional)
The 7SA522 has an integrated power swing supplement which allows both the blocking of trips by the
distance protection during power swings (power swing blocking) and the tripping during unstable power
swings (out-ofstep tripping). To avoid uncontrolled tripping, the distance protection devices are supplemented
with power swing blocking functions. At particular locations in the system, out-of-step tripping devices are
also applied to split the system into islanded networks at selected locations, when system stability
(synchronism) is lost due to severe (unstable) power swings.
Allgemeines
Following dynamic events such as load jumps, faults, reclose dead times or switching actions it is possible that
the generators must realign themselves, in an oscillatory manner, with the new load balance of the system.
The distance protection registers large transient currents during the power swing and, especially at the elec-
trical centre, small voltages (Figure 2-43). Small voltages with simultaneous large currents apparently imply
small impedances, which again could lead to tripping by the distance protection. In expansive networks with
large transferred power, even the stability of the energy transfer could be endangered by such power swings.
[pendelung-wlk-290702, 1, en_GB]
Figure 2-43 Measured quantities during a power swing
System power swings are three-phase symmetrical processes. Therefore a certain degree of measured value
symmetry may be assumed in general. System power swings may, however, also occur during asymmetrical
processes, e.g. after faults or during a single-pole dead time. Thus the power swing detection in the 7SA522 is
based on three measuring systems. For each phase, there is a measuring system that ensures phase-selective
power swing detection. In case of faults, the detected power swing is terminated in the corresponding phases,
which enables selective tripping of the distance protection.
Funktionsbeschreibung
To detect a power swing, the rate of change of the impedance vectors is measured.
[impedanzvektoren-21062010, 1, en_GB]
Figure 2-44 Impedance vectors during a power swing and during a fault
To ensure stable and secure operation of the power swing detection without the risk of an overfunction of the
power swing detection during a fault, the following measuring criteria are used:
2.3
2.3.1
2.3.2
Functions
2.3 Power swing detection (optional)
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•Trajectory monotony:
During a power swing, the measured impedance features a directional course of movement. This course
of movement occurs exactly when not more than one of the two components ΔR and ΔX features a
change of direction within one measuring window. A fault usually causes a change of direction in ΔR as
well as in ΔX within one measuring window.
•Trajectory continuity:
During a power swing, the distance between two subsequent impedance values features a clear change
in ΔR or ΔX. In case of a fault, the impedance vector jumps to the fault impedance without moving after-
wards.
•Trajectory uniformity:
During a power swing, the ratio between two subsequent changes of ΔR or ΔX will not exceed a
threshold. A fault usually causes an abrupt jump of the impedance vector from the load impedance to the
fault impedance.
The indication of a power swing is triggered when the impedance vector enters the power swing measuring
range PPOL (refer to the following figure) and the criteria of power swing detection are met. The fault detec-
tion range APOL for the polygonal characteristic is made up of the largest quantitative values set for R and X of
all active zones. The power swing area has a minimum distance ZDiffof 5 Ω (at ΙN = 1 A) or 1 Ω (at ΙN = 5 A) in
all directions from the fault detection zone. Analog features apply for the MHO characteristics. The power
swing circle also has a distance of 5 Ω (at IΙN = 1 A) or 1 Ω (at IΙN = 5 A) from the largest zone circle. The power
swing measuring range has no load trapezoid cutout.
[arbeitsbereich-21062010, 1, en_GB]
Figure 2-45 Operating range of the power swing detection for polygon and MHO characteristics
In Figure 2-46, a simplified logic diagram for the power swing function is given. This measurement is executed
per phase. A power swing signal will be generated if the measured impedance is inside the power swing
polygon (PPOL). The power swing signal remains active until a fault occurs or until the power swing has
decayed. The power swing detection can be blocked via the binary input No. 4160
>Pow. Swing BLK
.
Functions
2.3 Power swing detection (optional)
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[logikdia-der-pendelerfassung-240402-wlk, 1, en_GB]
Figure 2-46 Logic diagram of power swing detection
Power Swing Blocking
The power swing blocking function blocks the tripping of the distance protection for specific zones (which are
set under address 2002 P/S Op. mode) phase-selectively:
•Blocking of the trip command for all zones (All zones block): The trip command of the distance
protection is blocked for all zones during a power swing.
•Blocking of the trip command for the first zone only (Z1/Z1B block): Only the trip command of the
first zone and of the overreaching zone (Z1 and Z1B) are blocked during a power swing. A pickup in a
different zone (Z2 and higher) can lead to a trip command in the case of a power swing after the associ-
ated grading time has expired.
•Blocking of the trip command for the higher zones only (>= Z2 block): Z2 and the higher zones are
blocked for the tripping during a power swing. Only a pickup in the first zone or the overreach zone (Z1
and Z1B) can lead to a trip command.
•Blocking of the first two zones (Z1,Z1B,Z2 block): The trip commands of the first and second zone
(Z1 and Z2) and the overreaching zone (Z1B) are blocked during a power swing. A pickup in a different
zone (Z3 and higher) can lead to a trip command in the case of a power swing after the associated
grading time has expired.
[zonenblock-durchp-sperre-wlk-040624, 1, en_GB]
Figure 2-47 Blocking logic of the power swing supplement
Functions
2.3 Power swing detection (optional)
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Power Swing Tripping
If tripping in the event of an unstable power swing (out-of-step condition) is desired, the parameter Power-
Swing trip (address 2006) = YES is set. If the criteria for power swing detection are met, the distance
protection is initially blocked according to the configured program for power swing blocking, to avoid tripping
by the distance protection.
When the impedance vectors identified by the power swing detection exit the pickup characteristic APOL, the
sign of the R components in the vectors are checked to see if they are the same on exiting and entering the
pickup polygon. If this is the case, the power swing process is inclined to stabilize. Otherwise, the vector has
passed through the pickup characteristic (loss of synchronism). In this case, stable power transmission is no
longer possible. The device outputs an alarm to that effect (No 4163
P.Swing unstab.
). The alarm No.
4163
P.Swing unstab.
is a pulse with a duration of approx. 50 ms, which can also be processed further via
output relays or CFC links, e.g. for a cycle counter or a pulse counter.
If instability is detected, the device issues a three-pole trip command, thereby isolating the two system
segments from each other. Power swing tripping is signalled.
Indication No. 4177
P.Swing unst. 2
will already be transmitted when the impedance vector passes the
polygon bisect through the origin. The angle of this straight line corresponds to the inclination angle of the
polygons (address 1211 Distance Angle). Normally, this straight line is identical with the impedance char-
acteristic of the power line. This indication is also a pulse with a duration of approx. 50 ms, which can also be
processed further via CFC logic operation. However, it does not result in power swing tripping.
[pen-erkenn-21062010, 1, en_GB]
Figure 2-48 Detection of instable power swings
As the operating range of the power swing supplement depends on the distance protection settings, the
power swing tripping can only be active when the distance protection has been activated.
Setting Notes
The power swing supplement is only active if it has been set to Power Swing = Enabled (address 120)
during the configuration.
The 4 possible programs may be set in address 2002 P/S Op. mode, as described in Section 2.3 Power swing
detection (optional): All zones block, Z1/Z1B block, >= Z2 block or Z1,Z1B,Z2 block.
Additionally the tripping function for unstable power swings (asynchronism) can be set with parameter
PowerSwing trip (address 2006), which should be set to YES if required (presetting is NO). In the event of
power swing tripping it is sensible to set P/S Op. mode = All zones block for the power swing blocking
to avoid premature tripping by the distance protection.
2.3.3
Functions
2.3 Power swing detection (optional)
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i
i
NOTE
The power swing supplement works together with the impedance pickup and is only available in this
combination.
Settings
Addr. Parameter Setting Options Default Setting Comments
2002 P/S Op. mode All zones block
Z1/Z1B block
>= Z2 block
Z1,Z1B,Z2 block
All zones block Power Swing Operating mode
2006 PowerSwing trip NO
YES
NO Power swing trip
Information List
No. Information Type of
Informa-
tion
Comments
4160 >Pow. Swing BLK SP >BLOCK Power Swing detection
4163 P.Swing unstab. OUT Power Swing unstable
4164 Power Swing OUT Power Swing detected
4166 Pow. Swing TRIP OUT Power Swing TRIP command
4167 Pow. Swing L1 OUT Power Swing detected in L1
4168 Pow. Swing L2 OUT Power Swing detected in L2
4169 Pow. Swing L3 OUT Power Swing detected in L3
4177 P.Swing unst. 2 OUT Power Swing unstable 2
2.3.4
2.3.5
Functions
2.3 Power swing detection (optional)
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Protection data interfaces and communication topology (optional)
Where a teleprotection scheme is to be used to achieve 100 % instantaneous protection (Section 2.6 Telepro-
tection for distance protection), digital communication channels can be used for data transmission between
the devices. In addition to the protection data, other data can be transmitted and thus be made available at
the line ends. This data includes synchronization and topology data, as well as remote trip signals, remote
annunciation signals and measured values. The topology of the protection data communication system is
constituted by the allocation of devices to the ends of the protected object and by the allocation of communi-
cation paths to the protection data interfaces of the devices.
Functional Description
Protection Data Topology
For a standard layout of lines with two ends, you require one protection data interface for each device. The
protection data interface is named PDI 1 (see also Figure 2-49). The corresponding protection data interface
must be configured as Enabled during configuring the scope of functions (see Section 2.1.1 Functional
Scope). Additionally the indices for the devices have to be assigned (see also Section 2.4.2 Setting Notes at
margín heading “Protection Data Topology”).
Using two 7SA522 relays you can connect both protection data interfaces with each other provided that the
two devices are equipped with two protection data interfaces each and the necessary means for transmission
are available. This results in 100% redundancy as of the transmission (Figure 2-50). The devices autonomously
search for the fastest communication link. If this link is faulty, the devices automatically switch over to the
other link which is then used until the faster one is healthy again.
[dis-fuer-2-enden-mit-2-7sa6-mit-je-1-ws-sender-empf-wlk-290702, 1, en_GB]
Figure 2-49 Distance protection for two ends with two 7SA6 devices with one protection data interface
each (transmitter/ receiver)
[dis2endenmit2-7sa522je2ws-240402wlk, 1, en_GB]
Figure 2-50 Distance protection for two ends with two 7SA522 devices with one protection data interface
each (transmitter/ receiver)
Using three ends, at least one 7SA522 device with two protection data interfaces is required. Thus a communi-
cation chain can be formed. The number of devices (address 147 NUMBER OF RELAY) must correspond to
the number of ends of the protected object. Please observe that only current transformer sets that limit the
protected object are counted. The line in Figure 2-51, for instance, has three ends and three devices because
it is limited by three current transformer sets.
Using three ends, at least one 7SA522 device with two protection data interfaces is required. Thus a communi-
cation chain can be formed. The number of devices (address 147 NUMBER OF RELAY) must correspond to
2.4
2.4.1
Functions
2.4 Protection data interfaces and communication topology (optional)
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the number of ends of the protected object. Please observe that only current transformer sets that limit the
protected object are counted. The line in Figure 2-51, for instance, has three ends and three devices because
it is limited by three current transformer sets.
[dis-fuer-3-enden-mit-2-7sa6-mit-1-7sa522-kette-wlk-290702, 1, en_GB]
Figure 2-51 Distance protection for three ends with 3 7SA522, chain topology
Communication Media
The communication can be carried out directly via fiber optic connections or via communication networks.
Which kind of media is used depends on the distance and on the communication media available. For shorter
distances, a direct connection via fiber optic cables with a transmission rate of 512 kBit/s is possible. Other-
wise, we recommend communication converters. A transmission via copper cables and communication
networks can also be realized. Please take into consideration that the responding times of the protection data
communication depend on the quality of transmission and that they are prolonged in case of a reduced trans-
mission quality and/or an increased operating time.
Figure 2-52 shows some examples for communication connections. In case of a direct connection the distance
depends on the type of the optical fibre. The connection options are given in the Technical Data (see Chapter
4 Technical Data “Connection modules for protection data interface”. The modules in the device are replace-
able. For ordering information see Appendix, under “Ordering Information and Accessories”.
If a communication converter is used, the device and the communication converter are linked with an FO5
module via optical fibres. The converter itself is available in different versions allowing to connect it to
communication networks (X.21, G703 64 kBit, G703 E1/T1) or connection via two-wire copper lines. Use the
FO30 module to connect the device to the communication networks via IEEE C37.94. For the ordering infor-
mation, please refer to the Appendix under “Ordering Information and Accessories”.
i
i
NOTE
If the protection data interfaces of the devices are connected via a communication network, a circuit
switched network, e.g. a SDH and/or PDH-network is required. Packet switched networks, e.g. IP-Networks,
are not suitable for protection data interface communication. Networks of this type do not have determin-
istic channel delays as the symmetrical and asymmetrical channel delays vary too much from one telegram
to the next. As a result it is not possible to obtain a definite tripping time.
Functions
2.4 Protection data interfaces and communication topology (optional)
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[bsp-kom-verbin-180510-wlk, 1, en_GB]
Figure 2-52 Examples for communication connections
i
i
NOTE
The redundancy of different communication connections (for ring topology) requires a consistent separa-
tion of the devices connected to the communication network. For example, different communication
routes should not be conducted via the same multiplexer card, as there is no alternative which could be
used if the multiplexer card fails.
Functional Logout
In an overall topology up to 3 devices that use teleprotection, it is possible to take out one device, e.g. for
maintenance purposes, from the protection function “Teleprotection” without having to re-parameterize the
device. A logged out device (in the Functional Logout) no longer participates in the teleprotection, but still
sends and receives remote indications and commands (see Section 2.4.2 Setting Notes under “Communication
Topology”).
Disturbance and Transmission Failure
The communication is continuously monitored by the devices. Single faulty data telegrams are not a direct risk
if they occur only occasionally. They are recognized and counted in the device which detects the disturbance
and can be read out as statistical information.
If several faulty telegrams or no data telegrams are received, this is regarded as a communication disturbance
when a time delay for data disturbance alarm (default setting 100 ms, can be altered) is exceeded. A corre-
sponding alarm is output. When the system offers no alternative way of communication (as for the ring
topology), the teleprotection scheme is disabled. As soon as the data transmission operates properly again,
the devices will automatically switch back to the teleprotection scheme.
Functions
2.4 Protection data interfaces and communication topology (optional)
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Transmission time jumps that, for example, can occur in case of switchings in the communication network can
be recognized and corrected by the device. After at most 2 seconds the transmission times are measured
again.
If the communication is interrupted permanently (i.e. longer than a settable time), this is considered to be a
communicationfailure. A corresponding alarm is output. Otherwise the same reactions apply as for the
disturbance.
Setting Notes
General
Protection data interfaces connect the devices with the communication media. The communication is perma-
nently monitored by the devices. Address 4509 T-DATA DISTURB defines after which delay time the user is
informed about a faulty or missing telegram. Address 4510 T-DATAFAIL is used to set the time after which a
transmission failure alarm is output.
Protection Data Interface
At address 4501 STATE PROT I 1, the protection data interface can be switched ON or OFF. If it is switched
OFF, this corresponds to a transmission failure. In case of a ring topology, the transmission of data can
continue its operation, but not in case of a chain topology..
At address 4502 CONNEC. 1 OVER you can select the transmission medium which to connect to protection
data interface 1. The following selection is possible:
F.optic direct, i.e. direct communication via fibre-optic cable with 512 kBit/s,
Com c 64 kBit/s, i.e. via communication converters with 64 kBit/s (G703.1 or X.21),
Com c 128kBit/s, i.e. via communication converters with 128 kBit/s (X.21, copper cable),
Com c 512kBit/s, i.e. via communication converter 512 kbit/s (X.21),
IEEE C37.94, i.e. communication network connection with 1, 2, 4 or 8 slots.
The possibilities may vary for the different device versions. The data must be identical at both ends of a
communication route.
The devices measure and monitor the transmission times. Deviations are corrected, as long as they are within
the permissible range. These permissible ranges are set at address 4505 and 4605 and can generally be left at
their default values.
The maximum permissible signalling time (address 4505 PROT 1 T-DELAY) is set by default to a value that
does not exceed the usual value of communication media. This parameter can only be changed in DIGSI at
Display Additional Settings. If it is exceeded during operation (e.g. because of switchover to a different trans-
mission path), the message
PI1 TD alarm
will be issued. Once a fault has been detected in the communica-
tion of the protection data interface, the time at address 4511 Td ResetRemote is started for resetting the
remote signals. Please note that only the time of the device whose remote end has failed is considered. Thus
the same time is valid for all devices following in a chain.
Protection Data Interface 2
If protection data interface 2 exists and is used, the same options apply as for protection data interface 1. The
corresponding parameters are located under addresses 4601 STATE PROT I 2 (ON or OFF), 4602 CONNEC.
2 OVER and 4605 PROT 2 T-DELAY. The last parameter can only be modified with DIGSI under Additional
Settings.
Protection Data Topology
First, define your communication topology: Number the devices consecutively. This numbering is a serial
device index that serves for your overview. It starts for each distance protection system (i.e. for each protected
object) with 1. For the distance protection system the device with index 1 is always the absolute-time master,
i.e. the absolute time management of all devices which belong together depends on the absolute time
management of this device. As a result, the time information of all devices is comparable at all times. The
device index serves to clearly define the devices within the distance protection system (i.e. for one protected
object).
2.4.2
Functions
2.4 Protection data interfaces and communication topology (optional)
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An ID number is also to be given to each single device (device-ID). The device–ID is used by the communica-
tion system to identify each individual device. It must be between 1 and 65534 and must be unique within the
communication system. The ID number identifies the devices in the communication system since the
exchange of information between several distance protection systems (thus also for several protected objects)
can be executed via the same communication system.
Please make sure that the possible communication links and the existing interfaces are in accordance with
each other. If not all devices are equipped with two protection data interfaces, those with only one protection
data interface must be located at the ends of the communication chain.
A ring topology is only possible if all devices in a distance protection system are equipped withtwo protection
data interfaces.
If you use different physical interfaces and/or communication links, please make sure that each protection
data interface is compatible with the intended communication link.
For a protected object with two ends (e.g. a line) the addresses 4701 ID OF RELAY 1 and 4702 ID OF
RELAY 2 are set, e.g. for device 1 the device-ID 1 and for device 2 the device-ID 2 (Figure 2-53). The indices
of the devices and the device-IDs do not have to match here, as mentioned above.
[distanztop-2-end-2-geraet-wlk-090802, 1, en_GB]
Figure 2-53 Distance protection topology for 2 ends with 2 devices - example
For a protected object with more than two ends (and corresponding devices), the third end is allocated to its
device ID at parameter address 4703 ID OF RELAY 3. A maximum of 3 line ends is possible with 3 devices.
Figure 2-54 gives an example with 3 relays. During the configuration of the protection functions the number
of devices required for the relevant application was set in address 147 NUMBER OF RELAY. Device IDs can be
entered for as many devices as were configured under that address, no further IDs are offered during setting.
Functions
2.4 Protection data interfaces and communication topology (optional)
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[distanztop-3-end-3-geraet-wlk-090802, 1, en_GB]
Figure 2-54 Distance protection topology for 3 ends with 3 devices - example
In address 4710 LOCAL RELAY you finally indicate the actual local device. Enter the index for each device
(according to the consecutive numbering used). Each index from 1 to the entire number of devices must be
used once, but may not be used twice.
Make sure that the parameters of the distance protection topology for the distance protection system are
conclusive:
•Each device index can only be used once;
•Each device index must be allocated unambiguously to one device ID;
•Each device-index must be the index of a local device once;
•The device with index 1 is the source for the absolute time management (absolute time master).
During startup of the protection system, the above listed conditions are checked. If one out of these condi-
tions is not fulfilled, no protection data can be transmitted. The device signals
DT inconsistent
(“Device
table inconsistent”).
Device Logout
A device can be removed from the topology via the receive signal 3484
Logout
so that the remaining relays
can still assume their protection function.
If a device logs out functionally, the number of active protection devices is reduced. In this case, the telepro-
tection schemes are automatically switched from 3 to 2 ends. If no remote end is available,
Dis.T.Carr.Fail
is signalled.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
4501 STATE PROT I 1 ON
OFF
ON State of protection interface 1
2.4.3
Functions
2.4 Protection data interfaces and communication topology (optional)
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Addr. Parameter Setting Options Default Setting Comments
4502 CONNEC. 1 OVER F.optic direct
Com c 64 kBit/s
Com c 128kBit/s
Com c 512kBit/s
C37.94 1 slot
C37.94 2 slots
C37.94 4 slots
C37.94 8 slots
F.optic direct Connection 1 over
4505A PROT 1 T-DELAY 0.1 .. 30.0 ms 30.0 ms Prot 1: Maximal permissible delay
time
4509 T-DATA DISTURB 0.05 .. 2.00 sec 0.10 sec Time delay for data disturbance
alarm
4510 T-DATAFAIL 0.0 .. 60.0 sec 6.0 sec Time del for transmission failure
alarm
4511 Td ResetRemote 0.00 .. 300.00 sec; ∞ 0.00 sec Remote signal RESET DELAY for
comm.fail
4601 STATE PROT I 2 ON
OFF
ON State of protection interface 2
4602 CONNEC. 2 OVER F.optic direct
Com c 64 kBit/s
Com c 128kBit/s
Com c 512kBit/s
C37.94 1 slot
C37.94 2 slots
C37.94 4 slots
C37.94 8 slots
F.optic direct Connection 2 over
4605A PROT 2 T-DELAY 0.1 .. 30.0 ms 30.0 ms Prot 2: Maximal permissible delay
time
4701 ID OF RELAY 1 1 .. 65534 1 Identification number of relay 1
4702 ID OF RELAY 2 1 .. 65534 2 Identification number of relay 2
4703 ID OF RELAY 3 1 .. 65534 3 Identification number of relay 3
4710 LOCAL RELAY relay 1
relay 2
relay 3
relay 1 Local relay is
Information List
No. Information Type of
Informa-
tion
Comments
3196 local Teststate IntSP Local relay in Teststate
3215 Wrong Firmware OUT Incompatible Firmware Versions
3217 PI1 Data reflec OUT Prot Int 1: Own Datas received
3218 PI2 Data reflec OUT Prot Int 2: Own Datas received
3227 >PI1 light off SP >Prot Int 1: Transmitter is switched off
3228 >PI2 light off SP >Prot Int 2: Transmitter is switched off
3229 PI1 Data fault OUT Prot Int 1: Reception of faulty data
3230 PI1 Datafailure OUT Prot Int 1: Total receiption failure
2.4.4
Functions
2.4 Protection data interfaces and communication topology (optional)
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No. Information Type of
Informa-
tion
Comments
3231 PI2 Data fault OUT Prot Int 2: Reception of faulty data
3232 PI2 Datafailure OUT Prot Int 2: Total receiption failure
3233 DT inconsistent OUT Device table has inconsistent numbers
3234 DT unequal OUT Device tables are unequal
3235 Par. different OUT Differences between common parameters
3236 PI1<->PI2 error OUT Different PI for transmit and receive
3239 PI1 TD alarm OUT Prot Int 1: Transmission delay too high
3240 PI2 TD alarm OUT Prot Int 2: Transmission delay too high
3243 PI1 with VI Prot Int 1: Connected with relay ID
3244 PI2 with VI Prot Int 2: Connected with relay ID
3274 PI1: C37.94 n/a OUT PI1: IEEE C37.94 not supported by module
3275 PI2: C37.94 n/a OUT PI2: IEEE C37.94 not supported by module
3457 Ringtopology OUT System operates in a closed Ringtopology
3458 Chaintopology OUT System operates in a open Chaintopology
3464 Topol complete OUT Communication topology is complete
3475 Rel1Logout IntSP Relay 1 in Logout state
3476 Rel2Logout IntSP Relay 2 in Logout state
3477 Rel3Logout IntSP Relay 3 in Logout state
3484 Logout IntSP Local activation of Logout state
3487 Equal IDs OUT Equal IDs in constellation
3491 Rel1 Login OUT Relay 1 in Login state
3492 Rel2 Login OUT Relay 2 in Login state
3493 Rel3 Login OUT Relay 3 in Login state
Functions
2.4 Protection data interfaces and communication topology (optional)
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Remote signals via protection data interface (optional)
Functional Description
Provided that the devices work with protection data transmission via digital communication links at the ends,
the transmission of up to 28 items of binary information of any type from one device to the other is possible.
Four of 28 information items are transmitted like protection signals with high priority, i.e. very fast, and are
therefore especially suitable for the transmission of other protection signals which are generated outside of
7SA522. The other 24 are transmitted in the back-ground and are therefore suitable for any information that
does not depend on high-speed transmission, such as information on the events taking place in a substation
which may also be useful in other substations.
The information enters the device via binary inputs and can leave it again at the other ends via binary outputs.
The integrated user-defined CFC logic allows the signals to be linked logically with one another or with other
information items of the device's protection and monitoring functions.
The binary outputs and the binary inputs to be used must be allocated appropriately during the configuration
of the input and output functions (see SIPROTEC 4 System Description ). The four high-priority signals enter
into the device via the binary inputs
>Remote CMD 1
to
>Remote CMD 4
. They are then transmitted to the
devices at the other ends and can be processed on each receiving side with the output functions
Remote
CMD1 rec
to
Remote CMD4 rec
.
If the remote commands are to be used for direct remote tripping, they must be allocated at the send side via
CFC with the function that is to perform the transfer trip at the opposite side, and at the receiving side, also via
CFC, with the “>Ext. TRIP ...” input signals.
The other 24 items of information reach the device via the binary inputs
>Rem. Signal 1
to
>Rem.Signal24
and are available under
Rem.Sig 1recv
etc. at the receiving side.
No settings are required for the transmission of binary information. Each device sends the injected informa-
tion to all other devices at the ends of the protected object, even if the topology is incomplete. Where selec-
tion is necessary, it will have to be carried out by appropriate allocation and by a link at the receiving side.
Even devices that have logged out functionally (Functional Logout) can send and receive remote signals and
commands.
The annunciations Dev x available of the topology detection function can be used to determine whether the
signals of the sending devices are still available. They are issued if device x is actively involved in the commu-
nication topology and this state is stable.
Once a fault has been detected in the communication of the protection data interface, the time at address
4511 Td ResetRemote is started for resetting the remote signals.
Information List
No. Information Type of
Informa-
tion
Comments
3541 >Remote CMD 1 SP >Remote Command 1 signal input
3542 >Remote CMD 2 SP >Remote Command 2 signal input
3543 >Remote CMD 3 SP >Remote Command 3 signal input
3544 >Remote CMD 4 SP >Remote Command 4 signal input
3545 Remote CMD1 rec OUT Remote Command 1 received
3546 Remote CMD2 rec OUT Remote Command 2 received
3547 Remote CMD3 rec OUT Remote Command 3 received
3548 Remote CMD4 rec OUT Remote Command 4 received
3549 >Rem. Signal 1 SP >Remote Signal 1 input
3550 >Rem.Signal 2 SP >Remote Signal 2 input
3551 >Rem.Signal 3 SP >Remote Signal 3 input
2.5
2.5.1
2.5.2
Functions
2.5 Remote signals via protection data interface (optional)
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No. Information Type of
Informa-
tion
Comments
3552 >Rem.Signal 4 SP >Remote Signal 4 input
3553 >Rem.Signal 5 SP >Remote Signal 5 input
3554 >Rem.Signal 6 SP >Remote Signal 6 input
3555 >Rem.Signal 7 SP >Remote Signal 7 input
3556 >Rem.Signal 8 SP >Remote Signal 8 input
3557 >Rem.Signal 9 SP >Remote Signal 9 input
3558 >Rem.Signal10 SP >Remote Signal 10 input
3559 >Rem.Signal11 SP >Remote Signal 11 input
3560 >Rem.Signal12 SP >Remote Signal 12 input
3561 >Rem.Signal13 SP >Remote Signal 13 input
3562 >Rem.Signal14 SP >Remote Signal 14 input
3563 >Rem.Signal15 SP >Remote Signal 15 input
3564 >Rem.Signal16 SP >Remote Signal 16 input
3565 >Rem.Signal17 SP >Remote Signal 17 input
3566 >Rem.Signal18 SP >Remote Signal 18 input
3567 >Rem.Signal19 SP >Remote Signal 19 input
3568 >Rem.Signal20 SP >Remote Signal 20 input
3569 >Rem.Signal21 SP >Remote Signal 21 input
3570 >Rem.Signal22 SP >Remote Signal 22 input
3571 >Rem.Signal23 SP >Remote Signal 23 input
3572 >Rem.Signal24 SP >Remote Signal 24 input
3573 Rem.Sig 1recv OUT Remote signal 1 received
3574 Rem.Sig 2recv OUT Remote signal 2 received
3575 Rem.Sig 3recv OUT Remote signal 3 received
3576 Rem.Sig 4recv OUT Remote signal 4 received
3577 Rem.Sig 5recv OUT Remote signal 5 received
3578 Rem.Sig 6recv OUT Remote signal 6 received
3579 Rem.Sig 7recv OUT Remote signal 7 received
3580 Rem.Sig 8recv OUT Remote signal 8 received
3581 Rem.Sig 9recv OUT Remote signal 9 received
3582 Rem.Sig10recv OUT Remote signal 10 received
3583 Rem.Sig11recv OUT Remote signal 11 received
3584 Rem.Sig12recv OUT Remote signal 12 received
3585 Rem.Sig13recv OUT Remote signal 13 received
3586 Rem.Sig14recv OUT Remote signal 14 received
3587 Rem.Sig15recv OUT Remote signal 15 received
3588 Rem.Sig16recv OUT Remote signal 16 received
3589 Rem.Sig17recv OUT Remote signal 17 received
3590 Rem.Sig18recv OUT Remote signal 18 received
3591 Rem.Sig19recv OUT Remote signal 19 received
3592 Rem.Sig20recv OUT Remote signal 20 received
3593 Rem.Sig21recv OUT Remote signal 21 received
3594 Rem.Sig22recv OUT Remote signal 22 received
3595 Rem.Sig23recv OUT Remote signal 23 received
3596 Rem.Sig24recv OUT Remote signal 24 received
Functions
2.5 Remote signals via protection data interface (optional)
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Teleprotection for distance protection
General
Purpose of Teleprotection
Faults which occur on the protected line, beyond the first distance zone, can only be cleared selectively by the
distance protection after a delay time. On line sections that are shorter than the smallest sensible distance
setting, faults can also not be selectively cleared instantaneously.
To achieve non-delayed and selective tripping on 100 % of the line length for all faults by the distance protec-
tion, the distance protection can exchange and process information with the opposite line end by means of
teleprotection schemes. This can be done in a conventional way using send and receive contacts.
Um trotzdem bei allen Fehlern auf 100 % der Leitungsstrecke eine unverzögerte und selektive Abschaltung
durch den Distanzschutz zu erreichen, kann der Distanzschutz durch Signalübertragungsverfahren Informa-
tionen mit der Gegenstation austauschen und sie weiterverwenden. Dies kann über die konventionellen Wege
mittels Empfangs- und Sendekontakte realisiert werden.
As an alternative, digital communication lines can be used for signal transmission (ordering option).
Teleprotection Schemes
A distinction is made between underreach and overreach schemes.
In underreach schemes, the protection is set with a normal grading characteristic. If a trip command occurs in
the first zone, the other line end receives this information via a transmission channel. There the received
signal initates a trip, either by activation of overreach zone Z1B or via a direct trip command.
7SA522 allows:
•Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT),
•Direct (Underreach) Transfer Trip
In overreach schemes, the protection works from the start with a fast overreaching zone. This zone, however,
can only cause a trip if the opposite end also detects a fault in the overreaching zone. A release (unblock)
signal or a block signal can be transmitted. The following teleprotection schemes are differentiated:
Permissive (release) schemes:
•Permissive Overreach Transfer Trip (POTT) with overreaching zone Z1B
•Unblocking with overreaching zone Z1B.
Blocking scheme:
•Blocking of overreaching zone Z1B.
Since the distance zones function independently, an instantaneous trip in Z1 without a release or blocking
signal is always possible. If fast tripping in Z1 is not required (e.g. on very short lines), then Z1 must be
delayed with T1.
Transmission channels
If the device is equipped with an optional protection data interface, digital communication lines can be used
for signal transmission which include: e.g.: Fibre optic cables, communication networks or dedicated cables.
The following signal transmission schemes are suited for these kinds of transmission:
•Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT),
•Permissive Overreach Transfer Trip (POTT) (with overreaching zone Z1B).
7SA522 allows also the transmission of phase-selective signals. This has the advantage that reliable single-
pole automatic reclosure can be carried out even when two single-phase faults occur on different lines in the
system. Where the digital protection data interface is used, the signal transmission is always phase segre-
gated.
2.6
2.6.1
Functions
2.6 Teleprotection for distance protection
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The signal transmission schemes are also suited to three terminal lines (teed feeders). In this case, a signal is
transmitted from each of the three ends to each of the others in both directions. Phase segregated transmis-
sion is only possible for three terminal line applications if digital communication channels are used.
During disturbances in the transmission path, the teleprotection supplement may be blocked without
affecting the normal time graded distance protection. The measuring reach control (enable zone Z1B) can be
transmitted from the internal automatic reclose function or via the binary input
>Enable ARzones
from an
external reclosure device. With conventional signal transmission schemes, the disturbance is signalled by a
binary input, with digital communication it is detected automatically by the protection device.
Functional Description
Activation and Deactivation
The teleprotection function can be switched on and off by means of the parameter 2101 FCT Telep. Dis.,
or via the system interface (if available) and via binary input (if this is allocated). The switched state is saved
internally (refer to Figure 2-55) and secured against loss of auxiliary supply. It is only possible to switch on
from the source where previously it had been switched off from. To be active, it is necessary that the function
is not switched off from one of the three switching sources.
[ein-und-ausschalten-signaluebertragung-wlk-290702, 1, en_GB]
Figure 2-55 Activation and deactivation of teleprotection
Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT)
The following procedure is suited for both conventional and digital transmission media.
Principle
Figure 2-56 shows the operation scheme for the permissive underreach transfer trip with zone acceleration. In
case of a fault inside zone Z1, the transfer trip signal is sent to the opposite line end. The signal received there
causes tripping if the fault is detected in the preset direction inside zone Z1B. The transmit signal can be
prolonged by TS (settable at address 2103 Send Prolong.) to compensate for possible differences in the
pickup times at the two line ends. The distance protection is set in such a way that the first zone reaches up to
approximately 85% of the line length, the overreaching zone, however, is set to reach beyond the next station
(approximately 120% of the line length). On three terminal lines Z1 is also set to approximately 85% of the
shorter line section, but at least beyond the tee-off point. It has to be observed that Z1 does not reach beyond
one of the two other line ends. Z1B must securely reach beyond the longer line section, even when additional
infeed is possible via the tee point.
For this procedure, transmission via a protection data interface (if provided) is offered.
In protection relays equipped with a protection data interface, address 121 Teleprot. Dist. allows to set
SIGNALv.ProtInt. At address 2101 FCT Telep. Dis. the PUTT (Z1B) scheme can be selected.
2.6.2
2.6.3
Functions
2.6 Teleprotection for distance protection
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[funktionsschema-des-mitnahmeverfahrens-ueber-z1b-wlk-290702, 1, en_GB]
Figure 2-56 Operation scheme of the permissive underreach transfer trip method via Z1B
Sequence
The permissive transfer trip only works for faults in the “Forward” direction. Accordingly, the first zone Z1 and
the overreaching zone of the distance protection must definitely be set to Forward in address 1301 Op.
mode Z1 and 1351 Op. mode Z1B, refer also to Section 2.2.2 Distance protection with quadrilateral charac-
teristic (optional) under the margin heading “Independent Zones Z1 up to Z6” and “Controlled Zone Z1B”).
Functions
2.6 Teleprotection for distance protection
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[logikdia-der-mitnahme-ueber-z1b-ein-leitungsende-konv-skg, 1, en_GB]
Figure 2-57 Logic diagram of the permissive underreach transfer trip (PUTT) using Z1B (one line end,
conventional, no protection data interface)
Functions
2.6 Teleprotection for distance protection
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[logikdia-der-mitnahme-ueber-z1b-ein-leitungsende-mit-ws-skg, 1, en_GB]
Figure 2-58 Logic diagram of the permissive underreach transfer trip (PUTT) using Z1B (one line end, with
protection data interface)
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signals are sent to both opposite line
ends. The receive signals are then combined with an OR logic function. If the parameter Teleprot. Dist.
(address 121) is set to SIGNALv.ProtInt and parameter NUMBER OF RELAY (address 147) is set to 3
relays, the device is informed about two remote ends. The default setting is 2 relays, which corresponds
Functions
2.6 Teleprotection for distance protection
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to one remote end. If digital protection transmission is applied and the protection data interface is used,
signals will always be transmitted phase-selectively.
If conventional transmission is used, the parameter Type of Line (address 2102) informs the device
whether it has one or two opposite line ends.
During disturbance of the signal transmission path, the overreaching zone Z1B may be activated by an auto-
matic reclosure by setting parameter 1st AR -> Z1B, and by an external recloser device via the binary input
>Enable ARzones
.
If the parameter Mem.rec.sig. (address 2113) is set to YES and an own distance protection pickup is avail-
able in Z1B, the phase-selective release effected via the signal extension is stored. If the own distance protec-
tion pickup in Z1B drops out, it will be deleted.
If at one line end there is weak or zero infeed, so that the distance protection does not pick up, the circuit
breaker can still be tripped. This “Weak-infeed tripping” is described in Section 2.9.2 Classical Tripping.
Direct Underreach Transfer Trip
The following scheme is suited for conventional transmission media.
Principle
As is the case with PUTT (pickup) or PUTT with zone acceleration, a fault in the first zone Z1 is transmitted to
the opposite line end by means of a transfer trip signal. The signal received there causes a trip without further
queries after a short security margin Tv (settable in address 2202 Trip Time DELAY) (Figure 2-59). The
transmit signal can be prolonged by TS (settable in address 2103 Send Prolong.), to compensate for
possible differences in the pickup time at the two line ends. The distance protection is set such that the first
zone reaches up to approximately 85% of the line length. On three terminal lines Z1 is also set to approxi-
mately 85 % of the shorter line section, but at least beyond the tee-off point. Care must be taken to ensure
that Z1 does not reach beyond one of the two other line ends. The overreaching zone Z1B is not required
here. It may, however, be activated by internal automatic reclosure or external criteria via the binary input
>Enable ARzones
.
The advantage compared to the other permissive underreach transfer trip schemes lies in the fact that both
line ends are tripped without the necessity for any further measures, even if one line end has no infeed. There
is however no further supervision of the trip signal at the receiving end.
The direct underreach transfer trip application is not provided by its own selectable teleprotection scheme
setting, but implemented by setting the teleprotection supplement to operate in the permissive underreach
transfer trip scheme (address 121 Teleprot. Dist. = PUTT (Z1B)), and using the binary inputs for direct
external trip at the receiving end. Correspondingly, the transmit circuit in Section “The principle of PUTT”
(2.10 External direct and remote tripping) applies. For the receive circuit the logic of the „external trip“ as
described in Section 2.10 External direct and remote tripping applies.
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signals are sent to both opposite line
ends. The receive signals are then combined with a logical OR function.
2.6.4
Functions
2.6 Teleprotection for distance protection
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[funktionsschema-direkten-mitnahme-wlk-290702, 1, en_GB]
Figure 2-59 Function diagram of the direct underreach transfer trip scheme
Permissive Overreach Transfer Trip (POTT)
The following procedure is suited for both conventional and digital transmission media.
Principle
The permissive overreach transfer mode uses a permissive release principle. The overreaching zone Z1B, set
beyond the opposite station, is decisive. This mode can also be used on extremely short lines where a setting
of 85% of line length for zone Z1 is not possible and accordingly selective non-delayed tripping could not be
achieved. In this case however zone Z1 must be delayed by T1, to avoid non selective tripping by zone Z1
(Figure 2-60).
If the distance protection recognizes a fault inside the overreaching zone Z1B, it initially sends a release signal
to the opposite line end. If a release signal is also received from the opposite end, the trip signal is forwarded
to the command relay. A prerequisite for fast tripping is therefore that the fault is recognised inside Z1B in
forward direction at both line ends. The distance protection is set in such a way that overreaching zone Z1B
reaches beyond the next station (approximately 120% of the line length). On three terminal lines, Z1B must be
set to reliably reach beyond the longer line section, even if there is an additional infeed via the tee point. The
first zone is set in accordance with the usual grading scheme, i.e. approximately 85% of the line length; on
three terminal lines at least beyond the tee point.
The transmit signal can be prolonged by TS (settable under address 2103 Send Prolong.). The prolongation
of the send signal only comes into effect if the protection has already issued a trip command. This ensures
release of the opposite line end even when the short-circuit has been switched off rapidly by the independent
zone Z1.
For all zones except Z1B, tripping results without release from the opposite line end, allowing the protection
to function with the usual grading characteristic independent of the signal transmission.
For this procedure, transmission via a protection data interface (if provided) is offered.
In protection relays equipped with a protection data interface, address 121 Teleprot. Dist. allows to set
SIGNALv.ProtInt. At address 2101 FCT Telep. Dis. the POTT scheme can be selected.
2.6.5
Functions
2.6 Teleprotection for distance protection
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[funktionsschema-des-signalvergleichsverfahrens-wlk-290702, 1, en_GB]
Figure 2-60 Function diagram of the permissive overreach transfer trip method
Sequence
The permissive overreach transfer trip only functions for faults in the “Forward” direction. Accordingly, the first
overreach zone ZB1of the distance protection must definitely be set to Forward in addresses 1351 Op.
mode Z1B, refer also to Section 2.2.2 Distance protection with quadrilateral characteristic (optional) under
the margin heading “Controlled Zone ZB1”.
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signal is sent to both opposite line
ends. The receive signals are then combined with a logical AND gate, as all three line ends must transmit a
send signal during an internal fault.
If the parameter Teleprot. Dist. (address 121) is set to SIGNALv.ProtInt and parameter NUMBER OF
RELAY (address 147) is set to 3 relays, the device is informed about two remote ends. The default setting is
2 relays, which corresponds to one remote end. In protection relays equipped with one protection data
interface, signal transmission is always phase segregated (Figure 2-62).
If conventional transmission is used, parameter Type of Line (address 2102) informs the device whether it
has one or two opposite line ends (Figure 2-61).
During disturbance of the signal transmission path, the overreaching zone Z1B may be activated by an auto-
matic reclosure by setting parameter 1st AR -> Z1B, and by an external recloser device via the binary input
>Enable ARzones
.
During disturbance of the signal transmission path, the overreaching zone Z1B may be activated by an auto-
matic reclosure by setting parameter 1st AR -> Z1B, and by an external recloser device via the binary input
>Enable ARzones
.
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2.6 Teleprotection for distance protection
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[logikdia-signalvergleichsverfahrens-ein-ltgsend-konv-240402-wlk, 2, en_GB]
Figure 2-61 Logic diagram of the permissive overreach transfer trip (POTT) scheme (one line end, conven-
tional, no protection data interface))
Functions
2.6 Teleprotection for distance protection
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[logikdia-signalvergleichsverfahrens-ein-leitungsende-240402-wlk, 1, en_GB]
Figure 2-62 Logic diagram of the permissive overreach transfer trip (POTT) scheme (one line end, with
protection data interface)
Unblocking Scheme
The following scheme is suited for conventional transmission media.
2.6.6
Functions
2.6 Teleprotection for distance protection
126 SIPROTEC 4, 7SA522, Manual
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Principle
The unblocking method is a permissive release scheme. It differs from the permissive overreach transfer
scheme in that tripping is possible also when no release signal is received from the opposite line end. It is
therefore mainly used for long lines when the signal must be transmitted across the protected line by means
of power line carrier (PLC) and the attenuation of the transmitted signal at the fault location may be so severe
that reception at the other line end cannot necessarily be guaranteed. Here, a special unblocking logic takes
effect.
The function scheme is shown in Figure 2-63.
Two signal frequencies which are keyed by the transmit output of the 7SA522 are required for the transmis-
sion. If the transmission device has a channel monitoring, then the monitoring frequency f0 is keyed over to
the working frequency fU (unblocking frequency). When the protection recognizes a fault inside the over-
reaching zone Z1B, it initiates the transmission of the unblock frequency fU. During the quiescent state or
during a fault outside Z1B, or in the reverse direction, the monitoring frequency f0 is transmitted.
If a release signal is also received from the opposite end, the trip signal is forwarded to the command relay.
Accordingly, it is a prerequisite for fast tripping that the fault is recognised inside Z1B in forward direction at
both line ends. The distance protection is set in such a way that overreaching zone Z1B reaches beyond the
next station (approximately 120% of the line length). On three terminal lines, Z1B must be set to reliably reach
beyond the longer line section, even if there is an additional infeed via the tee point. The first zone is set in
accordance with the usual grading scheme, i.e. approximately 85% of the line length; on three terminal lines
at least beyond the tee point.
The transmit signal can be prolonged by TS (settable under address 2103 Send Prolong.). The prolongation
of the send signal only comes into effect if the protection has already issued a trip command. This ensures
release of the opposite line end even when the short-circuit has been switched off rapidly by the independent
zone Z1.
[funktionsschema-des-unblockverfahrens-wlk-300702, 1, en_GB]
Figure 2-63 Function diagram of the directional unblocking method
For all zones except Z1B, tripping without release from remote end is initiated, allowing the protection to
function with the usual grading characteristic independent of the signal transmission.
Sequence
Figure 2-64 shows the logic diagram of the unblocking scheme for one line end.
Functions
2.6 Teleprotection for distance protection
SIPROTEC 4, 7SA522, Manual 127
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The unblock scheme only functions for faults in the “forward” direction. Accordingly, the overreaching zone
Z1B of the distance protection must definitely be set to Forward: in Address 1351 Op. mode Z1B, see also
Subsection 2.2.1 Distance protection, general settings at margin heading “Controlled Zone Z1B”.
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines the send signal is transmitted to both opposite
ends. The receive signals are then combined with a logical AND gate, as all three line ends must transmit a
send signal during an internal fault. With the parameter Type of Line (address2102) the device is informed
as to whether it has one or two opposite line ends.
An unblock logic is inserted before the receive logic, which in essence corresponds to that of the permissive
overreach transfer scheme, see Figure 2-65. If an interference free unblock signal is received, a receive signal,
e.g.
>Dis.T.UB ub 1
, appears and the blocking signal, e.g.
>Dis.T.UB bl 1
disappears. The internal
signal “Unblock 1” is passed on to the receive logic, where it initiates the release of the overreaching zone Z1B
of the distance protection (when all remaining conditions have been fulfilled).
If the transmitted signal does not reach the other line end because the short-circuit on the protected feeder
causes too much attenuation or reflection of the transmitted signal, neither the unblocking signal e.g.,
>Dis.T.UB ub 1
, nor the blocking signal >Dis.T.UB bl 1 will appear on the receiving side. In this case, the
release “Unblock 1” is issued after a security delay time of 20 ms and passed onto the receive logic. This
release is however removed after a further 100 ms via the timer stage 100/100 ms. When the transmission is
functional again, one of the two receive signals must appear again, either
>Dis.T.UB ub 1
or
>Dis.T.UB
bl 1
; after a further 100 ms (drop-off delay of the timer stage 100/100 ms) the quiescent state is reached
again, i.e. the direct release path to the signal “Unblock L1” and thereby the usual release is possible.
If none of the signals is received for a period of more than 10 s the alarm
Dis.T.UB Fail1
is generated.
During disturbance of the signal transmission path, the overreaching zone Z1B may be activated by an auto-
matic reclosure (internal or external) via the binary input
>Enable ARzones
.
The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc-
tion reversal resulting during the clearance of faults on parallel lines, is neutralized by the “Transient Blocking”.
On feeders with single-sided infeed, the line end with no infeed cannot generate a release signal, as no fault
detection occurs there. To achieve tripping by the directional unblocking scheme also in this case, the device
features a special function. This “Weak Infeed Function” (echo function) is described in Section “Measures for
Weak and Zero Infeed”. It is activated when a signal is received from the opposite line end — in the case of
three terminal lines from at least one of the opposite line ends — without the device having detected a fault.
The circuit breaker can also be tripped at the line end with no or only weak infeed. This „weak-infeed trip-
ping“ is described in Section 2.9.2 Classical Tripping.
If the parameter Mem.rec.sig. (address 2113) is set to YES and an own distance protection pickup is avail-
able in Z1B, the phase-selective release effected via the signal extension is stored. If the own distance protec-
tion pickup in Z1B drops out, it will be deleted.
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2.6 Teleprotection for distance protection
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[logikdiagramm-unblockverfs-1-leitungsende-wlk-300702, 1, en_GB]
Figure 2-64 Send and enabling logic of the unblocking scheme
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2.6 Teleprotection for distance protection
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[unblock-logik-240402-wlk, 1, en_GB]
Figure 2-65 Unblock logic
Blocking Scheme
The following scheme is suited for conventional transmission media.
Principle
In the case of the blocking scheme, the transmission channel is used to send a block signal from one line end
to the other. The signal is sent as soon as the protection detects a fault in reverse direction or immediately
after occurrence of a fault (jump detector via dotted line in Figure 2-66). It is stopped immediately as soon as
the distance protection detects a fault in forward direction. Tripping is possible with this scheme even if no
signal is received from the opposite line end. It is therefore mainly used for long lines when the signal must be
transmitted across the protected line by means of power line carrier (PLC) and the attenuation of the trans-
mitted signal at the fault location may be so severe that reception at the other line end cannot necessarily be
guaranteed.
2.6.7
Functions
2.6 Teleprotection for distance protection
130 SIPROTEC 4, 7SA522, Manual
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The function scheme is shown in Figure 2-66.
Faults inside the overreaching zone Z1B, which is set to approximately 120% of the line length, will initiate
tripping unless a blocking signal is received from the other line end. On three terminal lines, Z1B must be set
to reliably reach beyond the longer line section, even if there is an additional infeed via the tee point. Due to
possible differences in the pickup times of the devices at both line ends and due to the signal transmission
time delay, the tripping must be somewhat delayed by TV in this case.
To avoid signal race conditions, a transmit signal can be prolonged by the settable time TS once it has been
initiated.
[funktionsschema-blockierverfahrens-wlk-300702, 1, en_GB]
Figure 2-66 Function diagram of the blocking scheme
Sequence
Figure 2-67 shows the logic diagram of the blocking scheme for one line end.
The overreach zone Z1B is blocked which is why it must be set to Forward (address 1351 Op. mode Z1B,
see also Section 2.2.1 Distance protection, general settings at margin heading “Controlled Zone Z1B”).
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signals are sent to both opposite line
ends. The receive signals are then combined with a logical OR gate as no blocking signal must be received
from any line end during an internal fault. With the parameter Type of Line (address 2102) the device is
informed as to whether it has one or two opposite line ends.
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2.6 Teleprotection for distance protection
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[logikdia-des-blockierverfahrens-ein-leitungsende-240402wlk, 1, en_GB]
Figure 2-67 Logic diagram of the blocking scheme (one line end)
As soon as the distance protection has detected a fault in the reverse direction, a blocking signal is transmitted
(e.g.
Dis.T.SEND
, No. 4056). The transmitted signal may be prolonged by setting address 2103 accordingly.
The blocking signal is stopped if a fault is detected in the forward direction (e.g.
Dis.T.BL STOP
, No. 4070).
Very rapid blocking is possible by transmitting also the output signal of the jump detector for measured
values. To do so, the output
DisJumpBlocking
(No. 4060) must also be allocated to the transmitter output
relay. As this jump signal appears at every measured value jump, it should only be used if the transmission
channel can be relied upon to respond promptly to the disappearance of the transmitted signal.
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2.6 Teleprotection for distance protection
132 SIPROTEC 4, 7SA522, Manual
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If there is a disturbance in the signal transmission path the overreaching zone can be blocked via a binary
input. The distance protection operates with the usual time grading characteristic (non delayed trip in Z1). The
overreach zone Z1B may, however, be activated by internal automatic reclosure or external criteria via the
binary input
>Enable ARzones
.
The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc-
tion reversal resulting during the clearance of faults on parallel lines is neutralised by “Transient blocking”. The
received blocking signals also prolong the release by the transient blocking time TrBlk BlockTime (address
2110) if it has been present for at least the waiting time TrBlk Wait Time (address 2109), see
Figure 2-68). After expiration of TrBlk BlockTime (address 2110) the delay time Release Delay
(address 2108) is restarted.
The blocking scheme inherently allows even single-end fed short-circuits to be tripped rapidly without any
special measures, as the non feeding end cannot generate a blocking signal.
Transient Blocking
In the overreach schemes, the transient blocking provides additional security against erroneous signals due to
transients caused by clearance of an external fault or by fault direction reversal during clearance of a fault on a
parallel line.
The principle of transient blocking scheme is that following the incidence of an external fault, the formation of
a release signal is prevented for a certain (settable) time. In the case of permissive schemes, this is achieved by
blocking of the transmit and receive circuit.
Figure 2-68 shows the principle of the transient blocking for a permissive scheme.
If, following fault detection, a non-directional fault or a fault in the reverse direction is determined within the
waiting time TrBlk Wait Time (address 2109), the transmit circuit and the release of the overreaching
zone Z1B are prevented. This blocking is maintained for the duration of the transient blocking time TrBlk
BlockTime (address 2110) also after the reset of the blocking criterion. But if a trip command is already
present in Z1, the transient blocking time TrBlk BlockTime is terminated and thus the blocking of the
signal transmission scheme in the event of an internal fault is prevented.
In the case of the blocking scheme, the transient blocking also prolongs the received block signal as shown in
the logic diagram Figure 2-85. After expiration of TrBlk BlockTime (address 2110) the delay time
Release Delay (address 2108) is restarted.
[trans-block-freigabe-wlk-300702, 1, en_GB]
Figure 2-68 Transient blocking for permissive schemes
Measures for Weak or Zero Infeed
In cases where there is weak or no infeed present at one line end, the distance protection will not pick up.
Neither a trip nor a send signal can therefore be generated there. With the comparison schemes, using a
2.6.8
2.6.9
Functions
2.6 Teleprotection for distance protection
SIPROTEC 4, 7SA522, Manual 133
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permissive signal, fast tripping could not even be achieved at the line end with strong infeed without special
measures, as the end with weak infeed does not transmit a permissive release signal.
To achieve fast tripping at both line ends in such cases, the distance protection provides special supplements
for feeders with weak infeed.
To enable the line end with the weak infeed condition to trip independently, 7SA522 has a special tripping
function for weak infeed conditions. As this is a separate protection function with a dedicated trip command,
it is described separately in Section 2.9.2 Classical Tripping.
Echo Function
If there is no fault detection at one line end, the echo function causes the received signal to be sent back to
the other line end as an “echo”, where it is used to initiate permissive tripping.
The common echo signal (see Section 2.9.1 Echo function) is triggered both by the distance protection and by
the earth fault protection. The following figure shows the generation of the echo release by the distance
protection.
The detection of the weak infeed condition and accordingly the requirement for an echo are combined in a
central AND gate. The distance protection must neither be switched off nor blocked as it would otherwise
always produce an echo due to the missing fault detection. If, however, the time delayed overcurrent protec-
tion is used as an emergency function, an echo is nevertheless possible if the distance protection is out of
service because the fault detection of the emergency time overcurrent protection replaces the distance protec-
tion fault detection. During this mode the emergency time overcurrent protection must naturally not also be
blocked or switched off.
Even when the emergency overcurrent protection does not pick up, an echo is created for permissive release
scheme during emergency function. The time overcurrent protection at the weaker end must operate with
more sensitivity than the distance protection at the end with high infeed. Otherwise, the selectivity
concerning 100% of the line length is not given.
The essential condition for an echo is the absence of distance protection or overcurrent protection fault detec-
tion with the simultaneous reception of a signal from the teleprotection scheme logic, as shown in the corre-
sponding logic diagrams (Figure 2-61, Figure 2-62, and Figure 2-64).
When the distance protection picks up single-pole or two-pole, it is nevertheless possible to send an echo if
the measurement of the phases that have not picked up has revealed weak infeed.
To prevent an echo following de-energisation of the line and dropout of the fault detection, no echo can be
generated anymore once a pickup has already occurred (RS flip-flop in thr following figure). Furthermore, the
echo can be blocked anytime via the binary input
>Dis.T.BlkEcho
.
Figure 2-69 shows the generation of the echo release signal. Since there is a correlation between this function
and the weak infeed tripping function, it is described separately (see Section 2.9.1 Echo function).
[logikdiagramm-echofkt-dis-signaluebert-skg-300702, 1, en_GB]
Figure 2-69 Generation of the echo release signal
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2.6 Teleprotection for distance protection
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Setting Notes
General
The teleprotection supplement of distance protection is only in service if it is set during the configuration to
one of the possible modes of operation in address 121. Depending on this configuration, only those parame-
ters which are applicable to the selected mode appear here. If the teleprotection supplement is not required
the address 121 Teleprot. Dist. = Disabled.
Conventional transmission
The following modes are possible with conventional transmission links (as described in Section 2.6 Teleprotec-
tion for distance protection:
Direct Underreach
Transfer Trip
Remote trip without any pickup,
PUTT (Z1B) Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT),
POTT Permissive Overreach Transfer Trip (POTT),
UNBLOCKING Directional Unblocking scheme,
BLOCKING Directional Blocking scheme,
At address 2101 FCT Telep. Dis. the use of a teleprotection scheme can be turned ON- or OFF.
If the teleprotection has to be applied to a three terminal line the setting in address 2102must be Type of
Line = Three terminals, if not, the setting remains Two Terminals.
Digital transmission
The following modes are possible with digital transmission using the protection data interface (described in
Section 2.6 Teleprotection for distance protection):
PUTT (Z1B) Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT)
POTT Permissive Overreach Transfer Trip (POTT)
The desired mode is selected in address 2101 FCT Telep. Dis.. The use of a teleprotection scheme can
also be turned OFF here. Address 147 NUMBER OF RELAY indicates the number of ends and must be set
identically in all devices. The distance protection scheme via the protection data interface is only active if
parameter 121 Teleprot. Dist. was set to SIGNALv.ProtInt for all devices in a constellation.
Distance Protection Prerequisites
For all applications of teleprotection schemes it must be ensured that the fault detection of the distance
protection in the reverse direction has a greater reach than the overreaching zone of the opposite line end
(refer to the shaded areas in Figure 2-70 on the right hand side)! This is normally predefined for the U/Ι/ϕ
pickup since the local voltage of a reverse fault is smaller than the voltage of the remote supplying end. For
impedance pickup at least one of the distance stages must be set to Reverse or Non-Directional. During
a fault in the shaded area (in the left section of the picture), this fault would be in zone Z1B of the protection
at B as zone Z1B is set incorrectly. The distance protection at A would not pick up and therefore interpret this
as a fault with single end infeed from B (echo from A or no block signal at A). This would result in a false trip!
The blocking scheme needs furthermore a fast reverse stage to generate the blocking signal. Apply zone 3
with non-delayed setting to this end.
[sign-ueber-dis-einst-vergl-oz-010802, 1, en_GB]
Figure 2-70 Distance protection setting with permissive overreach schemes
2.6.10
Functions
2.6 Teleprotection for distance protection
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Time Settings
The send signal prolongation Send Prolong. (address 2103) must ensure that the send signal reliably
reaches the opposite line end, even if there is very fast tripping at the sending line end and/or the signal trans-
mission time is relatively long. In the case of the permissive overreaching schemes POTT, and UNBLOCKING
this signal prolongation time is only effective if the device has already issued a trip command. This ensures the
release of the other line ends even if the short-circuit has been cleared very rapidly by the independent zone
Z1. In the case of the blocking scheme BLOCKING, the transmit signal is always prolonged by this time. In this
case, it corresponds to a transient blocking following a reverse fault. This parameter can only be changed in
DIGSI at Display Additional Settings.
If the permissive release scheme UNBLOCKING is used, steady-state line faults can be detected. The output of
such a fault can be delayed with the monitoring time Delay for alarm (address 2107). This parameter can
only be set in DIGSI at Display Additional Settings.
With the release delay Release Delay (address 2108) the release of the zone Z1B can be delayed. This is
only required for the blocking scheme BLOCKING to allow sufficient transmission time for the blocking signal
during external faults. This delay only has an effect on the receive circuit of the teleprotection scheme;
conversely the release signal is not delayed by the set time delay T1B of the overreaching zone Z1B.
The parameter Mem.rec.sig. (address 2113) is only effective for the schemes PUTT (Z1B) with zone
acceleration, POTT, and UNBLOCKING. If the parameter Mem.rec.sig. (address 2113) is set to YES and an
own distance protection pickup is available in Z1B, the phase-selective release effected via the teleprotection
scheme is stored. Storing the received signal makes sense if the teleprotection scheme is used in ring
networks as a backup protection with increased grading time.
Transient blocking
The parameters TrBlk Wait Time and TrBlk BlockTime serve the transient blocking with the permissive
(overreaching) schemes. With permissive underreach transfer trip schemes they are of no consequence.
The time TrBlk Wait Time (address 2109) is a waiting time prior to transient blocking. The transient
blocking will be activated in the permissive overreach transfer schemes only after the distance protection has
not detected a fault in forward direction within this time after fault detection. In the case of the blocking
scheme, the waiting time prevents transient blocking in the event that the blocking signal reception from the
opposite line end is very fast. With the setting ∞ there is no transient blocking. This parameter can only be
changed in DIGSI at Display Additional Settings.
i
i
NOTE
With POTT and UNBLOCKING schemes, the TrBlk Wait Time must not be set too short to prevent
unwanted activation of the transient blocking TrBlk BlockTime when the direction measurement is
delayed compared to the function pickup (signal transients). A setting of 10 ms to 40 ms is generally appli-
cable depending on the operating (tripping) time of the relevant circuit breaker on the parallel line.
It is absolutely necessary that the transient blocking time TrBlk BlockTime (address 2110) is longer than
the duration of transients resulting from the inception or clearance of external short circuits. During this time
the send signal is blocked for the permissive overreach schemes POTT and UNBLOCKING if the protection had
initially detected a reverse fault. In the case of blocking scheme BLOCKING, the blocking of the Z1B release is
prolonged by this time by both the detection of a reverse fault and the (blocking) received signal. After expira-
tion of TrBlk BlockTime (address 2110) the delay time Release Delay (address 2108) is restarted for
the blocking scheme. Since the blocking scheme always requires setting the delay time Release Delay, the
transient blocking time TrBlk BlockTime (address 2110) can usually be set very short. This parameter can
only be altered with DIGSI under Display Additional Settings.
Where the teleprotection schemes of the distance protection and earth fault protection share the same
channel, DIS TRANSBLK EF (address 2112) should be set to YES. This blocks also the distance protection if
an external fault was previously detected by the earth fault protection only.
Echo Function
The echo function settings are common to all weak infeed measures and summarized in tabular form in
Section 2.9.2.2 Setting Notes.
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2.6 Teleprotection for distance protection
136 SIPROTEC 4, 7SA522, Manual
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i
i
NOTE
The
ECHO SIGNAL
(No. 4246) must be allocated separately to the output relays for the transmitter actua-
tion, as it is not contained in the transmit signals of the transmission functions.
On the digital protection data interface with permissive overreach transfer trip mode, the echo is trans-
mitted as a separate signal without taking any special measures.enthalten.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
2101 FCT Telep. Dis. ON
PUTT (Z1B)
POTT
OFF
ON Teleprotection for Distance protec-
tion
2102 Type of Line Two Terminals
Three terminals
Two Terminals Type of Line
2103A Send Prolong. 0.00 .. 30.00 sec 0.05 sec Time for send signal prolongation
2107A Delay for alarm 0.00 .. 30.00 sec 10.00 sec Time Delay for Alarm
2108 Release Delay 0.000 .. 30.000 sec 0.000 sec Time Delay for release after pickup
2109A TrBlk Wait Time 0.00 .. 30.00 sec; ∞ 0.04 sec Transient Block.: Duration external
flt.
2110A TrBlk BlockTime 0.00 .. 30.00 sec 0.05 sec Transient Block.: Blk.T. after ext.
flt.
2112A DIS TRANSBLK EF YES
NO
YES DIS transient block by EF
2113 Mem.rec.sig. YES
NO
NO Memorize receive signal
Information List
No. Information Type of
Informa-
tion
Comments
4001 >Dis.Telep. ON SP >Distance Teleprotection ON
4002 >Dis.Telep.OFF SP >Distance Teleprotection OFF
4003 >Dis.Telep. Blk SP >Distance Teleprotection BLOCK
4005 >Dis.RecFail SP >Dist. teleprotection: Carrier faulty
4006 >DisTel Rec.Ch1 SP >Dis.Tele. Carrier RECEPTION Channel 1
4007 >Dis.T.RecCh1L1 SP >Dis.Tele.Carrier RECEPTION Channel 1,L1
4008 >Dis.T.RecCh1L2 SP >Dis.Tele.Carrier RECEPTION Channel 1,L2
4009 >Dis.T.RecCh1L3 SP >Dis.Tele.Carrier RECEPTION Channel 1,L3
4010 >Dis.T.Rec.Ch2 SP >Dis.Tele. Carrier RECEPTION Channel 2
4030 >Dis.T.UB ub 1 SP >Dis.Tele. Unblocking: UNBLOCK Channel 1
4031 >Dis.T.UB bl 1 SP >Dis.Tele. Unblocking: BLOCK Channel 1
4032 >Dis.T.UB ub1L1 SP >Dis.Tele. Unblocking: UNBLOCK Ch. 1, L1
4033 >Dis.T.UB ub1L2 SP >Dis.Tele. Unblocking: UNBLOCK Ch. 1, L2
4034 >Dis.T.UB ub1L3 SP >Dis.Tele. Unblocking: UNBLOCK Ch. 1, L3
2.6.11
2.6.12
Functions
2.6 Teleprotection for distance protection
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No. Information Type of
Informa-
tion
Comments
4035 >Dis.T.UB ub 2 SP >Dis.Tele. Unblocking: UNBLOCK Channel 2
4036 >Dis.T.UB bl 2 SP >Dis.Tele. Unblocking: BLOCK Channel 2
4040 >Dis.T.BlkEcho SP >Dis.Tele. BLOCK Echo Signal
4050 Dis.T.on/off BI IntSP Dis. Teleprotection ON/OFF via BI
4052 Dis.Telep. OFF OUT Dis. Teleprotection is switched OFF
4054 Dis.T.Carr.rec. OUT Dis. Telep. Carrier signal received
4055 Dis.T.Carr.Fail OUT Dis. Telep. Carrier CHANNEL FAILURE
4056 Dis.T.SEND OUT Dis. Telep. Carrier SEND signal
4057 Dis.T.SEND L1 OUT Dis. Telep. Carrier SEND signal, L1
4058 Dis.T.SEND L2 OUT Dis. Telep. Carrier SEND signal, L2
4059 Dis.T.SEND L3 OUT Dis. Telep. Carrier SEND signal, L3
4060 DisJumpBlocking OUT Dis.Tele.Blocking: Send signal with jump
4068 Dis.T.Trans.Blk OUT Dis. Telep. Transient Blocking
4070 Dis.T.BL STOP OUT Dis. Tele.Blocking: carrier STOP signal
4080 Dis.T.UB Fail1 OUT Dis. Tele.Unblocking: FAILURE Channel 1
4081 Dis.T.UB Fail2 OUT Dis. Tele.Unblocking: FAILURE Channel 2
4082 Dis.T.BL STOPL1 OUT DisTel Blocking: carrier STOP signal, L1
4083 Dis.T.BL STOPL2 OUT DisTel Blocking: carrier STOP signal, L2
4084 Dis.T.BL STOPL3 OUT DisTel Blocking: carrier STOP signal, L3
4085 Dis.T.RecL1Dev1 OUT Dis.Tele.Carrier RECEPTION, L1, Device1
4086 Dis.T.RecL2Dev1 OUT Dis.Tele.Carrier RECEPTION, L2, Device1
4087 Dis.T.RecL3Dev1 OUT Dis.Tele.Carrier RECEPTION, L3, Device1
4088 Dis.T.RecL1Dev2 OUT Dis.Tele.Carrier RECEPTION, L1, Device2
4089 Dis.T.RecL2Dev2 OUT Dis.Tele.Carrier RECEPTION, L2, Device2
4090 Dis.T.RecL3Dev2 OUT Dis.Tele.Carrier RECEPTION, L3, Device2
4091 Dis.T.RecL1Dev3 OUT Dis.Tele.Carrier RECEPTION, L1, Device3
4092 Dis.T.RecL2Dev3 OUT Dis.Tele.Carrier RECEPTION, L2, Device3
4093 Dis.T.RecL3Dev3 OUT Dis.Tele.Carrier RECEPTION, L3, Device3
Functions
2.6 Teleprotection for distance protection
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Earth fault overcurrent protection in earthed systems (optional)
In earthed systems, where extremely large fault resistances may exist during earth faults (e.g. overhead lines
without earth wire, sandy soil) the fault detection of the distance protection will often not pick up because the
resulting earth fault impedance could be outside the fault detection characteristic of the distance protection.
The 7SA522 distance protection features protection functions for high-resistance earth faults in earthed power
systems. These options are available — partly depending on the ordered version:
Three overcurrent stages with definite time tripping characteristic (definite time),
– One overcurrent stage with inverse time characteristic (IDMT) or
– One zero-sequence voltage stage with inverse time characteristic
– One zero-sequence power stage with inverse time characteristic
The stages may be configured independently of each other and combined according to the user's require-
ments. If the fourth current, voltage or power dependent stage is not required, it may be employed as a fourth
definite time stage.
Each stage may be set to non directional or directional — forward or reverse. For each stage it can be deter-
mined if it should cooperate with the teleprotection function. If the protection is applied in the proximity of
transformers, an inrush restraint can be activated. Furthermore, blocking by external criteria is possible via
binary inputs (e.g. for reverse interlocking or external automatic reclosure). During energisation of the
protected feeder onto a dead fault it is also possible to release any one stage or several stages for non-delayed
tripping. Stages that are not required, are disabled.
Functional Description
Measured Quantities
The zero-sequence current is used as measured variable. According to its definition equation it is obtained
from the sum of the three phase currents, i.e. 3·Ι0 = ΙL1 + ΙL2 + ΙL3. Depending on the version ordered, and the
configured application for the fourth current input Ι4 of the device, the zero-sequence current can be meas-
ured or calculated.
If input Ι4 is connected in the starpoint of the set of current transformers or to a separate earth current trans-
former on the protected feeder, the earth current is directly available as a measured value.
If the device is fitted with the highly sensitive current input for Ι4, this current Ι4 is used when allocated and
takes the set factor I4/Iph CT into consideration (address 221, see Section 2.1.2.1 Setting Notes). As the
linear range of this measuring input is restricted considerably in the high range, this current is only evaluated
up to an amplitude of approx. 1.6 A. In the event of larger currents, the device automatically switches over to
the evaluation of the zero-sequence current derived from the phase currents. Naturally, all three phase
currents obtained from a set of three star-connected current transformers must be available and connected to
the device. The processing of the earth current is then also possible if very small as well as large earth fault
currents occur.
If the fourth current input Ι4 is otherwise utilized, e.g. for a transformer starpoint current or for the earth
current of a parallel line, the device calculates the zero-sequence current from the phase currents. Naturally in
this case also all three phase currents derived from a set of three star connected current transformers must be
available and connected to the device.
The zero-sequence voltage is determined by its defining equation 3·U0 = UL1-E + UL2-E + UL3-E. The zero-
sequence voltage is measured or calculated depending on the application of the fourth voltage input U4 of the
device. If the fourth voltage input is connected to the open delta winding Udelta of a voltage transformer set
and if it is configured accordingly (address 210 U4 transformer = Udelta transf., see Section
2.1.2.1 Setting Notes), this voltage is used considering the factor Uph / Udelta (address 211, see Section
2.1.2.1 Setting Notes). If not, the device calculates the zero-sequence voltage from the phase voltages. Natu-
rally, all three phase-to-earth voltages obtained from a set of three star-connected voltage transformers must
be available and connected to the device.
2.7
2.7.1
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Definite time very high set current stage 3Ι0>>>
The triple zero-sequence current 3Ι0 is passed through a numerical filter and then compared with the set value
3I0>>>. If this value is exceeded an alarm is issued. After the corresponding delay time T 3I0>>> has
expired, a trip command is issued which is also alarmed. The reset threshold is approximately 95 % of the
pickup threshold.
Figure 2-71 shows the logic diagram of the 3Ι0>>> stage. The function blocks “direction determination”,
“permissive teleprotection” and the generation of the signals “Line closure” and “EF Inrush” are common to all
stages and described below. They may, however, affect each stage individually. This is accomplished with the
following setting parameters:
•Op. mode 3I0>>>, determines the operating direction of the stage: Forward, Reverse, Non-
Directional or Inactive.
•3I0>>> Telep/BI, determines whether a non-delayed trip with the teleprotection scheme or via
binary input 1310
>EF InstTRIP
is possible (YES) or not (NO).
•3I0>>>SOTF-Trip, determines whether during switching onto a fault tripping shall be instantaneous
(YES) or not (NO) with this stage.
•3I0>>>InrushBlk, which is used to switch the inrush stabilization (rush blocking) on (YES) or off(NO).
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[logikdia-der-3i0svgstufe-240402wlk, 1, en_GB]
Figure 2-71 Logic diagram of the 3Ι0>>>-stage
Definite time high set current stage 3Ι0>>
The logic of the high-set current stage 3Ι0>> is the same as that of the 3Ι0>>>-stage. In all references 3I0>>>
must merely be replaced with 3I0>>. In all other respects Figure 2-71 applies.
Definite time overcurrent stage 3Ι0>
The logic of the overcurrent stage 3Ι0> too, is the same as that of the 3Ι0>>>-stage. In all references 3I0>>>
must merely be replaced with 3I0>. In all other respects Figure 2-71 applies. This stage operates with a
specially optimized digital filter that completely suppresses all harmonic components beginning with the 2nd
harmonic. Therefore it is particularly suited for a highly-sensitive earth fault detection.
A fourth definite-time stage can be implemented by setting the “inverse-time” stage (refer to the next para-
graph) to definite-time stage.
Functions
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Inverse time overcurrent stage 3Ι0P
The logic of the stage with inverse time delay operates in the same way as the remaining stages. This stage
operates with a specially optimized digital filter that completely suppresses all harmonic components begin-
ning with the 2nd harmonic. Therefore it is particularly suited for a highly-sensitive earth fault detection.
However, the time delay is calculated here based on the type of the set characteristic, the intensity of the
earth current and a time multiplier 3I0p Time Dial ((IEC characteristic, Figure 2-72) or a time multiplier
TimeDial TD3I0p (ANSI characteristic). A pre-selection of the available characteristics was already carried
out during the configuration of the protection functions. Furthermore, an additional fixed delay Add.T-
DELAY may be selected. The characteristics are shown in the Technical Data.
Figure 2-72 shows the logic diagram. The setting addresses of the IEC characteristics are shown by way of an
example. In the setting information the different setting addresses are described in detail.
It is also possible to implement this stage equally with a definite time delay. In this case 3I0p PICKUP is the
pickup threshold and Add.T-DELAY the definite time delay. The inverse time characteristic is then effectively
bypassed.
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[logikdia-der-3i0p-stufe-abhaengiger-umz-240402-wlk, 1, en_GB]
Figure 2-72 Logic diagram of the 3Ι0P stage (inverse time overcurrent protection), example for IEC charac-
teristics
Inverse time overcurrent stage with logarithmic inverse characteristic
The inverse logarithmic characteristic differs from the other inverse characteristics mainly by the fact that the
shape of the curve can be influenced by a number of parameters. The slope and a time shift 3I0p MaxT-
DELAY which directly affect the curve, can be changed. The characteristics are shown in the Technical Data.
Figure 2-73 shows the logic diagram. In addition to the curve parameters, a minimum time 3I0p MinT-
DELAY can be determined; below this time no tripping can occur. Below a current factor of 3I0p Start-
point, which is set as a multiple of the basic setting 3I0p PICKUP, no tripping can take place.
Further information regarding the effect of the various parameters can be found in the setting information of
the function parameters in Section 2.7.2 Setting Notes.
The remaining setting options are the same as for the other curves.
Functions
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[logikdia-der-3i0p-stufe-der-log-inv-kennlinie-240402-wlk, 1, en_GB]
Figure 2-73 Logic diagram of the 3Ι0P stage for the inverse logarithmic characteristic
Zero-sequence voltage time protection (U0 inverse)
The zero-sequence voltage time protection operates according to a voltage-dependent trip time characteristic.
It can be used instead of the time overcurrent stage with inverse time delay.
The voltage/time characteristic can be displaced in voltage direction by a constant voltage (U0inv.
minimum, valid for t → ∞) and in time direction by a constant time (T forw. (U0inv))). The characteristics
are shown in the Technical Data.
Figure 2-74 shows the logic diagram. The tripping time depends on the level of the zero-sequence voltage U0.
For meshed earthed systems the zero-sequence voltage increases towards the earth fault location. The inverse
Functions
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characteristic results in the shortest command time for the relay closest to the fault. The other relays then
reset.
[gericht-nullspg-unger-reserve-wlk-300702, 1, en_GB]
Figure 2-74 Directional zero-sequence voltage time protection with non-directional backup stage
A further time stage T rev. (U0inv) provokes non-directional tripping with a voltage-independent delay.
This stage can be set above the directional stage. When tripping with this stage it is, however, a prerequisite
that the time of the voltage-controlled stage has already expired (without directional check). In case the zero-
sequence voltage is too low or the voltage transformer circuit breaker is tripped, this stage is also disabled.
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Zero-sequence power protection
The zero-sequence power protection operates according to a power-dependent trip time characteristic. It can
be used instead of an inverse time overcurrent stage.
The power is calculated from the zero-sequence voltage and the zero-sequence current. The component Sr is
decisive in direction of a configurable compensation angle ϕcomp, which is also referred to as compensated
zero-sequence power, i.e.
Sr = 3 Ι0·3 U0·cos(φ – φcomp)
with φ = ∠ (U0; Ι0). φcomp thus determines the direction of the maximum sensitivity (cos(φ – φcomp) = 1, wenn
φ = φcomp). Due to its sign information the power calculation automatically includes the direction. The power
for the reverse direction can be determined by reversing the sign.
The power-time characteristic can be displaced in power direction via a reference value Sref (= basic value for
the inverse characteristic for φ = φcomp) and in time direction by a factor k.
[logikdia-nullleistungsschutz-wlk-090902, 1, en_GB]
Figure 2-75 Zero-sequence power protection
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Figure 2-75 shows the logic diagram. The tripping time depends on the level of the compensated zero-
sequence power Sr as defined above. For meshed earthed systems the zero-sequence voltage and the zero-
sequence current increase towards the earth fault location. The inverse characteristic results in the shortest
command time for the relay closest to the fault. The other relays then reset.
Phase current stabilization
Asymmetrical load conditions in multiple-earthed systems or different current transformer errors can result in
a zero-sequence current. This zero-sequence current could cause faulty pickup of the earth current stages if
low pickup thresholds are set. To avoid this, the earth current stages are stabilized by the phase current: as the
phase currents increase, the pickup thresholds are increased (Figure 2-76). The stabilization factor (= slope)
can be changed with parameter Iph-STAB. Slope (address 3104). It applies to all stages.
[phasenstromstabilisierung-wlk-300702, 1, en_GB]
Figure 2-76 Phase current stabilization
Inrush restraint
If the device is connected to a transformer feeder, large inrush currents can be expected when the transformer
is energized; if the transformer starpoint is earthed, also in the zero-sequence path. The inrush current may be
a multiple of the rated current and flow for several tens of milliseconds up to several minutes.
Although the fundamental current is evaluated by filtering of the measured current, an incorrect pickup
during energization of the transformer may result if very short delay times are set. In the rush current there is
a substantial portion of fundamental current depending on the type and size of the transformer that is being
energized.
The inrush stabilization blocks tripping of all those stages for which it has been activated, for as long as the
rush current is recognized.
The inrush current is characterized by a relatively large amount of second harmonic (twice the rated
frequency) which is virtually non-existent in the short-circuit current. Numerical filters that carry out a Fourier
analysis of the current are used for the frequency analysis. As soon as the harmonic content is greater than the
set value (2nd InrushRest), the affected stage is blocked.
Inrush blocking is not effective below a certain current threshold. For devices with normal earth current trans-
former and for devices without separate earth current transformer, inrush blocking is only effective if the
earth current is higher than 0.41 ΙN or if the current of the 2nd harmonic is higher than 0.041 ΙN.
For devices with sensitive current transformer, inrush blocking becomes effective as soon as the earth current
is higher than 22 mA or the current of the 2nd earth current harmonic is higher than 2.2 mA.
Determination of direction with zero-sequence system (zero-sequence voltage and/or transformer star point
current
The direction determination is carried out with the measured current ΙE (= –3·Ι0), which is compared to a refer-
ence voltage UP.
The voltage required for direction determination UP may be derived from the starpoint current ΙY of an earthed
transformer (source transformer), provided that the transformer is available.
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Moreover, both the zero-sequence voltage 3·U0 and the starpoint current ΙY of a transformer can be used for
measurement. The reference magnitude UP then is the sum of the zero-sequence voltage 3·U0 and a value
which is proportional to reference current ΙY. This value is about 20 V for rated current (Figure 2-77).
The directional determination using the transformer starpoint current is independent of voltage transformers
and therefore also functions reliably during a fault in the voltage transformer secondary circuit. It requires,
however, that at least a substantial amount of the earth fault currents are fed via the transformer whose star-
point current is measured.
For the determination of direction, a minimum current 3Ι0 and a minimum displacement voltage which can be
set as 3U0> are required. If the displacement voltage is too small, the direction can only be determined if it is
polarised with the transformer starpoint current and this exceeds a minimum value corresponding to the
setting IY>. Direction determination with 3U0 is blocked if the device detects a fault condition in the voltage
transformer secondary circuit (binary input reports trip of the voltage transformer mcb, “Fuse Failure Monitor”,
measured voltage failure monitoring) or a single-pole dead time.
In order to allow directional determination also during a fault in the secondary circuit of the “normal” voltage
transformers, the broken delta winding Uen can additionally be connected, in combination with a separate VT
miniature circuit breaker (address 210 U4 transformer = Udelta transf.). When this VT miniature
circuit breaker trips for the Uen transformer (no. 362
>FAIL:U4 VT
), the system switches automatically to the
zerosequence voltage calculated from the "normal" voltage transformers.
Directional determination with 3·U0 is possible as long as the calculated zero-sequence voltage is not
disturbed as well. The calculated zero-sequence voltage is deemed to be disturbed if the VT miniature circuit
breaker has tripped (binary input no. 361
>FAIL:Feeder VT
), or if the “Fuse failure monitor” or the meas-
uring voltage monitoring have picked up.
[richtungskennlinie-des-erdfehlerschutzes-wlk-300702, 1, en_GB]
Figure 2-77 Directional characteristic of the earth fault protection
Determination of direction for long lines
In case of forward faults on very long lines, the zero-sequence voltage required for determination of direction
may become very small. The reason for this is the high ratio between the zero-sequence impedance of the line
and the infeed (source).
In the case of reverse faults, however, the zero-sequence voltage cannot drop that low if at the same time the
zero-sequence current exceeds the set pickup level; refer also to Figure 2-84).
For this reason, the system may automatically indicate a “forwards” direction when the zero-sequence voltage
drops below the threshold value 3186 3U0< forward.
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Determination of direction for lines with series compensation
The direction determination/directional characteristic of the earth fault protection is based on the assumption
of a mainly inductive zero-sequence system impedance. In case of a series-compensated line, however, this
assumption does not apply anymore. According to the degree of compensation, the zero-sequence system
impedance is more or less influenced regarding its capacity. The situation is especially unfavorable if the
capacitor is located on the busbar side of the voltage transformers.
In case of faults on the protected line, the zero-sequence voltage consists of two components: the voltage
drop on the source impedance (mainly inductive) and the voltage drop over the series capacitor.
If the capacity of the series capacitor is known (and constant), the voltage drop on the series capacitor can be
determined according to the following formula:
UCO = -jXCO 3·Ι0
[korr-serienkomp-richt-m-0-20100713, 1, en_GB]
Figure 2-78 Correction of series compensation for the direction determination with zero-sequence system
The voltage drop on the series capacitor UC0 = 3·Ι0 · XserCap (address 3187) is subtracted from the measured
zero-sequence voltage 3U0meas. The resulting voltage 3U0Dir is then assigned to the directional characteristic of
the earth fault protection, as shown on Figure 2-78.
Determination of direction with negative phase-sequence system
It is advantageous to use negative sequence system values for the direction measurement if the zero-
sequence voltages that appear during earth faults are too small for an analysis of the zero-sequence values.
Otherwise, this function operates the same way as the direction determination with zero-sequence current
and zero-sequence voltage. Instead of 3Ι0 and 3U0, the negative sequence signals 3Ι2 and 3U2 are simply used
for the measurement. These signals must also have a minimum magnitude of 3I2> or 3U2>.
It is also possible to determine the direction with a zero-sequence system or a negative sequence system. In
this case the device determines whether the zero-sequence voltage or the negative sequence voltage is larger.
The direction is determined by the larger of the two values. The direction is not determined during the single-
pole dead time.
For the application of a teleprotection scheme, the direction determination must be performed at all terminals
with the same setting.
Determination of direction with compensated zero-sequence power
The zero-sequence power may also be used for direction determination. In this case the sign of the compen-
sated zero-sequence power is decisive. This is the zero-sequence power component Sr as mentioned above
under “Zero-Sequence Power” in direction of a configurable compensation angle ϕcomp, i.e.
Sr = 3Ι0·3U0·cos(φ – φcomp).
The direction determination yields
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•forward if Sr is positive and Sr > S VORWÄRTS,
•reverse if Sr is negative and |Sr| > S VORWÄRTS.
The determination of direction requires a minimum current 3Ι0 and a minimum displacement voltage which
can be set as 3U0>. The prerequisite is still that the compensated zero-sequence power has a configurable
minimum magnitude. Direction determination is also blocked if the device detects a fault condition in the
voltage transformer secondary circuit (binary input reports trip of the voltage transformer mcb, “Fuse Failure
Monitor”, measured voltage failure monitoring) or a single-pole dead time. Figure 2-79 shows an example of
the directional characteristic.
[richtungsbest-nullleist-wlk-090902, 1, en_GB]
Figure 2-79 Directional characteristic with zero sequence power, example Sr = setting value S FORWARD
Selection of the earth faulted phase
Since the earth fault protection uses the quantities of the zero-sequence system and the negative sequence
system, the faulted phase cannot be determined directly. To enable single-pole automatic reclosure in case of
high-resistance earth faults, the earth fault protective function features a phase selector. The phase-selector
detects by means of the distribution of the currents and voltages whether a fault is single-phase or multi-
phase. If the fault is single-phase, the faulted phase is selected. The phase selector is blocked during a single-
pole automatic reclosure.
Once a multi-phase fault has been detected, a three-pole trip command is generated. Three-pole tripping is
also initiated if single-pole tripping would be possible but is not permitted. Single-pole tripping is prevented by
the setting or three-pole coupling of other internal protection functions or of an external reclosing device via
binary input.
The phase selector uses the phase angle between negative sequence current and zero-sequence current to
determine the fault type. The phase currents are evaluated - if necessary with load current compensation - to
distinguish between different fault types. This method relies on the fact that in the event of a single phase
fault the fault-free phases can conduct either no fault currents at all or only such fault currents that are almost
completely in phase.
If this criterion does not allow to determine the fault type, e.g. because the zero-sequence current or negative
sequence current is too low, an additional check is carried out for considerable voltage drops or overcurrents
that would indicate a single-phase fault.
The phase selector has an action time of approximately 40 ms. If the phase selector has not made a decision
during this time, three-pole tripping is initiated. Three-pole tripping is initiated anyway as soon as a multi-pole
fault has been detected, as described above. Therefore the phase-selective transmit signals in teleprotection
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schemes can have a delay of up to 40 ms as compared to the non phase-selective transmit signal 1384
EF
Tele SEND
(see Section 2.8 Teleprotection for earth fault overcurrent protection (optional)).
Figure 2-80 shows the logic diagram. The phase determined by the phase selector can be processed selectively
for each phase, for example the internal information “E/F PickupL1” etc. is used for phase-selective signal
transmission.
External indication of the phase-selective pickup is performed via the information
E/F L1 selec.
etc. This
information appears only if the phase was clearly detected. Single-pole tripping requires of course the general
prerequisites to be fulfilled (device must be suited for single-pole tripping, single-pole tripping allowed).
[logikdia-einpol-aus-phasenselek-wlk-090902, 1, en_GB]
Figure 2-80 Logic diagram of single-pole tripping with phase selector
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Blocking
The earth fault protection can be blocked by the distance protection. If in this case a fault is detected by the
distance protection, the earth fault protection will not trip. This gives the selective fault clearance by the
distance protection preference over tripping by the earth fault protection. The blocking can be restricted by
configuration to single-phase or multi-phase faults and to faults in distance zone Z1 or Z1/Z1B. The blocking
only affects the time sequence and tripping by the earth fault protection function and after the cause of the
blocking has been cleared, it is maintained for approximately 40ms to prevent signal race conditions. It is
issued as fault indication
EF TRIP BLOCK
(No. 1335).
The earth fault protection can also be blocked during the single-pole dead time of an automatic reclose cycle.
This prevents an incorrect measurement resulting from the zero-sequence current and voltage signals arising
in this state. The blocking affects optionally the entire protection function or the individual stages and is main-
tained for approximately 40ms after reclosure to prevent signal race conditions. If the complete function is
blocked, the indication
E/F BLOCK
(No. 1332) is output. The blocking of individual stages is signaled by the
indications 14080 to 14083.
If the device is combined with an external automatic reclose device or if single-pole tripping can result from a
separate (parallel tripping) protection device, the earth fault protection must be blocked via binary input
during the single-pole open condition.
[logik-blk-ef-1pol, 1, en_GB]
Figure 2-81 Logic diagram of single-pole tripping with phase selector
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Switching onto an earth fault
The line energisation detection can be used to achieve fast tripping when energising the circuit breaker in case
of an earth fault. The earth fault protection can then trip three-pole without delay. Parameters can be set to
determine to which stage(s) the non-delayed tripping following energisation applies (see also logic diagrams
from Figure 2-71 to Figure 2-75).
The non-delayed tripping in case of line energization detection is blocked as long as the inrush-stabilization
recognizes a rush current. This prevents instantaneous tripping by a stage which, under normal conditions, is
sufficiently delayed during energization of a transformer.
Setting Notes
General
During the configuration of the device scope of functions (refer to Section 2.1.1 Functional Scope, address
131 Earth Fault O/C) it was determined which group of characteristics is to be available. Only those
parameters that apply to the available characteristics, according to the selected configuration and the version
of the device, are accessible in the procedures described below.
Parameter 3101 FCT EarthFltO/C can be used to switch the earth fault protection ON- or OFF. This refers
to all stages of the earth fault protection.
If not required, each of the four stages can be deactivated by setting its MODUS ... to Inactive (see
below).
Blocking
The earth fault protection can be blocked by the distance protection to give preference to the selective fault
clearance by the distance protection over tripping by the earth fault protection. In address 3102 BLOCK for
Dist. it is determined whether blocking is performed during each fault detection of the distance protection
(every PICKUP) or only during single-phase fault detection by the distance protection (1phase PICKUP) or
only during multiple-phase fault detection by the distance protection (multiph. PICKUP). If blocking is not
desired, set NO.
It is also possible to block the earth fault protection trip only for pickup of the distance protection on the
protected line section. To block the earth fault protection for faults occurring within zone Z1, set address 3174
BLK for DisZone to in zone Z1. To block the earth fault protection for faults occurring within zone Z1 or
Z1B, set address 3174 BLK for DisZone to in zone Z1/Z1B. If, however, blocking of the earth fault
protection by the distance protection is to take effect regardless of the fault location, set address 3174 BLK
for DisZone to in each zone.
Address 3102 thus refers to the fault type and address 3174 to the fault location. The two blocking options
create an AND condition. To block the earth fault protection only for single-phase faults occurring in zone Z1,
set address 3102 BLOCK for Dist. = 1phase PICKUP and 3174 BLK for DisZone = in zone Z1. To
block the earth fault protection for any fault type (any distance protection pickup) occurring within zone Z1,
the setting 3102 BLOCK for Dist. = every PICKUP and 3174 BLK for DisZone = in zone Z1
applies.
The earth fault protection must be blocked during single-pole automatic reclose dead time to avoid pickup
with the zero-sequence values and, if applicable, the negative sequence values arising during this state.
When setting the power system data (Section 2.1.2.1 Setting Notes), it was specified whether all stages of the
earth fault protection are blocked together or separately during the single-pole dead time.
When setting 238 EarthFltO/C 1p to stages together, parameter 3103 BLOCK 1pDeadTim becomes
visible; the parameters for phase-selective blocking are hidden.
Parameter 3103 BLOCK 1pDeadTim must be set to YES (presetting for devices with single-pole tripping) if a
single-pole automatic reclosure is to be performed. If not, set NO.
Setting parameter 3103 BLOCK 1pDeadTim to YES completely blocks the earth fault protection if the Open
Pole Detector has recognized a single-pole dead time. If no single-pole tripping is carried out in the protected
network, this parameter should be set to NO.
2.7.2
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Regardless of how parameter address 3103 BLOCK 1pDeadTim is set, the earth fault protection will always
be blocked during the single-pole dead time, if it has issued a trip command itself. This is necessary because
otherwise the picked up earth fault protection cannot drop out if the fault current was caused by load current.
When setting stages separat., the parameters for phase-selective blocking become visible (3116
BLK /1p 3I0>>>, 3126 BLK /1p 3I0>>, 3136 BLK /1p 3I0> and 3157 BLK /1p 3I0p), parameter
3103 BLOCK 1pDeadTim is hidden.
The parameters 3116, 3126, 3136 and 3157 are used to define which stage is to be blocked during the single-
pole dead time. If the corresponding stage is to be blocked, the setting YES remains unchanged. If not, set No
(non-dir.).
i
i
NOTE
Stages of the earth fault protection, which are not to be blocked during the single-pole dead time, will not
be blocked even if the earth fault protection itself gives a single-pole trip command. Pickup and trip
command of the earth fault protection can thus only drop out if the earth current caused by the load
current lies below the threshold value of such a stage.
Trip
When setting the power system data (Section 2.1.2.1 Setting Notes), it was specified whether single-pole trip-
ping is set for all stages of the earth fault protection together or separately.
When setting 238 EarthFltO/C 1p to stages together, parameter 3109 Trip 1pole E/F becomes
visible; the parameters for phase-selective settings are hidden.
Address 3109 Trip 1pole E/F specifies that the earth fault protection trips single-pole, provided that the
faulted phase can be determined with certainty. This address is only valid for devices that have the option to
trip single-pole. If you are using single-pole automatic reclosure, the setting YES (default setting) remains
valid. Otherwise set NO.
When setting stages separat., the parameters for the phase-selective setting are visible (3117 Trip 1p
3I0>>>, 3127 Trip 1p 3I0>>, 3137 Trip 1p 3I0> and 3158 Trip 1p 3I0p) parameter 3109 Trip
1pole E/F is hidden.
The parameters 3117, 3127, 3137and 3158 can be used to determine which stage is to trip 1-pole, provided
that the faulted phase can be determined with certainty. If the corresponding stage is to trip 1-pole, the
setting YES remains unchanged; if not, set NO.
Definite time stages
First of all, the mode for each stage is set: address 3110 Op. mode 3I0>>>, address 3120 Op. mode
3I0>> and address 3130 Op. mode 3I0>. Each stage can be set to operate Forward (usually towards line),
Reverse (usually towards busbar) or Non-Directional (in both directions). If a single stage is not
required, set its mode to Inactive.
The definite time stages 3I0>>> (address 3111), 3I0>> (address 3121) and 3I0> (address 3131) can be
used for a three-stage definite time overcurrent protection. They can also be combined with the inverse time
stage 3I0p PICKUP (address 3141, see below). The pick up thresholds should in general be selected such
that the most sensitive stage picks up with the smallest expected earth fault current.
The 3Ι0>>- and 3Ι0>>> stages are best suited for fast tripping stages (instantaneous), as these stages use an
abridged filter with shorter response time. Whereas, the stages 3Ι0> and 3Ι0P are best suited for very sensitive
earth fault detection due to their effective method of suppressing harmonics.
If no inverse time stage, but rather a fourth definite time stage is required, the “inverse time” stage can be
implemented as a definite time stage. This must already be taken regard of during the configuration of the
protection functions (see Section 2.1.1.2 Setting Notes, address 131 Earth Fault O/C = Definite
Time). For this stage, the address 3141 3I0p PICKUP then determines the current pickup threshold and
address 3147 Add.T-DELAY the definite time delay.
The values for the time delay settings T 3I0>>> (address 3112), T 3I0>> (address 3122) and T 3I0>
(address 3132) are derived from the earth fault grading coordination diagram of the system.
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During the selection of the current and time settings, regard must be taken as to whether a stage should be
direction dependent and whether it uses teleprotection. Refer also to the margin headings “Determination of
Direction” and “Teleprotection with Earth Fault Protection”.
The set time delays are pure additional delays, which do not include the operating time (measuring time).
Inverse time stage with IEC characteristic
If the fourth stage has been configured as an inverse time overcurrent stage with IEC characteristic (address
131 Earth Fault O/C = TOC IEC), you first set the mode: Address 3140 Op. mode 3I0p. This stage can
be set to operate Forward (usually towards line) or Reverse (usually towards busbar) or Non-Direc-
tional (in both directions). If the stage is not required, set its mode to Inactive.
For the inverse time overcurrent stage 3Ι0P it is possible to select from a variety of characteristics depending on
the version of the relay and the configuration (see Section 2.1.1.2 Setting Notes, address 131). If an inverse
time overcurrent stage is not required, set address 131 Earth Fault O/C = Definite Time. The 3Ι0P
stage can then be used as a fourth definite time stage (refer to “Definite Time Stages” above) or deactivated.
With IEC characteristics (address 131 Earth Fault O/C = TOC IEC) the following options are available in
address 3151 IEC Curve:
Normal Inverse ((inverse, type A according to IEC 60255-3),
Very Inverse (very inverse, type B according to IEC 60255-3),
Extremely Inv. (extremely inverse, type C according to IEC 60255-3) und
LongTimeInverse ((long inverse, type B according to IEC 60255-3).
The characteristics and equations they are based on are listed in the Technical Data.
The setting of the pickup threshold 3I0p PICKUP (address 3141) is similar to the setting of definite time
stages (see above). In this case it must be noted that a safety margin between the pickup threshold and the
set value has already been incorporated. Pickup only occurs at a current which is approximately 10 % above
the set value.
The time multiplier setting 3I0p Time Dial (address 3143) is derived from the grading coordination chart
which was set up for earth faults in the system.
In addition to the inverse time delay, a constant (fixed length) time delay can also be set if this is required. The
setting Add.T-DELAY (address 3147) is added to the time of the set characteristic.
During the selection of the current and time settings, regard must be taken as to whether a stage should be
direction dependent and whether it uses teleprotection. Refer also to the margin headings “Determination of
Direction” and “Teleprotection with Earth Fault Protection”.
Inverse Time Current Stage with ANSI Characteristic
If the fourth stage has been configured as an inverse time overcurrent stage with ANSI characteristic (address
131 Earth Fault O/C = TOC ANSI), you first set the mode: Address 3140 Op. mode 3I0p. This stage
can be set to operate Forward (usually towards line) or Reverse (usually towards busbar) or Non-Direc-
tional (in both directions). If the stage is not required, set its mode to Inactive.
For the inverse time overcurrent stage 3Ι0P it is possible to select from a variety of characteristics depending on
the version of the relay and the configuration (Section 2.1.1 Functional Scope, address 131). If an inverse time
overcurrent stage is not required, set address 131 Earth Fault O/C = Definite Time. The 3Ι0P stage can
then be used as a fourth definite time stage (refer to “Definite Time Stages” above). With ANSI characteristics
(address 131 Earth Fault O/C = TOC ANSI) the following options are available in address 3152 ANSI
Curve:
Inverse,
Short Inverse,
Long Inverse,
Moderately Inv.,
Very Inverse,
Extremely Inv.,
Definite Inv..
The characteristics and equations they are based on are listed in the Technical Data.
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The setting of the pickup threshold 3I0p PICKUP (address 3141) is similar to the setting of definite time
stages (see above). In this case it must be noted that a safety margin between the pickup threshold and the
set value has already been incorporated. Pickup only occurs at a current which is approximately 10 % above
the set value.
The time multiplier setting 3I0p Time Dial (address 3144) is derived from the grading coordination chart
which was set up for earth faults in the system.
In addition to the inverse time delay, a constant (fixed length) time delay can also be set if this is required. The
setting Add.T-DELAY (address 3147) is added to the time of the set curve.
During the selection of the current and time settings, regard must be taken as to whether a stage should be
direction dependent and whether it uses teleprotection. Refer also to the margin headings “Determination of
Direction”“ and “Teleprotection with Earth Fault Protection”.
Inverse time stage with logarithmic inverse characteristic
If you have configured the inverse time overcurrent stage with logarithmic inverse characteristic (address 131
Earth Fault O/C = TOC Logarithm.), you set the operating mode first: Address 3140 Op. mode 3I0p.
This stage can be set to operate Forward (usually towards line) or Reverse (usually towards busbar) or Non-
Directional (in both directions). If the stage is not required, set its mode to Inactive.
For the logarithmic inverse characteristic (address 131 Earth Fault O/C = TOC Logarithm.) address
3153 LOG Curve = Log. inverse.
The characteristic and the formula on which it is based can be found in the Technical Data.
Figure 2-82 illustrates the influence of the most important setting parameters on the curve. 3I0p PICKUP
(address 3141) is the reference value for all current values, while 3I0p Startpoint (address 3154) deter-
mines the beginning of the curve, i.e. the lowest operating range on the current axis (referred to 3I0p
PICKUP). The timer setting 3I0p MaxT-DELAY (address 3146) determines the starting point of the curve
(for 3Ι0 = 3I0p PICKUP). The time factor 3I0p Time Dial (address 3145) changes the slope of the curve.
For large currents, 3I0p MinT-DELAY (address 3142) determines the lower limit on the time axis. For
currents larger than 35 · 3I0p PICKUP the operating time no longer decreases.
Finally, at address 3147 Add.T-DELAY a fixed time delay can be set as was done for the other curves.
During the selection of the current and time settings, regard must be taken as to whether a stage should be
direction dependent and whether it uses teleprotection. Refer also to the margin headings “Determination of
Direction” and “Teleprotection with Earth Fault Protection”.
[erdkurzschl-kennl-param-log-inv-kennl-oz-010802, 1, en_GB]
Figure 2-82 Curve parameters in the logarithmic–inverse characteristic
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Zero-Sequence Voltage-controlled Stage with Inverse Characteristic
If you have configured the zero-sequence voltage controlled stage (address 131 Earth Fault O/C = U0
inverse), you set the operating mode first: Address 3140 Op. mode 3I0p. This stage can be set to operate
Forward (usually towards line) or Reverse (usually towards busbar) or Non-Directional (in both direc-
tions). If the stage is not required, set its mode to Inactive.
Address 3141 3I0p PICKUP indicates the minimum current value above which this stage is required to
operate. The value must be exceeded by the minimum earth fault current value.
The voltage-controlled characteristic is based on the following formula:
[formel-erdkurzschl-abh-nullspg-inv-kennl-oz-010802, 1, en_GB]
U0 is the actual zero-sequence voltage. U0 min is the setting value U0inv. minimum (address 3183). Please
take into consideration that the formula is based on the zero-sequence voltage U0, not on 3U0. The function is
illustrated in the Technical Data.
Figure 2-83 shows the most important parameters. U0inv. minimum displaces the voltage-controlled char-
acteristic in direction of 3U0. The set value is the asymptote for this characteristic (t → ∞). In Figure 2-83, a'
shows an asymptote that belongs to the characteristic a.
The minimum voltage 3U0>(U0 inv) (address 3182) is the lower voltage threshold. It corresponds to the
line c in Figure 2-83. In characteristic b (asymptote not drawn) the curve is cut by the minimum voltage
3U0>(U0 inv) (line c).
In address 3184, an additional time T forw. (U0inv) that is added to the voltage-controlled characteristic
can be set for directional-controlled tripping.
With the non-directional time T rev. (U0inv) (address 3185) a non-directional back-up stage can be
generated.
[erdkurzschl-kennl-param-abh-nullspg-stufe-oz-010802, 1, en_GB]
Figure 2-83 Characteristic settings of the zero-sequence voltage time-dependent stage — without addi-
tional times
Zero-sequence power stage
If you have configured the fourth stage as zero-sequence power stage (address 131 Earth Fault O/C = Sr
inverse), set the mode first: Address 3140 Op. mode 3I0p. This stage can be set to operate Forward
(usually towards line) or Reverse (usually towards busbar) or Non-Directional (in both directions). If the
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stage is not required, set its mode to Inactive. The zero-sequence power protection is to operate always in
line direction.
Address 3141 3I0p PICKUP indicates the minimum current value above which this stage is required to
operate. The value must be exceeded by the minimum earth fault current value.
The zero-sequence power Sr is calculated according to the formula:
Sr = 3Ι0 · 3U0 · cos(φ – φcomp)
The angle ϕcomp is set as maximum-sensitivity angle at address 3168 PHI comp. It refers to the zero-sequence
voltage in relation to the zero-sequence current. The default setting 255° thus corresponds to a zero-sequence
impedance angle of 75° (255° – 180°). Refer also to margin heading “Zero-Sequence Power Protection”.
The trip time depends on the zero sequence power according to the following formula:
[formel-ausloese-t-nullleistung-wlk-090902, 1, en_GB]
Where Sr is the compensated power according to above formula. Sref is the setting value S ref (address
3156), that indicates the pickup value of the stage at ϕ = ϕcomp. Factor k (address 3155) can be set to displace
the zero-sequence time characteristic in time direction, the reference value S ref can be set for displacement
in power direction.
The time setting Add.T-DELAY (address 3147) allows an additional power-independent delay time to be set.
Direction determination
The direction of each required stage was already determined when setting the different stages.
According to the requirements of the application, the directionality of each stage is individually selected. If, for
instance, a directional earth fault protection with a non-directional back-up stage is required, this can be
implemented by setting the 3Ι 0>> stage directional with a short or no delay time and the 3Ι 0> stage with the
same pickup threshold, but a longer delay time as directional backup stage. The 3Ι 0>>> stage could be applied
as an additional high set instantaneous stage.
If a stage is to operate with teleprotection according to Section 2.8 Teleprotection for earth fault overcurrent
protection (optional) , it may operate without delay in conjunction with a permissive scheme. In the blocking
scheme, a short delay equal to the signal transmission time, plus a small reserve margin of approx. 20 ms is
sufficient.
Direction determination of the overcurrent stages usually uses the earth current as measured quantity Ι E = –3
Ι 0, whose angle is compared with a reference quantity. The desired reference quantity is set in POLARIZA-
TION (address 3160):
The default setting U0 + IY or U2 is universal. The device then selects automatically whether the refer-
ence quantity is composed of the zero-sequence voltage plus the transformer starpoint current, or whether
the negative- sequence voltage is used, depending on which quantity prevails. You can even apply this setting
when no transformer starpoint current Ι Y is connected to the device since an unconnected current does not
have any effect.
The setting U0 + IY can also be applied with or without transformer starpoint current connected.
If the direction determination must be carried out using only Ι Y as reference signal, apply the setting with
IY only . This makes sense if a reliable transformer starpoint current Ι Y is always available at the device
input Ι 4. The direction determination is then not influenced by disturbances in the secondary circuit of the
voltage transformers. This presupposes that the device is equipped with a current input Ι 4 of normal sensi-
tivity and that the current from the transformer starpoint infeed is connected to Ι 4.
If direction determination is to be carried out using exclusively the negative sequence system signals 3 Ι 2 and
3 U 2, the setting with U2 and I2 is applied. In this case, only the negative-sequence signals calculated by
the device are used for direction determination. In that case, the device does not require any zero-sequence
signals for direction determination.
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If you are using the zero-sequence power protection (address 131 Earth Fault O/C = Sr inverse ), it
is reasonable to conduct the direction determination also via the zero-sequence power. In this case, apply the
option zero seq. power for POLARIZATION .
Finally, the threshold values of the reference quantities must be set. 3U0> (address 3164) determines the
minimum operating voltage for direction determination with U 0. If U 0 is not used for the direction determina-
tion, this setting is of no consequence. The set threshold should not be exceeded by asymmetries in the opera-
tional measured voltage. The setting value relates to the triple zero-sequence voltage, that is
3·U 0 = | U L1 + U L2 + U L3 |
If the voltage-controlled characteristic (U0 inverse) is used as directional stage, it is reasonable for the
minimum polarizing voltage to use a value that is equal to or below the minimum voltage of the voltage-
controlled characteristic (address 3182).
Only if you have set in the P.System Data 1 (see Section 2.1.2.1 Setting Notes ) the connection of the
fourth current transformer I4 transformer (address 220) = IY starpoint , address 3165 IY> will
appear. It is the lower threshold for the current measured in the starpoint of a source transformer. A relatively
sensitive setting can be applied for this value, as the measurement of the starpoint current is quite accurate by
nature.
If the direction determination must be carried out with the negative sequence system signals, the setting
values 3U2> (address 3166) and 3I2> (address 3167) are decisive for the lower limit of the direction deter-
mination. The setting values must in this case also be selected such that operational asymmetry in the system
does not lead to a pickup.
If you are using the zero-sequence power protection and the fault direction is determined on the basis of the
zero-sequence power, address 3169 S forward indicates the value of the compensated zero-sequence
power above which the direction is recognized as forward. This value should be smaller than the reference
power S ref (address 3156, see paragraph “Zero-Sequence Power Stage”). This ensures the availability of
direction determination even with smaller zero-sequence power conditions.
The position of the directional characteristic can be changed in dependence on the selected method of direc-
tion determination (address 3160 POLARIZATION , see above). All methods based on angle measurement
between measured signal and reference signal (i.e. all methods except POLARIZATION = zero seq.
power ), allow the angle range of the direction determination to be changed with the setting angles Dir.
ALPHA and Dir. BETA (addresses 3162 and 3163). This parameter can only be changed in DIGSI at Display
Additional Settings. As these set values are not critical, the presettings may be left unchanged. If you want to
change these values, refer to margin heading “Direction Determination with Zero-Sequence System” for the
angle determination.
The direction determination POLARIZATION with zero seq. power determines the directional character-
istic by means of the compensation angle PHI comp (address 3168) which indicates the symmetry axis of
the directional characteristic. This value is also not critical for direction determination. For information on the
angle definition, refer to margin heading “Direction Determination with Zero-Sequence Power”. This angle
determines at the same time the maximum sensitivity of the zero-sequence power stage thus also affecting
indirectly the trip time as described above (margin heading “Zero-Sequence Power Stage”).
The ancillary function for increased directional sensitivity for long lines is set with parameter 3186 3U0<
forward . With default setting 0, the ancillary function is disabled. This parameter can only be altered in
DIGSI at Display Additional Settings.
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[netz-1pol-erdkurzschluss-20101104, 1, en_GB]
Figure 2-84 Power system diagram and symmetrical components for a single-pole earth fault in reverse
direction
Z1A, Z2A, Z0A Source impedance side A, symmetrical components
Z1B, Z2B, Z0B Source impedance side B, symmetrical components
ZL, Z0L Line impedance, positive sequence and zero-
sequence impedance
ZF Fault impedance
For the protection of lines whose zero-sequence impedance is significantly higher than the infeed zero-
sequence impedance (Z 0L + Z 0B > Z 0A in Figure 2-84 ), the following setting is recommended for param-
eter3186 3U0< forward :
3U0< forward = 0.8 * 3I0> ·(lowest directional stage)·* Z 0L
Additional safety can be obtained through the zero-sequence impedance of the infeed at the opposite line
end, which is not taken into account in the formula (Z 0B in Figure 2-84 ).
In lines with series compensation, it is possible to compensate the negative influence of the series capacitor
on the directional determination of the earth fault protection. For this purpose, the reactance of the series
capacitor must be entered in parameter 3187 XserCap . To prevent the compensation from falsifying the
direction measurement in case of reverse faults, the parameter 3187 XserCap must be set lower or equal to
the zerosequence reactance of the line.
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For lines without series compensation, do not change the default setting 0 of parameter XserCap (address
3187). The voltage U P used for directional determination remains unchanged in this case.
Teleprotection with earth fault protection
The earth fault protection in the 7SA522 may be expanded to a directional comparison protection using the
integrated teleprotection logic. Additional information regarding the available teleprotection schemes and
their modes of operation may be obtained from Section 2.8 Teleprotection for earth fault overcurrent protec-
tion (optional). If this is to be used, certain preconditions must already be observed when setting the earth
current stage.
Initially, it must be determined which stage is to operate in conjunction with the teleprotection scheme. This
stage must be set directional in the line direction. If, for example, the 3Ι0 stage should operate as directional
comparison, set address 3130 Op. mode 3I0> = Forward (see above “Definite Time Stages”).
Furthermore, the device must be informed that the applicable stage functions together with the teleprotec-
tion to allow undelayed release of the tripping during internal faults. For the 3Ι0> stage this means that
address 3133 3I0> Telep/BI is set to YES. The time delay T 3I0> set for this stage (address 3132) then
functions as a back-up stage, e.g. during failure of the signal transmission. For the remaining stages the corre-
sponding parameter is set to NO, therefore, in this example: address 3123 3I0>> Telep/BI for stage 3Ι0>>,
address 3113 3I0>>> Telep/BI for stage 3Ι0>>>, address 3148 3I0p Telep/BI for stage 3Ι0P (if used).
If the echo function is used in conjunction with the teleprotection scheme, or if the weak-infeed tripping func-
tion should be used, the additional teleprotection stage 3IoMin Teleprot (address 3105) must be set to
avoid unselective tripping during through-fault earth current measurement. For further information, see
Section 2.8 Teleprotection for earth fault overcurrent protection (optional), margin heading “Earth Fault
Protection Prerequisites”.
Switching onto an earth fault
It is possible to determine with a setting which stage trips without delay following closure onto a dead fault.
The parameters 3I0>>>SOTF-Trip (address 3114), 3I0>> SOTF-Trip (address 3124), 3I0> SOTF-Trip
(address 3134) and, if necessary, 3I0p SOTF-Trip (address 3149) are available for the stages and can be
set to YES or NO for each stage. Selection of the most sensitive stage is usually not reasonable as a solid short-
circuit may be assumed following switching onto a fault, whereas the most sensitive stage often also has to
detect high resistance faults. It is important to avoid that the selected stage picks up due to transients during
line energization.
On the other hand, it does not matter if a selected stage may pick up due to inrush conditions on trans-
formers. The switch-onto-fault tripping by a stage is blocked by the inrush stabilization even if it is set as
instantaneous switch-onto-fault stage.
To avoid a spurious pickup due to transient overcurrents, the delay SOTF Time DELAY (address 3173) can be
set. Usually, the default setting 0 can be retained. In the case of long cables, where large peak inrush currents
can occur, a short delay may be useful. The time delay depends on the severity and duration of the transient
overcurrents as well as on which stages were selected for the fast switch onto fault clearance.
With the parameter SOTF Op. Mode (address 3172) it is finally possible to determine whether the fault
direction must be checked (PICKUP+DIRECT.) or not (PICKUP), before a switch-onto-fault tripping is gener-
ated. It is the direction setting for each stage that applies for this direction check.
Phase current stabilization
To avoid spurious pickup of the stages in the case of asymmetrical load conditions or varying current trans-
former measuring errors in earthed systems, the earth current stages are restrained by the phase currents: as
the phase currents increase, the pickup thresholds are increased. By means of the setting in address 3104
Iph-STAB. Slope the preset value of 10 % for all stages can be jointly changed for all stages. This param-
eter can only be changed in DIGSI at Display Additional Settings.
Inrush restraint
The inrush restraint is only required if the device is applied to transformer feeders or on lines that end on a
transformer; in this case also only for such stages that have a pickup threshold below the inrush current and
have a very short or zero delay. The parameters 3I0>>>InrushBlk (address 3115), 3I0>> InrushBlk
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(address 3125), 3I0> InrushBlk (address 3135) and 3I0p InrushBlk (Aadress 3150) can be set to YES
(inrush restraint active) or NO (inrush restraint inactive) for each stage. If the inrush restraint has been disa-
bled for all stages, the following parameters are of no consequence.
For the recognition of the inrush current, the portion of second harmonic current content referred to the
fundamental current component can be set in address 3170 2nd InrushRest. Above this threshold the
inrush blocking is effective. The preset value (15 %) should be sufficient in most cases. Lower values imply
higher sensitivity of the inrush blocking (smaller portion of second harmonic current results in blocking).
In applications on transformer feeders or lines that are terminated on transformers it may be assumed that, if
very large currents occur, a short-circuit has occurred before the transformer. In the event of such large
currents, the inrush restraint is inhibited. This threshold value which is set in the address 3171 Imax
InrushRest, should be larger than the maximum expected inrush current (RMS value).
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
3101 FCT EarthFltO/C ON
OFF
ON Earth Fault overcurrent
function
3102 BLOCK for Dist. every PICKUP
1phase PICKUP
multiph. PICKUP
NO
every PICKUP Block E/F for Distance
protection
3103 BLOCK 1pDeadTim YES
NO
YES Block E/F for 1pole Dead
time
3104A Iph-STAB. Slope 0 .. 30 % 10 % Stabilisation Slope with
Iphase
3105 3IoMin Teleprot 1A 0.01 .. 1.00 A 0.50 A 3Io-Min threshold for Tele-
prot. schemes
5A 0.05 .. 5.00 A 2.50 A
3105 3IoMin Teleprot 1A 0.003 .. 1.000 A 0.500 A 3Io-Min threshold for Tele-
prot. schemes
5A 0.015 .. 5.000 A 2.500 A
3109 Trip 1pole E/F YES
NO
YES Single pole trip with earth
flt.prot.
3110 Op. mode 3I0>>> Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3111 3I0>>> 1A 0.05 .. 25.00 A 4.00 A 3I0>>> Pickup
5A 0.25 .. 125.00 A 20.00 A
3112 T 3I0>>> 0.00 .. 30.00 sec; ∞ 0.30 sec T 3I0>>> Time delay
3113 3I0>>> Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3114 3I0>>>SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
3115 3I0>>>InrushBlk NO
YES
NO Inrush Blocking
3116 BLK /1p 3I0>>> YES
No (non-dir.)
YES Block 3I0>>> during 1pole
dead time
2.7.3
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Addr. Parameter C Setting Options Default Setting Comments
3117 Trip 1p 3I0>>> YES
NO
YES Single pole trip with
3I0>>>
3120 Op. mode 3I0>> Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3121 3I0>> 1A 0.05 .. 25.00 A 2.00 A 3I0>> Pickup
5A 0.25 .. 125.00 A 10.00 A
3122 T 3I0>> 0.00 .. 30.00 sec; ∞ 0.60 sec T 3I0>> Time Delay
3123 3I0>> Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3124 3I0>> SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
3125 3I0>> InrushBlk NO
YES
NO Inrush Blocking
3126 BLK /1p 3I0>> YES
No (non-dir.)
YES Block 3I0>> during 1pole
dead time
3127 Trip 1p 3I0>> YES
NO
YES Single pole trip with 3I0>>
3130 Op. mode 3I0> Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3131 3I0> 1A 0.05 .. 25.00 A 1.00 A 3I0> Pickup
5A 0.25 .. 125.00 A 5.00 A
3131 3I0> 1A 0.003 .. 25.000 A 1.000 A 3I0> Pickup
5A 0.015 .. 125.000 A 5.000 A
3132 T 3I0> 0.00 .. 30.00 sec; ∞ 0.90 sec T 3I0> Time Delay
3133 3I0> Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3134 3I0> SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
3135 3I0> InrushBlk NO
YES
NO Inrush Blocking
3136 BLK /1p 3I0> YES
No (non-dir.)
YES Block 3I0> during 1pole
dead time
3137 Trip 1p 3I0> YES
NO
YES Single pole trip with 3I0>
3140 Op. mode 3I0p Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3140 Op. mode 3I0p Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Addr. Parameter C Setting Options Default Setting Comments
3140 Op. mode 3I0p Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3140 Op. mode 3I0p Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3141 3I0p PICKUP 1A 0.05 .. 25.00 A 1.00 A 3I0p Pickup
5A 0.25 .. 125.00 A 5.00 A
3141 3I0p PICKUP 1A 0.003 .. 25.000 A 1.000 A 3I0p Pickup
5A 0.015 .. 125.000 A 5.000 A
3141 3I0p PICKUP 1A 0.003 .. 25.000 A 1.000 A 3I0p Pickup
5A 0.015 .. 125.000 A 5.000 A
3141 3I0p PICKUP 1A 0.05 .. 25.00 A 1.00 A 3I0p Pickup
5A 0.25 .. 125.00 A 5.00 A
3141 3I0p PICKUP 1A 0.003 .. 25.000 A 1.000 A 3I0p Pickup
5A 0.015 .. 125.000 A 5.000 A
3141 3I0p PICKUP 1A 0.05 .. 25.00 A 1.00 A 3I0p Pickup
5A 0.25 .. 125.00 A 5.00 A
3141 3I0p PICKUP 1A 0.003 .. 25.000 A 1.000 A 3I0p Pickup
5A 0.015 .. 125.000 A 5.000 A
3141 3I0p PICKUP 1A 0.05 .. 25.00 A 1.00 A 3I0p Pickup
5A 0.25 .. 125.00 A 5.00 A
3142 3I0p MinT-DELAY 0.00 .. 30.00 sec 1.20 sec 3I0p Minimum Time Delay
3143 3I0p Time Dial 0.05 .. 3.00 sec; ∞ 0.50 sec 3I0p Time Dial
3144 3I0p Time Dial 0.50 .. 15.00 ; ∞ 5.00 3I0p Time Dial
3145 3I0p Time Dial 0.05 .. 15.00 sec; ∞ 1.35 sec 3I0p Time Dial
3146 3I0p MaxT-DELAY 0.00 .. 30.00 sec 5.80 sec 3I0p Maximum Time Delay
3147 Add.T-DELAY 0.00 .. 30.00 sec; ∞ 1.20 sec Additional Time Delay
3147 Add.T-DELAY 0.00 .. 30.00 sec; ∞ 1.20 sec Additional Time Delay
3147 Add.T-DELAY 0.00 .. 30.00 sec; ∞ 1.20 sec Additional Time Delay
3147 Add.T-DELAY 0.00 .. 30.00 sec; ∞ 1.20 sec Additional Time Delay
3148 3I0p Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3148 3I0p Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3148 3I0p Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3148 3I0p Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
3149 3I0p SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
3149 3I0p SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
3149 3I0p SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Addr. Parameter C Setting Options Default Setting Comments
3149 3I0p SOTF-Trip NO
YES
NO Instantaneous trip after
SwitchOnToFault
3150 3I0p InrushBlk NO
YES
NO Inrush Blocking
3150 3I0p InrushBlk NO
YES
NO Inrush Blocking
3150 3I0p InrushBlk NO
YES
NO Inrush Blocking
3150 3I0p InrushBlk NO
YES
NO Inrush Blocking
3151 IEC Curve Normal Inverse
Very Inverse
Extremely Inv.
LongTimeInverse
Normal Inverse IEC Curve
3152 ANSI Curve Inverse
Short Inverse
Long Inverse
Moderately Inv.
Very Inverse
Extremely Inv.
Definite Inv.
Inverse ANSI Curve
3153 LOG Curve Log. inverse Log. inverse LOGARITHMIC Curve
3154 3I0p Startpoint 1.0 .. 4.0 1.1 Start point of inverse char-
acteristic
3155 k 0.00 .. 3.00 sec 0.50 sec k-factor for Sr-character-
istic
3156 S ref 1A 1 .. 100 VA 10 VA S ref for Sr-characteristic
5A 5 .. 500 VA 50 VA
3157 BLK /1p 3I0p YES
No (non-dir.)
YES Block 3I0p during 1pole
dead time
3157 BLK /1p 3I0p YES
No (non-dir.)
YES Block 3I0p during 1pole
dead time
3157 BLK /1p 3I0p YES
No (non-dir.)
YES Block 3I0p during 1pole
dead time
3157 BLK /1p 3I0p YES
No (non-dir.)
YES Block 3I0p during 1pole
dead time
3158 Trip 1p 3I0p YES
NO
YES Single pole trip with 3I0p
3158 Trip 1p 3I0p YES
NO
YES Single pole trip with 3I0p
3158 Trip 1p 3I0p YES
NO
YES Single pole trip with 3I0p
3158 Trip 1p 3I0p YES
NO
YES Single pole trip with 3I0p
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Addr. Parameter C Setting Options Default Setting Comments
3160 POLARIZATION U0 + IY or U2
U0 + IY
with IY only
with U2 and I2
zero seq. power
U0 + IY or U2 Polarization
3162A Dir. ALPHA 0 .. 360 ° 338 ° ALPHA, lower angle for
forward direction
3163A Dir. BETA 0 .. 360 ° 122 ° BETA, upper angle for
forward direction
3164 3U0> 0.5 .. 10.0 V 0.5 V Min. zero seq.voltage 3U0
for polarizing
3165 IY> 1A 0.05 .. 1.00 A 0.05 A Min. earth current IY for
polarizing
5A 0.25 .. 5.00 A 0.25 A
3166 3U2> 0.5 .. 10.0 V 0.5 V Min. neg. seq. polarizing
voltage 3U2
3167 3I2> 1A 0.05 .. 1.00 A 0.05 A Min. neg. seq. polarizing
current 3I2
5A 0.25 .. 5.00 A 0.25 A
3168 PHI comp 0 .. 360 ° 255 ° Compensation angle PHI
comp. for Sr
3169 S forward 1A 0.1 .. 10.0 VA 0.3 VA Forward direction power
threshold
5A 0.5 .. 50.0 VA 1.5 VA
3170 2nd InrushRest 10 .. 45 % 15 % 2nd harmonic ratio for
inrush restraint
3171 Imax InrushRest 1A 0.50 .. 25.00 A 7.50 A Max.Current, overriding
inrush restraint
5A 2.50 .. 125.00 A 37.50 A
3172 SOTF Op. Mode PICKUP
PICKUP+DIRECT.
PICKUP+DIRECT. Instantaneous mode after
SwitchOnToFault
3173 SOTF Time DELAY 0.00 .. 30.00 sec 0.00 sec Trip time delay after SOTF
3174 BLK for DisZone in zone Z1
in zone Z1/Z1B
in each zone
in each zone Block E/F for Distance
Protection Pickup
3182 3U0>(U0 inv) 1.0 .. 10.0 V 5.0 V 3U0> setpoint
3183 U0inv. minimum 0.1 .. 5.0 V 0.2 V Minimum voltage U0min
for T->oo
3184 T forw. (U0inv) 0.00 .. 32.00 sec 0.90 sec T-forward Time delay
(U0inv)
3185 T rev. (U0inv) 0.00 .. 32.00 sec 1.20 sec T-reverse Time delay
(U0inv)
3186A 3U0< forward 0.1 .. 10.0 V; 0 0.0 V 3U0 min for forward direc-
tion
3187A XserCap 1A 0.000 .. 600.000 Ω 0.000 Ω Reactance X of series
capacitor
5A 0.000 .. 120.000 Ω 0.000 Ω
Information List
No. Information Type of
Informa-
tion
Comments
1305 >EF BLK 3I0>>> SP >Earth Fault O/C Block 3I0>>>
2.7.4
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
166 SIPROTEC 4, 7SA522, Manual
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No. Information Type of
Informa-
tion
Comments
1307 >EF BLOCK 3I0>> SP >Earth Fault O/C Block 3I0>>
1308 >EF BLOCK 3I0> SP >Earth Fault O/C Block 3I0>
1309 >EF BLOCK 3I0p SP >Earth Fault O/C Block 3I0p
1310 >EF InstTRIP SP >Earth Fault O/C Instantaneous trip
1331 E/F Prot. OFF OUT Earth fault protection is switched OFF
1332 E/F BLOCK OUT Earth fault protection is BLOCKED
1333 E/F ACTIVE OUT Earth fault protection is ACTIVE
1335 EF TRIP BLOCK OUT Earth fault protection Trip is blocked
1336 E/F L1 selec. OUT E/F phase selector L1 selected
1337 E/F L2 selec. OUT E/F phase selector L2 selected
1338 E/F L3 selec. OUT E/F phase selector L3 selected
1345 EF Pickup OUT Earth fault protection PICKED UP
1354 EF 3I0>>>Pickup OUT E/F 3I0>>> PICKED UP
1355 EF 3I0>> Pickup OUT E/F 3I0>> PICKED UP
1356 EF 3I0> Pickup OUT E/F 3I0> PICKED UP
1357 EF 3I0p Pickup OUT E/F 3I0p PICKED UP
1358 EF forward OUT E/F picked up FORWARD
1359 EF reverse OUT E/F picked up REVERSE
1361 EF Trip OUT E/F General TRIP command
1362 E/F Trip L1 OUT Earth fault protection: Trip 1pole L1
1363 E/F Trip L2 OUT Earth fault protection: Trip 1pole L2
1364 E/F Trip L3 OUT Earth fault protection: Trip 1pole L3
1365 E/F Trip 3p OUT Earth fault protection: Trip 3pole
1366 EF 3I0>>> TRIP OUT E/F 3I0>>> TRIP
1367 EF 3I0>> TRIP OUT E/F 3I0>> TRIP
1368 EF 3I0> TRIP OUT E/F 3I0> TRIP
1369 EF 3I0p TRIP OUT E/F 3I0p TRIP
1370 EF InrushPU OUT E/F Inrush picked up
14080 E/F 3I0>>>BLOCK OUT E/F 3I0>>> is blocked
14081 E/F 3I0>> BLOCK OUT E/F 3I0>> is blocked
14082 E/F 3I0> BLOCK OUT E/F 3I0> is blocked
14083 E/F 3I0p BLOCK OUT E/F 3I0p is blocked
Functions
2.7 Earth fault overcurrent protection in earthed systems (optional)
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Teleprotection for earth fault overcurrent protection (optional)
General
With the aid of the integrated comparison logic, the directional earth fault protection according to Section
2.7 Earth fault overcurrent protection in earthed systems (optional) can be expanded to a directional compar-
ison protection scheme.
Transmission Modes
One of the stages which must be directional Forward is used for the directional comparison. This stage can
only trip rapidly if a fault is also detected in the forward direction at the other line end. A release (unblock)
signal or a block signal can be transmitted.
The following permissive teleprotection schemes are available:
•Directional comparison,
•Directional unblock scheme
and blocking scheme:
•Blocking of the directional stage
Further stages can be set as directional and/or non-directional backup stages.
Information on the effect of the phase selector on the release signals can be found in Section 2.7 Earth fault
overcurrent protection in earthed systems (optional) under margin heading “Selection of the Earth Faulted
Phase”.
Transmission Channels
For the signal transmission, one channel in each direction is required. Fibre optic connections or voice
frequency modulated high frequency channels via pilot cables, power line carrier or microwave radio links can
be used for this purpose. If the same transmission channel is used as for the transmission by the distance
protection, the transmission mode must also be the same!
If the device is equipped with an optional protection data interface, digital communication lines can be used
for signal processing; these include: Fibre optic cables, communication networks or dedicated lines. The
following teleprotection scheme is suited for “Directional comparison”.
7SA522 allows also the transmission of phase-segregated signals. This has the advantage that single-pole
automatic reclosure can be carried out even when two single-phase faults occur on different lines in the
system.
When using the digital protection data interface, signal transmission is always phase-selective. If no single-
phase fault is detected, the signals are transmitted for all three phases.
With earth fault protection, phase-selective transmission only makes sense if the earth faulted phase is identi-
fied by means of the phase selector (address 3109 Trip 1pole E/F to YES, refer also to Section 2.7 Earth
fault overcurrent protection in earthed systems (optional) under “Tripping”).
The signal transmission schemes are also suited to three terminal lines (teed feeders). In this case, signal
transmission channels are required from each of the three ends to each of the others in both directions. Phase
segregated transmission is only possible for three terminal line applications if digital communication channels
are used.
During disturbances on the transmission path, the teleprotection supplement may be blocked. With conven-
tional signal transmission schemes, the disturbance is signalled by a binary input, with digital communication
it is detected automatically by the protection device.
Activation and Deactivation
The comparison function can be switched on and off by means of the parameter 3201 FCT Telep. E/F, via
the system interface (if available) and via binary inputs (if allocated). The switch states are saved internally
(refer to Figure 2-85) and secured against loss of auxiliary supply. It is only possible to switch on from the
2.8
2.8.1
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
168 SIPROTEC 4, 7SA522, Manual
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source from where it had previously been switched off. To be active, it is necessary that the function is
switched on from all three switching sources.
[ein-aus-schalten-signalzus-wlk-300702, 1, en_GB]
Figure 2-85 Activation and deactivation of the signal transmission logic
Directional Comparison Pickup
The following procedure is suited for both conventional and digital transmission media.
Principle
The directional comparison scheme is a permissive scheme. The scheme functionality is shown in Figure 2-86.
When the earth fault protection recognizes a fault in the forward direction, it initially sends a permissive signal
to the opposite line end. If a permissive signal is also received from the opposite end, a trip signal is routed to
the trip logic. Accordingly it is a prerequisite for fast tripping that the fault is recognized in the forward direc-
tion at both line ends.
The send signal can be prolonged by TS (settable). The prolongation of the send signal only comes into effect
if the protection has already issued a trip command. This ensures that the permissive signal releases the oppo-
site line end even if the earth fault is very rapidly cleared by a different independent protection.
[funktionsschema-richtungsvergleichsverfahrens-wlk-300702, 1, en_GB]
Figure 2-86 Operation scheme of the directional comparison pickup
Sequence
Figure 2-87 shows the logic diagram of the directional comparison scheme for one line end.
The directional comparison only functions for faults in the “Forward” direction. Accordingly the overcurrent
stage intended for operation in the direction comparison mode must definitely be set to Forward (RICH.
3I0...); refer also to Section 2.7 Earth fault overcurrent protection in earthed systems (optional) under
margin heading “Teleprotection with Earth Fault Protection”.
2.8.2
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signals are sent to both opposite line
ends. The receive signals are then combined with a logical AND gate, as all three line ends must transmit a
send signal during an internal fault. With the parameter Line Config. (address 3202) the device is
informed as to whether it has one or two opposite line ends.
If the parameter Teleprot. E/F (address 132) is set to SIGNALv.ProtInt and parameter NUMBER OF
RELAY (address 147) is set to 3 relays, the device is informed about two remote ends. The default setting is
2 relays, which corresponds to one remote end.
The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc-
tion reversal resulting during the clearance of faults on parallel lines, is neutralized by the “Transient Blocking”
(see margin heading “Transient Blocking”).
On lines where there is only a single-sided infeed or where the starpoint is only earthed behind one line end,
the line end without zero sequence current cannot generate a release signal as fault detection does not take
place there. To ensure tripping by the directional comparison also in this case, the device has special features.
This “Weak Infeed Function” (echo function) is referred to at the margin heading “Echo function”. It is activated
when a signal is received from the opposite line end — in the case of three terminal lines from at least one of
the opposite line ends — without the device having detected a fault.
The circuit breaker can also be tripped at the line end with no or only weak infeed. This “weak-infeed tripping”
is referred to in Section 2.9.2 Classical Tripping.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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[logikdia-ef-richtungsverglsverf-1-leitungsende-171102-wlk, 1, en_GB]
Figure 2-87 Logic diagram of the directional comparison scheme (one line end)
Figure 2-88 shows the logic diagram of the directional comparison scheme for one line end with protection
interface.
For earth fault protection, only directional comparison pickup is offered for transmission via protection inter-
face. The directional comparison pickup scheme is only effective if the parameter 132 Teleprot. E/F has
been set to SIGNALv.ProtInt in all devices of the setup. The message
Par. different
is sent in the
event of a fault.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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[logikdia-ef-richtverglsverf-1-ende-mitwss-171102-wlk, 1, en_GB]
Figure 2-88 Logic diagram of the directional comparison scheme with protection data interface (for one
device)
Directional Unblocking Scheme
The following scheme is suited for conventional transmission media.
2.8.3
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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Principle
The unblocking method is a permissive scheme. It differs from the directional comparison scheme in that trip-
ping is possible also when no release signal is received from the opposite line end. It is therefore mainly used
for long lines when the signal must be transmitted across the protected feeder by means of power line carrier
(PLC) and the attenuation of the transmitted signal at the fault location may be so severe that reception at the
other line cannot necessarily be guaranteed.
The scheme functionality is shown in Figure 2-89.
Two signal frequencies which are keyed by the transmit output of the 7SA522 are required for the transmis-
sion. If the transmission device has a channel monitoring, then the monitoring frequency f0 is keyed over to
the working frequency fU (unblocking frequency). When the protection recognizes an earth fault in the
forward direction, it initiates the transmission of the unblock frequency fU. During the quiescent state or
during an earth fault in the reverse direction, the monitoring frequency f0 is transmitted.
If a release signal is also received from the opposite end, the trip signal is forwarded to the command relay. A
pre-condition for fast fault clearance is therefore that the earth fault is recognized in the forward direction at
both line ends.
The send signal can be prolonged by TS (settable). The prolongation of the send signal only comes into effect
if the protection has already issued a trip command. This ensures that the permissive signal releases the oppo-
site line end even if the earth fault is very rapidly cleared by a different independent protection.
[funktionsschema-unblockverfahrens-ef-wlk-300702, 1, en_GB]
Figure 2-89 Operation scheme of the directional unblocking method
Sequence
Figure 2-90 shows the logic diagram of the unblocking scheme for one line end.
The directional unblocking scheme only functions for faults in the “forward” direction. Accordingly the over-
current stage intended for operation in the directional unblocking scheme must definitely be set to Forward
(RICH.3I0...); refer also to Section 2.7 Earth fault overcurrent protection in earthed systems (optional) at
the margin heading “Teleprotection with Earth Fault Protection”.
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signals are sent to both opposite line
ends. The receive signals are then combined with a logical AND gate, as all three line ends must transmit a
send signal during an internal fault. With the parameter Line Config. (address 3202) the device is
informed as to whether it has one or two opposite line ends.
An unblock logic is inserted before the receive logic, which in essence corresponds to that of the directional
comparison scheme, see Figure 2-91. If an interference free unblock signal is received, a receive signal,
e.g.
>EF UB ub 1
, appears and the blocking signal, e.g.
>EF UB bl 1
disappears. The internal signal
“Unblock 1” is passed on to the receive logic, where it initiates the release of the tripping (when all remaining
conditions have been fulfilled).
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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If the transmitted signal does not reach the other line end because the short-circuit on the protected feeder
causes too much attenuation or reflection of the transmitted signal, the unblock logic takes effect: neither the
unblocking signal
>EF UB ub 1
nor the monitoring signal
>EF UB bl 1
are received. In this case, the
release “Unblock 1” is issued after a security delay time of 20 ms and passed onto the receive logic. This
release is however removed after a further 100 ms via the timer stage 100/100 ms. When the transmission is
functional again, one of the two receive signals must appear again, either
>EF UB ub 1
or
>EF UB bl 1
;
after a further 100 ms (dropout delay of the timer stage 100/100 ms) the quiescent state is reached again, i.e.
the direct release path to the signal “Unblock 1” and thereby the usual release is possible. On three terminal
lines, the unblock logic can be controlled via both receive channels.
If none of the signals is received for a period of more than 10 s the alarm
EF TeleUB Fail1
is generated.
The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc-
tion reversal resulting during the clearance of faults on parallel lines, is neutralized by the “Transient Blocking”.
On lines where there is only a single-sided infeed or where the starpoint is only earthed behind one line end,
the line end without zero sequence current cannot generate a release signal as fault detection does not take
place there. To ensure tripping by the directional comparison also in this case, the device has special features.
This “Weak Infeed Function” is referred to in Section “Measures for Weak and Zero Infeed”. The function is acti-
vated when a signal is received from the opposite line end — in the case of three terminal lines from at least
one of the opposite line ends — without the device having detected a fault.
The circuit breaker can also be tripped at the line end with no or only weak infeed. This “weak-infeed tripping”
is referred to in Section2.9.2 Classical Tripping.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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[logikdiagramm-unblockverfs-1-ltgse-ef-wlk-300702, 1, en_GB]
Figure 2-90 Logic diagram of the unblocking scheme (one line end)
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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[unblock-logik-ef-wlk-190802, 1, en_GB]
Figure 2-91 Unblock logic
Directional Blocking Scheme
The following scheme is suited for conventional transmission media.
Principle
In the case of the blocking scheme, the transmission channel is used to send a block signal from one line end
to the other. The signal is sent as soon as the protection detects a fault in reverse direction, alternatively also
immediately after fault inception (jump detector via dotted line). It is stopped immediately as soon as the
earth fault protection detects an earth fault in forward direction. Tripping is possible with this scheme even if
no signal is received from the opposite line end. It is therefore mainly used for long lines when the signal must
be transmitted across the protected line by means of power line carrier (PLC) and the attenuation of the trans-
mitted signal at the fault location may be so severe that reception at the other line end cannot necessarily be
guaranteed.
2.8.4
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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The scheme functionality is shown in Figure 2-92.
Earth faults in the forward direction cause tripping if a blocking signal is not received from the opposite line
end. Due to possible differences in the pickup times of the devices at both line ends and due to the signal
transmission time delay, the tripping must be somewhat delayed by TV in this case.
To avoid signal race conditions, a transmit signal can be prolonged by the settable time TS once it has been
initiated.
[funktionsschema-blockierverf-ef-wlk-300702, 1, en_GB]
Figure 2-92 Operation scheme of the directional blocking method
Sequence
Figure 2-93 shows the logic diagram of the blocking scheme for one line end.
The stage to be blocked must be set to Forward (RICH. 3I0...); refer also to Section 2.7 Earth fault over-
current protection in earthed systems (optional) under margin heading “Teleprotection with Earth Fault
Protection”.
On two terminal lines, the signal transmission may be phase segregated. In this case, send and receive circuits
operate separately for each phase. On three terminal lines, the transmit signals are sent to both opposite line
ends. The receive signals are then combined with a logical OR gate as no blocking signal must be received
from any line end during an internal fault. With the parameter Line Config. (address 3202) the device is
informed as to whether it has one or two opposite line ends.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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[logikdia-blockierverf-1-ltged-ef-wlk-300702, 1, en_GB]
Figure 2-93 Logic diagram of the blocking scheme (one line end)
As soon as the earth fault protection has detected a fault in the reverse direction, a blocking signal is trans-
mitted (e.g.
EF Tele SEND
, No. 1384). The transmitted signal may be prolonged by setting address 3203
accordingly. The blocking signal is stopped if a fault is detected in the forward direction (e.g.
EF Tele BL
STOP
, No. 1389). Very rapid blocking is possible by transmitting also the output signal of the jump detector
for measured values. To do so, the output
EF Tele BL Jump
(No. 1390) must also be allocated to the trans-
mitter output relay. As this jump signal appears at every measured value jump, it should only be used if the
transmission channel can be relied upon to respond promptly to the disappearance of the transmitted signal.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc-
tion reversal resulting during the clearance of faults on parallel lines is neutralised by “Transient blocking”. The
received blocking signals also prolong the release by the transient blocking time TrBlk BlockTime (address
3210) if it has been present for at least the waiting time TrBlk Wait Time(address 3209), see Figure 2-94).
After expiration of TrBlk BlockTime (address 3210) the delay time Release Delay (address 3208) is
restarted.
It lies in the nature of the blocking scheme that single end fed short-circuits can also be tripped rapidly
without any special measures, as the non-feeding end cannot generate a blocking signal.
Transient Blocking
Transient blocking provides additional security against erroneous signals due to transients caused by clearance
of an external fault or by fault direction reversal during clearance of a fault on a parallel line.
The principle of transient blocking scheme is that following the incidence of an external fault, the formation of
a release signal is prevented for a certain (settable) time. In the case of permissive schemes, this is achieved by
blocking of the transmit and receive circuit.
Figure 2-94 shows the principle of the transient blocking.
If, following fault detection, a non-directional fault or a fault in the reverse direction is determined within the
waiting time TrBlk Wait Time (address 3209), the transmit circuit and the trip release are prevented. This
blocking is maintained for the duration of the transient blocking time TrBlk BlockTime (address 3210) also
after the reset of the blocking criterion.
With the blocking scheme the transient blocking prolongs also the received blocking signal as shown in the
logic diagram Figure 2-94. After expiration of TrBlk BlockTime (address 3210) the delay time Release
Delay (address3208) is restarted
[trans-block-freigabe-ef-wlk-300702, 1, en_GB]
Figure 2-94 Transient blocking
Measures for Weak or Zero Infeed
On lines where there is only a single-sided infeed or where the starpoint is only earthed behind one line end,
the line end without zero sequence current cannot generate a permissive signal, as fault detection does not
take place there. With the comparison schemes, using a permissive signal, fast tripping could not even be
achieved at the line end with strong infeed without special measures, as the end with weak infeed does not
transmit a permissive release signal.
To achieve rapid tripping at both line ends under these conditions, the device has a special supplement for
lines with weak zero sequence infeed.
2.8.5
2.8.6
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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To enable even the line end with the weak infeed to trip, 7SA6 provides a weak infeed tripping supplement. As
this is a separate protection function with a dedicated trip command, it is described separately in Section
2.9.2 Classical Tripping.
Echo Function
The received signal at the line end that has no earth current is returned to the other line end as an “echo” by
the echo function. The received echo signal at the other line end enables the release of the trip command.
The common echo signal (see Figure , Section 2.9.1 Echo function) is triggered by both the earth fault protec-
tion and the distance protection. Figure 2-127 shows the generation of the echo release by the earth fault
protection.
The detection of the weak infeed condition and accordingly the requirement for an echo are combined in a
central AND gate. The earth fault protection must neither be switched off nor blocked, as it would otherwise
always produce an echo due to the missing fault detection.
The essential condition for an echo is the absence of an earth current (current stage 3IoMin Teleprot)
with simultaneous receive signal from the teleprotection scheme logic, as shown in the corresponding logic
diagrams (Figure 2-87, , Figure 2-88 or Figure 2-90).
To prevent the generation of an echo signal after the line has been tripped and the earth current stage
3IoMin Teleprot has reset, it is not possible to generate an echo if a fault detection by the earth current
stage had already been present (RS flip-flop in Figure 2-95). The echo can in any event be blocked via the
binary input
>EF BlkEcho
.
The following figure shows the generation of the echo release signal. Since this function is also associated
with the weak infeed tripping, it is described separately (see Section 2.9.1 Echo function).
[logikdia-echo-ef-signal-skg-300702, 1, en_GB]
Figure 2-95 Generation of the echo release signal
Setting Notes
General
The teleprotection supplement for earth fault protection is only operational if it was set to one of the available
modes during the configuration of the device (address 132). Depending on this configuration, only those
parameters which are applicable to the selected mode appear here. If the teleprotection supplement is not
required the address 132 Teleprot. E/F = Disabled.
If a protection interface is available, the additional setting text SIGNALv.ProtInt is displayed in address 132
Teleprot. E/F.
Conventional Transmission
The following modes are possible with conventional transmission links (as described in Section 2.8 Teleprotec-
tion for earth fault overcurrent protection (optional):
Dir.Comp.Pickup Directional comparison pickup,
UNBLOCKING Directional unblocking scheme,
2.8.7
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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BLOCKING Directional blocking scheme.
At address 3201 FCT Telep. E/F the use of a teleprotection scheme can be switched ON or OFF.
If the teleprotection has to be applied to a three terminal line, the setting in address 3202 must be Line
Config. = Three terminals, if not, the setting remains Two Terminals.
Digital Transmission
The following mode is possible with digital transmission using the protection data interface:
SIGNALv.ProtInt Directional comparison pickup.
At address 3201 FCT Telep. E/F the use of a teleprotection scheme can be turned ON- or OFF. Address
147 NUMBER OF RELAY indicates the number of ends and must be set identically in all devices. The earth
fault directional comparison pickup scheme via the protection interface is only active if parameter 132 Tele-
prot. E/F was set to SIGNALv.ProtInt for all devices in a constellation.
Earth Fault Protection Prerequisites
In the application of the comparison schemes, absolute care must be taken that both line ends recognize an
external earth fault (earth fault through-current) in order to avoid a faulty echo signal in the case of the
permissive schemes, or in order to ensure the blocking signal in the case of the blocking scheme. If, during an
earth fault according to Figure 2-96, the protection at B does not recognize the fault, this would be interpreted
as a fault with single-sided infeed from A (echo from B or no blocking signal from B), which would lead to
unwanted tripping by the protection at A. Therefore, the earth fault protection features an earth fault stage
3IoMin Teleprot (address 3105). This stage must be set more sensitive than the earth current stage used
for the teleprotection. The larger the capacitive earth current (ΙEC in Figure 2-96) is, the smaller this stage must
be set. On overhead lines a setting equal to 70 % to 80 % of the earth current stage is usually adequate. On
cables or very long lines where the capacitive currents in the event of an earth fault are of the same order of
magnitude as the earth fault currents, the echo function should not be used or restricted to the case where
the circuit breaker is open; the blocking scheme should not be used under these conditions at all.
[sig-uebertrag-verf-erdkurz-stromverteil-oz-010802, 1, en_GB]
Figure 2-96 Possible current distribution during external earth fault
On three terminal lines (teed feeders) it should further be noted that the earth fault current is not equally
distributed on the line ends during an external fault. The most unfavourable case is shown in Figure 2-97. In
this case, the earth current flowing in from A is distributed equally on the line ends B and C. The setting value
3IoMin Teleprot (address 3105), which is decisive for the echo or the blocking signal, must therefore be
set smaller than one half of the setting value for the earth current stage used for teleprotection. In addition,
the above comments regarding the capacitive earth current which is left out in Figure 2-97 apply. If the earth
current distribution is different from the distribution assumed here, the conditions are more favourable as one
of the two earth currents ΙEB or ΙEC must then be larger than in the situation described previously.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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[sig-uebertrag-verf-erdkurz-ung-stromverteil-oz-010802, 1, en_GB]
Figure 2-97 Possible unfavourable current distribution on a three terminal line during an external earth
fault
Time Settings
The send signal prolongation Send Prolong.(address 3203) must ensure that the send signal reliably
reaches the opposite line end, even if there is very fast tripping at the sending line end and/or the signal trans-
mission time is relatively long. In the case of the permissive schemes Dir.Comp.Pickup and UNBLOCKING,
this signal prolongation time is only effective if the device has already issued a trip command. This ensures the
release of the other line end even if the short-circuit is cleared very rapidly by a different protection function
or other stage. In the case of the blocking scheme BLOCKING, the transmit signal is always prolonged by this
time. In this case, it corresponds to a transient blocking following a reverse fault. This parameter can only be
altered in DIGSI at Display Additional Settings.
In order to detect steady-state line faults such as open circuits, a monitoring time Delay for alarm is
started when a fault is detected (address 3207). Upon expiration of this time the fault is considered a perma-
nent failure. This parameter can only be altered in DIGSI at Display Additional Settings.
The release of the directional tripping can be delayed by means of the permissive signal delay Release
Delay (address 3208). In general, this is only required for the blocking scheme BLOCKING to allow sufficient
transmission time for the blocking signal during external faults. This delay only has an effect on the receive
circuit of the teleprotection. Conversely, tripping by the comparison protection is not delayed by the set time
delay of the directional stage.
Transient Blocking
The setting parameters TrBlk Wait Time and TrBlk BlockTime are for the transient blocking with the
comparison schemes. This parameter can only be changed in DIGSI at Display Additional Settings.
The time TrBlk Wait Time (address 3209) is a waiting time prior to transient blocking. In the case of the
permissive schemes, only once the directional stage of the earth fault protection has recognized a fault in the
reverse direction, within this period of time after fault detection, will the transient blocking be activated. In
the case of the blocking scheme, the waiting time prevents transient blocking in the event that the blocking
signal reception from the opposite line end is very fast. With the setting ∞ there is no transient blocking.
i
i
NOTE
The TrBlk Wait Time must not be set to zero to prevent unwanted activation of the transient blocking
TrBlk BlockTime when the direction measurement is not as fast as the pick-up (signal transients). A
setting of 10 ms to 40 ms is generally applicable depending on the operating (tripping) time of the relevant
circuit breaker on the parallel line.
It is absolutely necessary that the transient blocking time TrBlk BlockTime (address 3210) is longer than
the duration of transients resulting from the inception or clearance of external earth faults. The send signal is
delayed by this time with the permissive overreach schemes Dir.Comp.Pickup and UNBLOCKING if the
protection had initially detected a reverse fault. In the blocking scheme, the blocking of the stage release is
prolonged by this time by both the detection of a reverse fault and the (blocking) received signal. After expira-
tion of TrBlk BlockTime (address 3210) the delay time Release Delay (address 3208) is restarted. Since
the blocking scheme always requires setting the delay time Release Delay, the transient blocking time
TrBlk BlockTime (address 3210) can usually be set very short.
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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When the teleprotection schemes of the distance protection and earth fault protection share the same
channel, EF TRANSBLK DIS (address 3212) should be set to YES. This blocks also the distance protection if
an external fault was previously detected by the earth fault protection only.
Echo Function
The echo function settings are common to all weak infeed measures and summarized in tabular form in
Section 2.9.2.2 Setting Notes.
i
i
NOTE
The
ECHO SIGNAL
(No 4246) must be allocated separately to the output relays for the transmitter actua-
tion, as it is not contained in the transmit signals of the transmission functions.
On the digital protection data interface with permissive overreach transfer trip mode, the echo is trans-
mitted as a separate signal without taking any special measures.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
3201 FCT Telep. E/F ON
OFF
ON Teleprotection for Earth Fault O/C
3202 Line Config. Two Terminals
Three terminals
Two Terminals Line Configuration
3203A Send Prolong. 0.00 .. 30.00 sec 0.05 sec Time for send signal prolongation
3207A Delay for alarm 0.00 .. 30.00 sec 10.00 sec Unblocking: Time Delay for Alarm
3208 Release Delay 0.000 .. 30.000 sec 0.000 sec Time Delay for release after pickup
3209A TrBlk Wait Time 0.00 .. 30.00 sec; ∞ 0.04 sec Transient Block.: Duration external
flt.
3210A TrBlk BlockTime 0.00 .. 30.00 sec 0.05 sec Transient Block.: Blk.T. after ext.
flt.
3212A EF TRANSBLK DIS YES
NO
YES EF transient block by DIS
Information List
No. Information Type of
Informa-
tion
Comments
1311 >EF Teleprot.ON SP >E/F Teleprotection ON
1312 >EF TeleprotOFF SP >E/F Teleprotection OFF
1313 >EF TeleprotBLK SP >E/F Teleprotection BLOCK
1318 >EF Rec.Ch1 SP >E/F Carrier RECEPTION, Channel 1
1319 >EF Rec.Ch2 SP >E/F Carrier RECEPTION, Channel 2
1320 >EF UB ub 1 SP >E/F Unblocking: UNBLOCK, Channel 1
1321 >EF UB bl 1 SP >E/F Unblocking: BLOCK, Channel 1
1322 >EF UB ub 2 SP >E/F Unblocking: UNBLOCK, Channel 2
1323 >EF UB bl 2 SP >E/F Unblocking: BLOCK, Channel 2
1324 >EF BlkEcho SP >E/F BLOCK Echo Signal
1325 >EF Rec.Ch1 L1 SP >E/F Carrier RECEPTION, Channel 1, Ph.L1
1326 >EF Rec.Ch1 L2 SP >E/F Carrier RECEPTION, Channel 1, Ph.L2
2.8.8
2.8.9
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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No. Information Type of
Informa-
tion
Comments
1327 >EF Rec.Ch1 L3 SP >E/F Carrier RECEPTION, Channel 1, Ph.L3
1328 >EF UB ub 1-L1 SP >E/F Unblocking: UNBLOCK Chan. 1, Ph.L1
1329 >EF UB ub 1-L2 SP >E/F Unblocking: UNBLOCK Chan. 1, Ph.L2
1330 >EF UB ub 1-L3 SP >E/F Unblocking: UNBLOCK Chan. 1, Ph.L3
1371 EF Tele SEND L1 OUT E/F Telep. Carrier SEND signal, Phase L1
1372 EF Tele SEND L2 OUT E/F Telep. Carrier SEND signal, Phase L2
1373 EF Tele SEND L3 OUT E/F Telep. Carrier SEND signal, Phase L3
1374 EF Tele STOP L1 OUT E/F Telep. Block: carrier STOP signal L1
1375 EF Tele STOP L2 OUT E/F Telep. Block: carrier STOP signal L2
1376 EF Tele STOP L3 OUT E/F Telep. Block: carrier STOP signal L3
1380 EF TeleON/offBI IntSP E/F Teleprot. ON/OFF via BI
1381 EF Telep. OFF OUT E/F Teleprotection is switched OFF
1384 EF Tele SEND OUT E/F Telep. Carrier SEND signal
1386 EF TeleTransBlk OUT E/F Telep. Transient Blocking
1387 EF TeleUB Fail1 OUT E/F Telep. Unblocking: FAILURE Channel 1
1388 EF TeleUB Fail2 OUT E/F Telep. Unblocking: FAILURE Channel 2
1389 EF Tele BL STOP OUT E/F Telep. Blocking: carrier STOP signal
1390 EF Tele BL Jump OUT E/F Tele.Blocking: Send signal with jump
1391 EF Rec.L1 Dev1 OUT EF Tele.Carrier RECEPTION, L1, Device1
1392 EF Rec.L2 Dev1 OUT EF Tele.Carrier RECEPTION, L2, Device1
1393 EF Rec.L3 Dev1 OUT EF Tele.Carrier RECEPTION, L3, Device1
1394 EF Rec.L1 Dev2 OUT EF Tele.Carrier RECEPTION, L1, Device2
1395 EF Rec.L2 Dev2 OUT EF Tele.Carrier RECEPTION, L2, Device2
1396 EF Rec.L3 Dev2 OUT EF Tele.Carrier RECEPTION, L3, Device2
1397 EF Rec.L1 Dev3 OUT EF Tele.Carrier RECEPTION, L1, Device3
1398 EF Rec.L2 Dev3 OUT EF Tele.Carrier RECEPTION, L2, Device3
1399 EF Rec.L3 Dev3 OUT EF Tele.Carrier RECEPTION, L3, Device3
Functions
2.8 Teleprotection for earth fault overcurrent protection (optional)
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Measures for Weak and Zero Infeed
In cases where there is no or only weak infeed present at one line end, the distance protection does not pick
up there during a short-circuit on the line. On lines where there is only a single-sided infeed, a pickup by the
distance protection is only possible at the infeed end. On lines where the starpoint is only earthed behind one
line end, there is also no pickup at the line without zero sequence current. The missing pickup means that the
release signal for the remote end cannot be created. The settings and information table applies for the
following functions.
Echo function
Functional Description
Figure 2-98 shows the method of operation of the echo function. The echo function can be activated (ECHO
only) or deactivated (OFF) under address 2501 FCT Weak Infeed (weak infeed FunCTion). You can also
activate the weak infeed tripping function (ECHO and TRIP and Echo &Trip(I=0)) with this “switch”.
Refer also to Section 2.9.2 Classical Tripping. This setting is common to the teleprotection functions for the
distance protection and for the earth fault protection.
If there is no fault detection or no earth current at one line end, the echo function causes the received signal
to be sent back to the other line end as an “echo”, where it is used to initiate permissive tripping.
In applications with one common transmission channel used by both the distance and the earth fault protec-
tion spurious trippings may occur, if distance protection and earth fault protection create an echo independ-
ently from each other. In this case parameter Echo:1channel has to be set to YES.
If the conditions for an echo signal are met by the distance protection or the earth fault protection (see also
Sections 2.6 Teleprotection for distance protection and 2.8 Teleprotection for earth fault overcurrent protec-
tion (optional) under “Echo Function”), a short delay Trip/Echo DELAY is initially activated. This delay is
necessary to avoid transmission of the echo if the protection at the weak line end has a longer fault detection
time during reverse faults or if it picks up a little later due to unfavourable short-circuit or earth current distri-
bution. If, however, the circuit breaker at the non-feeding line end is open, this delay of the echo signal is not
required. The echo delay time may then be bypassed. The circuit breaker position is provided by the central
information control functions (refer to Section 2.20.1 Function Control).
The echo impulse is then transmitted (alarm output
ECHO SIGNAL
), the duration of which can be set with the
parameter Trip EXTENSION. The
ECHO SIGNAL
must be allocated separately to the output relay(s) for
transmission, as it is not contained in the transmit signals
Dis.T.SEND
, “Dis.T.SEND L*” or
EF Tele SEND
.
i
i
NOTE
The
ECHO SIGNAL
(No. 4246) must be separately allocated to the output relay to start the send signal via
the transmitter actuation. It is not included in the transmit signals of the transmission functions.
On the digital protection data interface with permissive overreach transfer trip mode, the echo is trans-
mitted as a separate signal without taking any special measures.
After output of the echo pulse or during the send signal of the distance protection or the earth fault protec-
tion, a new echo cannot be sent for at least 50 ms (presetting). This prevents echo repetition after the line has
been switched off.
In the case of the blocking scheme and the underreach schemes, the echo function is not required and there-
fore ineffective.
2.9
2.9.1
2.9.1.1
Functions
2.9 Measures for Weak and Zero Infeed
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[logik-echofkt-signal-100422-wlk, 1, en_GB]
Figure 2-98 Logic diagram of the echo function with teleprotection
Classical Tripping
Functional Description
Teleprotection schemes
By coordinating the weak infeed function with the teleprotection in conjunction with distance protection
and/or earth fault protection, fast tripping can also be achieved at both line ends in the above cases.
At the strong infeed line end, the distance protection can always trip instantaneously for faults inside zone Z1.
With permissive teleprotection schemes, fast tripping for faults on 100% of the line length is achieved by acti-
vation of the echo function (see Section 2.6 Teleprotection for distance protection).This provides the permis-
sive release of the trip signal at the strong infeed line end.
The permissive teleprotection scheme in conjunction with the earth fault protection can also achieve release
of the trip signal at the strong infeed line end by means of the echo function (refer to Section 2.8 Teleprotec-
tion for earth fault overcurrent protection (optional)).
Auch beim Erdkurzschlussschutz kann mit den Übertragungsverfahren nach dem Freigabeprinzip am spei-
senden Leitungsende mit Hilfe der Echofunktion (siehe Abschnitt 2.8 Teleprotection for earth fault overcur-
rent protection (optional)) das Auslösekommando freigegeben werden.
In many cases tripping of the circuit breaker at the weak infeeding line end is also desired. For this purpose the
device 7SA522 has a dedicated protection function with dedicated trip command.
Pickup with undervoltage
In Figure 2-99 , the logic diagram of the weak-infeed tripping is shown. The function can be activated ( ECHO
and TRIP and Echo &Trip(I=0) ) or deactivated ( OFF ) in address 2501 FCT Weak Infeed (Weak
Infeed FunCTion). If this “switch” is set to ECHO only , the tripping is also disabled; however, the echo func-
tion to release the infeeding line end is activated (refer also to Section 2.6 Teleprotection for distance protec-
tion and 2.8 Teleprotection for earth fault overcurrent protection (optional) ). The tripping function can be
blocked at any time via the binary input
>BLOCK Weak Inf
.
2.9.2
2.9.2.1
Functions
2.9 Measures for Weak and Zero Infeed
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The logic for the detection of a weak-infeed condition is built up per phase in conjunction with the distance
protection and additionally once for the earth fault protection. Since the undervoltage check is performed for
each phase, single-pole tripping is also possible, provided the device version has the single-pole tripping
option.
In the event of a short-circuit, it may be assumed that only a small voltage appears at the line end with the
weakinfeed condition, as the small fault current only produces a small voltage drop in the short-circuit loop. In
the event of zero-infeed, the loop voltage is approximately zero. The weak-infeed tripping is therefore
dependent on the measured undervoltage UNDERVOLTAGE which is also used for the selection of the faulty
phase.
If a signal is received from the opposite line end without fault detection by the local protection, this indicates
that there is a fault on the protected feeder. In the case of three terminal lines when using a comparison
scheme a receive signal from both ends may be present. In the case of underreach schemes one receive signal
from at least one end is sufficient.
After a security margin time of 40°ms following reception of the receive signal, the weak-infeed tripping is
released if the remaining conditions are satisfied: undervoltage, circuit breaker closed and no pickup of the
distance protection or of the earth fault protection.
To avoid a faulty pickup of the weak infeed function following tripping of the line and reset of the fault detec-
tion, the function cannot pick up anymore once a fault detection in the affected phase was present (RS flip-
flop in the following figure).
In the case of the earth fault protection, the release signal is routed via the phase segregated logic modules.
Single-phase tripping is therefore also possible if both distance protection and earth fault protection or exclu-
sively earth fault protection issues a release condition.
Functions
2.9 Measures for Weak and Zero Infeed
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[logik-ase-hiko-20100422, 1, en_GB]
Figure 2-99 Logic diagram of the weak infeed tripping
*) Where the distance protection and the earth fault protection function share the same transmis-
sion channel (address 2509 = YES ) and neither the distance protection nor the earth fault
protection are blocked, the output of this gate is an AND combination of the inputs.
Functions
2.9 Measures for Weak and Zero Infeed
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Setting Notes
General
It is a prerequisite for the operation of the weak infeed function that this function is enabled during the
configuration of the device at address 125 Weak Infeed = Enabled.
With the parameter FCT Weak Infeed (address 2501), it is determined whether the device shall trip during
a weak infeed condition or not. With the settings ECHO and TRIP and Echo &Trip(I=0), both the echo
function and the weak infeed tripping function are activated. With the setting ECHO only, the echo function
for provision of the release signal at the infeeding line end is activated. There is, however, no tripping at the
line end with missing or weak infeed condition. As the weak-infeed measures are dependent on the signal
reception from the opposite line end, they only make sense if the protection is coordinated with teleprotection
(refer to Section 2.6 Teleprotection for distance protection and/or 2.8 Teleprotection for earth fault overcur-
rent protection (optional)).
The receive signal is a functional component of the trip condition. Accordingly, the weak infeed tripping func-
tion must not be used with the blocking schemes. It is only permissible with the permissive schemes and
the comparison schemes with release signals! In all other cases it should be switched OFF at address 2501. In
such cases it is better to disable this function from the onset by setting address 125 to Disabled during the
device configuration. The associated parameters are then not accessible.
The undervoltage setting value UNDERVOLTAGE (address 2505) must in any event be set below the minimum
expected operational phase-earth voltage. The lower limit for this setting is given by the maximum expected
voltage drop at the relay location on the weak-infeed side during a short-circuit on the protected feeder for
which the distance protection may no longer pick up.
Echo Function
In the case of line ends with weak infeed, the echo function is sensible in conjunction with permissive over-
reach transfer schemes so that the feeding line end is also released. The parameters for weak infeed are listed
in Section 2.9.3.2 Setting Notes. The echo function can be enabled (ECHO only) or disabled (OFF) at address
2501 FCT Weak Infeed. With this “switch” you can also activate the weak infeed tripping function (ECHO
and TRIP and Echo &Trip(I=0)).
If no circuit breaker auxiliary contacts are routed and if no current flow takes place, a tripping during weak
infeed is only possible with the setting Echo &Trip(I=0). With this setting, the function is not blocked by
checking the residual current. If the circuit breaker auxiliary contacts are routed, a tripping during weak infeed
is further blocked if the auxiliary contacts signal that the circuit breaker is opened.
Tripping during weak infeed via ECHO and TRIP is only possible if either the circuit breaker auxiliary
contacts signal that the circuit breaker is closed or current flows in the corresponding phase which exceeds
the preset residual current (address 1130 PoleOpenCurrent).
Please do not fail to observe the notes on the setting of the distance protection zones at margin heading
“Distance Protection Prerequisites” in Section 2.6 Teleprotection for distance protection, and the notes on
earth fault protection regarding the setting of the earth current stage 3IoMin Teleprot at margin heading
“Earth Fault Protection Prerequisites” in Section 2.8 Teleprotection for earth fault overcurrent protection
(optional).
The echo delay time Trip/Echo DELAY (address 2502) must be set long enough to avoid incorrect echo
signals resulting from the difference in fault detection pick-up time of the distance protection functions or the
earth fault protection function at all line ends during external faults (through-fault current). Typical setting is
approx. 40 ms (presetting). This parameter can only be altered in DIGSI at Display Additional Settings.
The echo impulse duration Trip EXTENSION (address 25033) may be matched to the configuration data of
the signal transmission equipment. It must be long enough to ensure that the receive signal is recognized
even with different pickup times by the protection devices at the line ends and different response times of the
transmission equipment. In most cases approx. 50 ms (presetting) is sufficient. This parameter can only be
altered in DIGSI at Display Additional Settings.
A continous echo signal between the line ends can be avoided (e.g. spurious signal from the command
channel) by blocking a new echo for a certain time Echo BLOCK Time (address 2504) after each output of
an echo signal. Typical setting is approx. 50 ms. In addition after the distance protection or earth fault protec-
tion signal was sent, the echo is also blocked for the time Echo BLOCK Time. This parameter can only be
altered in DIGSI at Display Additional Settings.
2.9.2.2
Functions
2.9 Measures for Weak and Zero Infeed
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In applications with a transmission channel used by both the distance and the earth fault protection spurious
trippings may occur, if distance protection and earth fault protection create an echo independently from each
other. In this case parameter Echo:1channel (address 2509) has to be set to YES. The default setting is NO.
i
i
NOTE
The
ECHO SIGNAL
(No. 4246) must be allocated separately to the output relays for the transmitter actua-
tion, as it is not contained in the transmit signals of the transmission functions.
On the digital protection data interface with permissive overreach transfer trip mode, the echo is trans-
mitted as a separate signal without taking any special measures.
Tripping According to French Specification
Functional Description
An alternative for detecting weak infeed is only available in the models 7SA522*-**D** .
Pickup with Relative Voltage Jump
In addition to the classical function of weak infeed, the so called Logic no. 2 (address 125) presents an
alternative to the method used so far.
This function operates independently of the teleprotection scheme by using its own receive signal and it is
able to trip with delay and without delay.
2.9.3
2.9.3.1
Functions
2.9 Measures for Weak and Zero Infeed
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Non-delayed Tripping
[logikdiagramm-ase-unverz-wlk-151002, 1, en_GB]
Figure 2-100 Logic diagram for non-delayed tripping
Functions
2.9 Measures for Weak and Zero Infeed
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Trip with Delay
[logikdiagramm-ase-verz-wlk-151002, 1, en_GB]
Figure 2-101 Logic for delayed tripping
Setting Notes
Phase selection
Phase selection is accomplished via undervoltage detection. For this purpose no absolute voltage threshold in
volts is parameterized, but a factor (address 2510 Uphe< Factor) which is multiplied with the measured
phase-phase voltage, and yields the voltage threshold. This method considers operational deviations from the
rated voltage in the undervoltage threshold and adjusts them to the current conditions.
2.9.3.2
Functions
2.9 Measures for Weak and Zero Infeed
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The undervoltage threshold is created from the mean value of the measured phase-to-phase voltages of the
last 500 ms and delayed via a voltage memory. Thus changes of the phase-to-phase voltage affect the
threshold only slowly. The time constant can be set at address 2511 Time const. τ. In case of pickup the
last determined voltage threshold of the phase that has picked up remains until a trip command is issued. This
ensures that an influence of the voltage threshold by the fault is avoided for long waiting times. The under-
voltage is determined for all 3 phases.
If the measured phase-to-phase voltage falls below the threshold (address 1131 PoleOpenVoltage), under-
voltage is no longer detected in this phase.
Since a positive feedback occurs during tripping, i. e. the measured fault status cannot be eliminated by
switching off, the picked up element drops out after the WI tripping. When the current voltage exceeds the
dropout threshold, a new pickup is possible after a maximum of 1 s.
[logik-unterspg-ase-wlk-301002, 1, en_GB]
Figure 2-102 Undervoltage detection for UL1–E
Instantaneous tripping
An undelayed TRIP command is issued if a receive signal
>WI reception
is present and if an undervoltage is
detected simultaneously. The receive signal is prolonged at address 2512 Rec. Ext. so that a trip command
is still possible in the event of a quick dropout of the transmitting line end.
To prevent a faulty pickup of the weak infeed function following tripping of the line and reset of the fault
detection by the distance protection function, a pickup is blocked in the corresponding phase. This blocking is
maintained until the receive signal disappears.
If a receive signal applies and no undervoltage is detected, but the zero sequence current threshold 3I0>
Threshold is exceeded (address 2514), a fault on the line can be assumed. If this state (receive signal, no
undervoltage and zero sequence current) applies for longer than 500 ms, 3-pole tripping is initiated. The time
delay for the signal “3I0> exceeded” is set at address 2513 T 3I0> Ext.. If the zero sequence current
exceeds the threshold 3I0> Threshold for longer than the set time T 3I0> alarm (address 2520), the
annunciation
3I0 erkannt
“ is issued.
The non-delayed stage operates only if binary input
>WI rec. OK
reports the proper functioning of the
transmission channel.
Moreover, the phase-selective block signals BLOCK Weak Inf affect the non-delayed logic. Faulty pickups are
thus prevented, especially after the dedicated line end was shut down.
In address 2530 WI non delayed the stage for instantaneous tripping is switched OFF or ON permanently.
Trip with delay
The operation of the delayed tripping is determined by three parameters:
Functions
2.9 Measures for Weak and Zero Infeed
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•Address 2517 1pol. Trip enables a single-pole trip command for phase-to-ground faults if it is para-
meterised to ON
•Address 2518 1pol. with 3I0, if set to ON, allows a single-pole trip command only if also the
threshold 3I0> Threshold for the zero current has been exceeded. If the threshold 3I0> Threshold
is not exceeded, phase-to-ground faults do not cause a tripping. Position OFF allows a single-pole trip
command even when 3I0> Threshold is not exceeded. The time delay of “3I0> exceeded” is set at
address 2513 T 3I0> Ext..
•Address 2519 3pol. Trip, if set to ON, also allows a three-pole trip command in the event of a multi-
pole pickup. In position OFF only the multi-pole pickup is reported but a three-pole trip command is not
issued (only reporting). A 1-pole or 3-pole trip command for 1-pole pickup can still be issued.
A delayed tripping stage is implemented to allow tripping of the dedicated line end in case the transmission
channel is faulted. When undervoltage conditions have been detected, this stage picks up in one or more
phases and trips with delay after a configured time (address 2515 TM and address 2516 TT) depending on the
set stage mode (address 2517 1pol. Trip and 2519 3pol. Trip). If no trip command is issued during a
pickup after the times 2515 TM and 2516 TT have elapsed, the voltage memory is reset and the pickup is
cancelled.
Address 2531 WI delayed allows to set delayed tripping as operating mode. With ON this stage is perma-
nently active. With the setting by receive fail, this stage will only be active when
>WI rec. OK
is not
true. With OFF this stage is permanently switched off.
To avoid erroneous pickup, phase selection via undervoltage is blocked entirely in the event of voltage failure
(pickup of the fuse failure monitor or of the VT mcb). In addition, the relevant phases are blocked when the
distance protection function is activated.
Tables on Classical Tripping and Tripping according to French Specification
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
2501 FCT Weak Infeed OFF
ECHO only
ECHO and TRIP
Echo &Trip(I=0)
ECHO only Weak Infeed function
2502A Trip/Echo DELAY 0.00 .. 30.00 sec 0.04 sec Trip / Echo Delay after
carrier receipt
2503A Trip EXTENSION 0.00 .. 30.00 sec 0.05 sec Trip Extension / Echo
Impulse time
2504A Echo BLOCK Time 0.00 .. 30.00 sec 0.05 sec Echo Block Time
2505 UNDERVOLTAGE 2 .. 175 V 25 V Undervoltage (ph-e)
2509 Echo:1channel NO
YES
NO Echo logic: Dis and EF on
common channel
2510 Uphe< Factor 0.10 .. 1.00 0.70 Factor for undervoltage
Uphe<
2511 Time const. τ 1 .. 60 sec 5 sec Time constant Tau
2512A Rec. Ext. 0.00 .. 30.00 sec 0.65 sec Reception extension
2513A T 3I0> Ext. 0.00 .. 30.00 sec 0.60 sec 3I0> exceeded extension
2514 3I0> Threshold 1A 0.05 .. 1.00 A 0.50 A 3I0 threshold for neutral
current pickup
5A 0.25 .. 5.00 A 2.50 A
2515 TM 0.00 .. 30.00 sec 0.40 sec WI delay single pole
2.9.4
2.9.4.1
Functions
2.9 Measures for Weak and Zero Infeed
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Addr. Parameter C Setting Options Default Setting Comments
2516 TT 0.00 .. 30.00 sec 1.00 sec WI delay multi pole
2517 1pol. Trip ON
OFF
ON Single pole WI trip allowed
2518 1pol. with 3I0 ON
OFF
ON Single pole WI trip with 3I0
2519 3pol. Trip ON
OFF
ON Three pole WI trip allowed
2520 T 3I0> alarm 0.00 .. 30.00 sec 10.00 sec 3I0> exceeded delay for
alarm
2530 WI non delayed ON
OFF
ON WI non delayed
2531 WI delayed ON
by receive fail
OFF
by receive fail WI delayed
Information List
No. Information Type of
Informa-
tion
Comments
4203 >BLOCK Weak Inf SP >BLOCK Weak Infeed
4204 >BLOCK del. WI SP >BLOCK delayed Weak Infeed stage
4205 >WI rec. OK SP >Reception (channel) for Weak Infeed OK
4206 >WI reception SP >Receive signal for Weak Infeed
4221 WeakInf. OFF OUT Weak Infeed is switched OFF
4222 Weak Inf. BLOCK OUT Weak Infeed is BLOCKED
4223 Weak Inf ACTIVE OUT Weak Infeed is ACTIVE
4225 3I0 detected OUT Weak Infeed Zero seq. current detected
4226 WI U L1< OUT Weak Infeed Undervoltg. L1
4227 WI U L2< OUT Weak Infeed Undervoltg. L2
4228 WI U L3< OUT Weak Infeed Undervoltg. L3
4229 WI TRIP 3I0 OUT WI TRIP with zero sequence current
4231 WeakInf. PICKUP OUT Weak Infeed PICKED UP
4232 W/I Pickup L1 OUT Weak Infeed PICKUP L1
4233 W/I Pickup L2 OUT Weak Infeed PICKUP L2
4234 W/I Pickup L3 OUT Weak Infeed PICKUP L3
4241 WeakInfeed TRIP OUT Weak Infeed General TRIP command
4242 Weak TRIP 1p.L1 OUT Weak Infeed TRIP command - Only L1
4243 Weak TRIP 1p.L2 OUT Weak Infeed TRIP command - Only L2
4244 Weak TRIP 1p.L3 OUT Weak Infeed TRIP command - Only L3
4245 Weak TRIP L123 OUT Weak Infeed TRIP command L123
4246 ECHO SIGNAL OUT ECHO Send SIGNAL
2.9.4.2
Functions
2.9 Measures for Weak and Zero Infeed
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External direct and remote tripping
Any signal from an external protection or monitoring device can be coupled into the signal processing of the
7SA522 by means of a binary input. This signal can be delayed, alarmed and routed to one or several output
relays.
Functional Description
External trip of the local circuit breaker
Figure 2-103 shows the logic diagram. If device and circuit breaker are capable of single-phase operation, it is
also possible to trip single-pole. The tripping logic of the device ensures that the conditions for single-pole trip-
ping are met (e.g. single-phase tripping permissible, automatic reclosure ready).
The external tripping can be switched on and off with a setting parameter and may be blocked via binary
input.
[logikdiagramm-ext-ausloesung-wlk-310702, 1, en_GB]
Figure 2-103 Logic diagram of the local external tripping
Remote trip of the circuit breaker at the opposite line end
On a digital communication link via protection interface, transmission of up to 4 remote commands is
possible, as described in Section 2.5 Remote signals via protection data interface (optional).
On conventional transmission paths, one transmission channel per desired transmission direction is required
for remote tripping at the remote end. For example, fibre optic connections or voice frequency modulated
high frequency channels via pilot cables, power line carrier or microwave radio links can be used for this
purpose in the following ways.
If the trip command of the distance protection is to be transmitted, it is best to use the integrated teleprotec-
tion function for the transmission of the signal as this already incorporates the optional extension of the trans-
mitted signal, as described in Section 2.6 Teleprotection for distance protection. Any of the commands can of
course be used to trigger the transmitter to initiate the send signal.
On the receiver side, the external local trip function is used. The receive signal is routed to a binary input
which is assigned to the logical binary input function
>DTT Trip L123
. If single-pole tripping is desired, you
can also use binary inputs
>DTT Trip L1
,
>DTT Trip L2
and
>DTT Trip L3
. Figure 2-103 thus also
applies in this case.
2.10
2.10.1
Functions
2.10 External direct and remote tripping
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Setting Notes
General
A prerequisite for the application of the direct and remote tripping functions is that during the configuration
of the scope of functions in address 122 DTT Direct Trip = Enabled was applied. At address 2201 FCT
Direct Trip ON or OFF.
It is possible to set a trip delay for both the local external trip and the receive side of the remote trip in address
2202 Trip Time DELAY. This can be used as a security time margin, especially in the case of local trip.
Once a trip command has been issued, it is maintained for at least as long as the set minimum trip command
duration TMin TRIP CMD which was set for the device in general in address 240 (Section 2.1.2 Power
System Data 1). Reliable operation of the circuit breaker is therefore ensured, even if the initiating signal pulse
is very short. This parameter can only be altered in DIGSI at Display Additional Settings.
Settings
Addr. Parameter Setting Options Default Setting Comments
2201 FCT Direct Trip ON
OFF
OFF Direct Transfer Trip (DTT)
2202 Trip Time DELAY 0.00 .. 30.00 sec; ∞ 0.01 sec Trip Time Delay
Information List
No. Information Type of
Informa-
tion
Comments
4403 >BLOCK DTT SP >BLOCK Direct Transfer Trip function
4412 >DTT Trip L1 SP >Direct Transfer Trip INPUT Phase L1
4413 >DTT Trip L2 SP >Direct Transfer Trip INPUT Phase L2
4414 >DTT Trip L3 SP >Direct Transfer Trip INPUT Phase L3
4417 >DTT Trip L123 SP >Direct Transfer Trip INPUT 3ph L123
4421 DTT OFF OUT Direct Transfer Trip is switched OFF
4422 DTT BLOCK OUT Direct Transfer Trip is BLOCKED
4432 DTT TRIP 1p. L1 OUT DTT TRIP command - Only L1
4433 DTT TRIP 1p. L2 OUT DTT TRIP command - Only L2
4434 DTT TRIP 1p. L3 OUT DTT TRIP command - Only L3
4435 DTT TRIP L123 OUT DTT TRIP command L123
2.10.2
2.10.3
2.10.4
Functions
2.10 External direct and remote tripping
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Overcurrent protection (optional)
The 7SA522 features a time overcurrent protection function which can be used as either a back-up or an
emergency overcurrent protection. All stages may be configured independently of each other and combined
according to the user's requirements.
General
Whereas the distance protection can only function correctly if the measured voltage signals are available to
the device, the emergency overcurrent protection only requires the currents. The emergency overcurrent
function is automatically activated when the measured voltage signal is lost, e.g. due to a short circuit or inter-
ruption of the voltage transformer secondary circuits (emergency operation). The emergency operation there-
fore replaces the distance protection as short circuit protection if loss of the measured voltage signal is recog-
nized by one of the following conditions:
•Pickup of the internal measured voltage monitoring (“Fuse-Failure-Monitor”, refer to Subsection
2.19.1 Measurement Supervision) or
•The “Voltage transformer mcb tripped” signal is received via binary input, indicating that the measured
voltage signal is lost.
If one of these conditions occur, the distance protection is immediately blocked and the emergency operation
is activated.
If the overcurrent protection is set as a back-up overcurrent protection, it will work independently of other
protection and monitoring functions, i.e. also independently of the distance protection. The back-up overcur-
rent protection could for instance be used as the only short-circuit protection if the voltage transformers are
not yet available when the feeder is initially commissioned.
The overcurent protection has a total of four stages for each phase current and four stages for the earth
current, these are:
•Two overcurrent stages with a definite time characteristic (O/C with DT),
•One overcurrent stage with inverse time characteristic (IDMT),
•One additional overcurrent stage which is preferably used as a stub protection, but which can be applied
as an additional normal definite time delayed stage. With the device variants for the region Germany
(10th digit of ordering code = A) this stage is only available if the setting 126 TOC IEC /w 3ST is
active.
These four stages are independent from each other and are freely combinable. Blocking by external criteria via
binary input is possible as well as rapid (non-delayed) tripping (e.g. by an external automatic reclose device).
During energization of the protected feeder onto a dead fault it is also possible to release any stage, or also
several, for non-delayed tripping. If you do not need all stages, each individual stage can be deactivated by
setting the pickup threshold to ∞.
Functional Description
Measured values
The phase currents are fed to the device via the input transformers of the measuring input. Earth current 3·Ι0
is either measured directly or calculated depending on the ordered device version and usage of the fourth
current input Ι4 of the device.
If Ι4 is connected to the starpoint of the current transformer set, the earth current will be available directly as
measured quantity
If the device is fitted with the highly sensitive current input for Ι4, this current Ι4 is used with the factor
I4/Iph CT (address 221, refer to Section 2.1.2 Power System Data 1 of the P.System Data 1). As the
linear range of this measuring input is restricted considerably in the high range, this current is only evaluated
up to an amplitude of approx. 1.6°A. In the event of larger currents, the device automatically switches over to
2.11
2.11.1
2.11.2
Functions
2.11 Overcurrent protection (optional)
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the evaluation of the zero sequence current derived from the phase currents. Naturally, all three phase
currents obtained from a set of three starconnected current transformers must be available and connected to
the device. The processing of the earth current is then also possible if very small as well as large earth fault
currents occur.
If the fourth current input Ι4 is used e.g. for a power transformer star point current or for the earth current of a
parallel line, the device derives the earth current from the phase currents. Naturally in this case also all three
phase currents derived from a set of three star connected current transformers must be available and
connected to the device.
Definite time high set current stage Ι>>
Each phase current is compared with the setting value Iph>> (address 2610) the earth current is compared
with 3I0>> PICKUP (address2612). A trip command is issued after pickup of an element and expiration of
the associated time delays T Iph>> (address 2611) or T 3I0>> (address 2613). The dropout value is about 7
% below the pickup value, but at least 1,8 % of the rated current.
The figure below shows the logic diagram of the Ι stages. They can be blocked via binary input
>BLOCK O/C
I>>
. The binary input
>O/C InstTRIP
and the function block “switch-onto-fault” are common to all stages
and described below. They may, however, separately affect the phase and/or ground current elements. This is
accomplished with the following setting parameters:
•I>> InstTrip BI (Address 2614) determines whether a non-delayed trip of this element via binary
input
>O/C InstTRIP
is possible (YES) or not possible (NO) and
•I>> SOTF (address2615) whether during switching onto a fault tripping shall be instantaneous (YES) or
not (NO).
Functions
2.11 Overcurrent protection (optional)
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[logikdiagramm-i-vg-stufe-wlk-310702, 1, en_GB]
Figure 2-104 Logic diagram of the Ι stage
1) The output indications associated with the pickup signals can be found in Table 2-5
2) The output indications associated with the trip signals can be found in Table 2-6
Definite time overcurrent stage Ι>
The logic of the overcurrent stage Ι is the same as that of the Ι stages. In all references Iph>> must merely be
replaced by Iph> or 3I0>> PICKUP by 3I0>. In all other respects Figure 2-104 applies.
Inverse time overcurrent stage ΙP
The logic of the inverse overcurrent stage also operates chiefly in the same way as the remaining stages.
However, the time delay is calculated here based on the type of the set characteristic, the intensity of the
current and a time multiplier (following figure). A pre-selection of the available characteristics was already
carried out during the configuration of the protection functions. Furthermore, an additional constant time
delay T Ip Add (address 2646) or T 3I0p Add (address 2656) may be selected, which is added to the
inverse time. The possible characteristics are shown in the Technical Data.
The following figure shows the logic diagram. The setting addresses of the IEC characteristic curves are shown
by way of example. In the setting information (Section 2.11.3 Setting Notes) the different setting addresses
are described in detail.
Functions
2.11 Overcurrent protection (optional)
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Figure 2-105 Logic diagram of the ΙP stage (inverse time overcurrent protection), for example IEC character-
istics
1) The output indications associated with the pickup signals can be found in Table 2-5
2) The output indications associated with the trip signals can be found in Table 2-6
End fault stage
A further overcurrent stage is the stub protection. It can, however, also be used as a normal additional definite
time overcurrent stage, as it functions independently of the other stages.
A stub fault is a short-circuit located between the current transformer set and the line isolator. It is of partic-
ular importance with the 11/2 circuit breaker arrangements.
Functions
2.11 Overcurrent protection (optional)
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[endfehler-eineinhalb-ls-wlk-0702, 1, en_GB]
Figure 2-106 Stub fault at an 11/2 circuit breaker arrangement
If a short circuit current ΙA and/or ΙB flows while the line isolator 1 is open, this implies that a fault in the stub
range between the current transformers ΙA, ΙB and the line isolator exists. The circuit breakers CBA and CBC
that carry the short-circuit current can be tripped without delay. The two sets of current transformers are
connected in parallel such that the current sum ΙA + ΙB represents the current flowing towards the line isolator.
The stub protection is an overcurrent protection which is only in service when the state of the line isolator
indicates the open condition via a binary input
>I-STUB ENABLE
. The binary input must therefore be oper-
ated via an auxiliary contact of the isolator. In the case of a closed line isolator, the stub protection is out of
service. For more information see the next logic diagram.
If the stub protection stage is to be used as a normal definite time overcurrent stage, the binary input
>BLOCK
I-STUB
should be left without allocation or routing (matrix). However the release input
>I-STUB ENABLE
must be continually activated (either via a binary input or via the user definable logic functions CFC).
Functions
2.11 Overcurrent protection (optional)
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[logikdiagramm-endfehlerschutz-wlk-310702, 1, en_GB]
Figure 2-107 Logic diagram of stub fault protection
1) The output indications associated with the pickup signals can be found in Table 2-5
2) The output indications associated with the trip signals can be found in Table 2-6
Instantaneous tripping before automatic reclosure
If automatic reclosure is to be carried out, quick fault clearance before reclosure is usually desirable. A release
signal from an external automatic reclosure device can be injected via binary input
>O/C InstTRIP
. The
interconnection of the internal automatic reclose function is performed via an additional CFC logic, which typi-
cally connects the output signal 2889
AR 1.CycZoneRel
with the input signal
>O/C InstTRIP
. Any stage
of the overcurrent protection can thus perform an instantaneous trip before reclosure via the parameter
Telep / BI ....
Switching onto a fault
The internal line energization detection can be used to achieve quick tripping of the circuit breaker in the
event of an earth fault. The time overcurrent protection can then trip three-pole without delay or with a
reduced delay. It can be determined via parameter setting for which stage(s) the instantaneous tripping
following energization applies (refer also to the logic diagrams Figure 2-104, Figure 2-105 and Figure 2-107).
Functions
2.11 Overcurrent protection (optional)
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This function is independent of the high-current instantaneous tripping described in Section 2.12 Instanta-
neous high-current switch-on-to-fault protection (SOTF).
Pickup logic and tripping logic
The pickup signals of the individual phases (or the ground) and of the stages are linked in such a way that
both the phase information and the stage which has picked up are output (Table 2-5).
Table 2-5 Pickup signals of the individual phases
Internal Indication Figure Output Indication No.
Ι>> Trip L1
Ι> Trip L1
Ιp Trip L1
Ι>>> Trip L1
Figure 2-104
Figure 2-105
Figure 2-107
O/C Pickup L1
7162
Ι>> Trip L2
Ι> Trip L2
Ιp Trip L2
Ι>>> Trip L2
Figure 2-104
Figure 2-105
Figure 2-107
O/C Pickup L2
7163
Ι>> Trip L3
Ι> Trip L3
Ιp Trip L3
Ι>>> Trip L3
Figure 2-104
Figure 2-105
Figure 2-107
O/C Pickup L3
7164
Ι>> Trip E
Ι> Trip E
Ιp TripE
Ι>>> Trip E
Figure 2-104
Figure 2-105
Figure 2-107
O/C Pickup E
7165
Ι>> Trip L1
Ι>> Trip L2
Ι>> Trip L3
Ι>> Trip E
Figure 2-104
Figure 2-104
Figure 2-104
Figure 2-104
O/C PICKUP I>>
7191
Ι> Trip L1
Ι> Trip L2
Ι> Trip L3
Ι> Trip E
O/C PICKUP I>
7192
Ιp Trip L1
Ιp Trip L2
Ιp Trip L3
Ιp Trip E
Figure 2-105
Figure 2-105
Figure 2-105
Figure 2-105
O/C PICKUP Ip
7193
Ι>>> Trip L1
Ι>>> Trip L2
Ι>>> Trip L3
Ι>>> Trip E
Figure 2-107
Figure 2-107
Figure 2-107
Figure 2-107
I-STUB PICKUP
7201
(All pickups)
O/C PICKUP
7161
For the tripping signals (Table 2-6) the stage which caused the tripping is also output. If the device has the
option to trip single-pole and if this option has been activated, the pole which has been tripped is also indi-
cated in case of single-pole tripping (refer also to Section 2.20.1 Function Control “Tripping Logic of the Entire
Device”).
Functions
2.11 Overcurrent protection (optional)
204 SIPROTEC 4, 7SA522, Manual
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Table 2-6 Trip signals of the single phases
Internal Indication Figure Output Indication No.
Ι>> OFF L1
Ι> OFF L1
Ιp OFF L1
Ι>>> OFF L1
Figure 2-104
Figure 2-105
Figure 2-107
O/C TRIP 1p.L1
or
O/C TRIP L123
7212 or
7215
Ι>> OFF L2
Ι> OFF L2
Ιp OFF L2
Ι>>> OFF L2
Figure 2-104
Figure 2-105
Figure 2-107
O/C TRIP 1p.L2
or
O/C TRIP L123
7213 or
7215
Ι>> OFF L3
Ι> OFF L3
Ιp OFF L3
Ι>>> OFF L3
Figure 2-104
Figure 2-105
Figure 2-107
O/C TRIP 1p.L3
or
O/C TRIP L123
7214 or
7215
Ι>> OFF E
Ι> OFF E
Ιp OFFE
Ι>>> OFF E
Figure 2-104
Figure 2-105
Figure 2-107
O/C TRIP L123
7215
Ι>> OFF L1
Ι>> OFF L2
Ι>> OFF L3
Ι>> OFF E
Figure 2-104
Figure 2-104
Figure 2-104
Figure 2-104
O/C TRIP I>>
7221
Ι> OFF L1
Ι> OFF L2
Ι> OFF L3
Ι> OFF E
O/C TRIP I>
7222
Ιp OFF L1
Ιp OFF L2
Ιp OFF L3
Ιp OFF E
Figure 2-105
Figure 2-105
Figure 2-105
Figure 2-105
O/C TRIP Ip
7223
Ι>>> OFF L1
Ι>>> OFF L2
Ι>>> OFF L3
Ι>>> OFF E
Figure 2-107
Figure 2-107
Figure 2-107
Figure 2-107
I-STUB TRIP
7235
(General TRIP)
O/C TRIP
7211
Setting Notes
General
During configuration of the scope of functions for the device (address 126) the available characteristics were
determined. Depending on the configuration and the order variant, only those parameters that apply to the
selected characteristics are accessible in the procedures described below.
Address 2601 is set according to the desired mode of operation of the overcurrent protection: Operating
Mode = ON:always activ means that the overcurrent protection works independently of other protection
functions, i.e. as a backup overcurrent protection. If it is to work only as an emergency function in case of loss
of VT supply, ON:with VT loss must be set. Finally, it can also be set to OFF.
If not all stages are required, each individual stage can be deactivated by setting the pickup threshold to ∞.
But if you set only an associated time delay to ∞ this does not suppress the pickup signals but prevents the
timers from running.
2.11.3
Functions
2.11 Overcurrent protection (optional)
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The stub protection remains in service even if the overcurrent mode of operation setting is ON:with VT
loss.
One or several stages can be set as instantaneous tripping stages when switching onto a fault. This is chosen
during the setting of the individual stages (see below). To avoid a spurious pick-up due to transient overcur-
rents, the delay SOTF Time DELAY (address 2680) can be set. Typically, the presetting of 0 s is correct. A
short delay can be useful in case of long cables for which high inrush currents can be expected, or for trans-
formers. This delay depends on the intensity and the duration of the transient overcurrents as well as on
which stages were selected for the fast switch onto fault clearance.
High current stages Ιph>>, 3Ι0>>
The Ι>>-stages Iph>> (address 2610) and 3I0>> PICKUP (address 2612) together with the Ι>-stages or the
Ιp stages from a two0stage characteristic curve. Of course, all three stages can be combined as well. If one
stage is not required, the pickup value has to be set to ∞. The Ι>> stages always operate with a defined delay
time.
If the Ι>> stages are used for instantaneous tripping before the automatic reclosure (via CFC interconnection),
the current setting corresponds to the Ι> or Ιp stages (see below). In this case, only the different delay times
are of interest. The times T Iph>> (address 2611) and T 3I0>> (address 2613) can then be set to 0 s or a
very low value, as the fast clearance of the fault takes priority over the selectivity before the automatic reclo-
sure is initiated. These stages have to be blocked before final trip in order to achieve the selectivity.
For very long lines with a small source impedance or on applications with large reactances (e.g. transformers,
series reactors), theΙ>> stages can also be used for current grading. In this case, they must be set in such a
way that they do not pick up in case of a fault at the end of the line. The times can then be set to 0s or to a
small value.
When using a personal computer and DIGSI to apply the settings, these can be optionally entered as primary
or secondary values. For settings with secondary values the currents will be converted for the secondary side
of the current transformers.
Calculation Example:
110 kV overhead line 150 mm2:
s (length) = 60 km
R1/s = 0.19 Ω/km
X1/s = 0.42 Ω/km
Short-circuit power at the beginning of the line:
Sk' = 2.5 GVA
Current Trans-
former
600 A/5 A
From that the line impedance ZL and the source impedance ZS are calculated:
[fo_7sa6_fkt-UMZ_bsp, 1, en_GB]
ZL = 0.46 Ω/km · 60 km = 27.66 Ω
[formel-ueberstromzeit-hochstrom-1-oz-010802, 1, en_GB]
The 3-phase short-circuit current at the end of the line is Ιk end:
Functions
2.11 Overcurrent protection (optional)
206 SIPROTEC 4, 7SA522, Manual
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[formel-ueberstromzeit-hochstrom-2-oz-010802, 1, en_GB]
With a safety factor of 10%, the following primary setting value is calculated:
Setting value Ι>> = 1.1 · 2150 A = 2365 A
or the secondary setting value:
[formel-ueberstromzeit-hochstrom-3-oz-010802, 1, en_GB]
If short-circuit currents exceed 2365 A (primary) or 19.7 A (secondary), there is a short circuit on the line to be
protected. This fault can immediately be cleared by the time overcurrent protection.
Note: the calculation was carried out with absolute values, which is sufficiently precise for overhead lines. If
the angles of the source impedance and the line impedance vary considerably, a complex calculation must be
carried out.
A similar calculation must be carried out for earth faults, with the maximum earth current occurring at the line
end during a short-circuit being decisive.
The set time delays are pure additional delays, which do not include the operating time (measuring time).
The parameter I>> InstTrip BI (address 2614) determines, whether the time delays
>O/C InstTRIP
(No 7110) or the automatic reclosure in ready state can be bypassed by the binary input T Iph>> (address
2611) and T 3I0>> (address2613) is possible. The binary input (if allocated) is applied to all stages of the
time-overcurrent protection. With I>> InstTrip BI = YES you define that the Ι>> stages trip without delay
after pickup if the binary input was activated. For I>> InstTrip BI = NO the set delays are always active
If the Ι>>-stage, when switching the line onto a fault, is to trip without delay or with a short delay, SOTF
Time DELAY (address 2680, see above under margin heading “General”) set the parameter I>> SOTF
(address 2615) to YES. Any other stage can be selected as well for this instantaneous tripping.
Overcurrent Stages Ιph>, 3Ι0> in Definite-time Overcurrent Protection
For the setting of the current pickup value, Iph> (address 2620), the maximum operating current is most
decisive. Pickup due to overload should never occur, since the device in this operating mode operates as fault
protection with correspondingly short tripping times and not as overload protection. For this reason, a pickup
value of about 10 % above the expected peak load is recommended for line protection, and a setting of about
20 % above the expected peak load is recommended for transformers and motors.
When using a personal computer and DIGSI to apply the settings, these can be optionally entered as primary
or secondary values. For settings with secondary values the currents will be converted for the secondary side
of the current transformers.
Calculation Example:
110 kV overhead line 150 mm2
maximum transmittable power
Pmax = 120 MVA
corresponding to
Ιmax = 630 A
Current Transformer 600 A/5 A
Safety factor 1.1
With settings in primary quantities the following setting value is calculated:
Set value Ι> = 1.1 · 630 A = 693 A
With settings in secondary quantities the following setting value is calculated:
Functions
2.11 Overcurrent protection (optional)
SIPROTEC 4, 7SA522, Manual 207
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[formel-ueberstromzeit-ueberstrom-oz-310702, 1, en_GB]
The earth current stage 3I0> (address 2622) should be set to detect the smallest earth fault current to be
expected. For very small earth currents the earth fault protection is most suited (refer to Section 2.7 Earth
fault overcurrent protection in earthed systems (optional)).
The time delay T Iph> (address 2621) results from the time grading schedule designed for the network. If
implemented as emergency overcurrent protection, shorter tripping times are advisable (one grading time
step above the fast tripping stage), as this function is only activated in the case of the loss of the local meas-
ured voltage.
The time T 3I0> (address 2623) can normally be set shorter, according to a separate time grading schedule
for earth currents.
The set times are mere additional delays for the independent stages, which do not include the inherent oper-
ating time of the protection. If only the phase currents are to be monitored, set the pickup value of the earth
fault stage to ∞.
The parameter I> Telep/BI (address 2624) defines whether the time delays T Iph> (address 2621) and T
3I0> (address 2623) can be bypassed by the binary input
>O/C InstTRIP
. The binary input (if allocated) is
applied to all stages of the time-overcurrent protection. With I> Telep/BI = YES you define that the Ι>
stages trip without delay after pickup if the binary input was activated. For I> Telep/BI = NO the set delays
are always active.
If the Ι> stage, when switching the line onto a fault, is to retrip without delay or with a short delay SOTF
Time DELAY (address 2680, see above under side title “General”), set parameter I> SOTF (address 2625) to
YES. We recommend, however, not to choose the sensitive setting for the fast tripping as switching onto a
fault typically causes a solid short circuit. It is important to avoid that the selected stage picks up due to transi-
ents during line energization.
Overcurrent Stages ΙP, 3Ι0P for Inverse-time Overcurrent Protection with IEC Characteristics
In the case of the inverse time overcurrent stages, various characteristics can be selected, depending on the
ordering version of the device and the configuration (address 126). With IEC characteristics (address 126
Back-Up O/C = TOC IEC) the following options are available in address 2660 IEC Curve:
Normal Inverse (inverse, type A according to IEC 60255-3),
Very Inverse (very inverse, type B according to IEC 60255-3),
Extremely Inv. (extremely inverse, type C according to IEC 60255-3) und
LongTimeInverse (longtime, type B according to IEC 60255-3).
The characteristics and equations they are based on are listed in the „Technical Data“.
For the setting of the current thresholds Ip> (address 2640) and 3I0p PICKUP (address 2650) the same
considerations as for the overcurrent stages of the definite time protection (see above) apply. In this case, it
must be noted that a safety margin between the pickup threshold and the set value has already been incorpo-
rated. Pickup only occurs at a current which is approximately 10 % above the set value.
The above example shows that the maximum expected operating current may directly be applied as setting
here.
Primary: Set value ΙP = 630 A,
Secondary: Set value ΙP = 5.25 A, d.h. (630 A/600 A) · 5 A.
The time multiplier setting T Ip Time Dial (address 2642) is derived from the grading coordination plan
applicable to the network. If implemented as emergency overcurrent protection, shorter tripping times are
advisable (one grading time step above the fast tripping stage), as this function is only activated in the case of
the loss of the local measured voltage.
The time multiplier setting T 3I0p TimeDial (address 2652) can usually be set smaller according to a sepa-
rate earth fault grading plan. If only the phase currents are to be monitored, set the pickup value of the earth
fault stage to ∞.
In addition to the current-dependent delays, a time fixed delay can be set, if necessary. The settings T Ip
Add (address 2646 for phase currents) and T 3I0p Add (address 2656 for earth currents) are in addition to
the time delays resulting from the set curves.
Functions
2.11 Overcurrent protection (optional)
208 SIPROTEC 4, 7SA522, Manual
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The parameter I(3I0)p Tele/BI (address 2670) defines whether the time delays T Ip Time Dial
(address 2642), including the additional delay T Ip Add (address 2646), and T 3I0p TimeDial (address
2652), including the additional delay T 3I0p Add (address 2656), can be bypassed by the binary input
>O/C
InstTRIP
(No. 7110). The binary input (if allocated) is applied to all stages of the time-overcurrent protec-
tion. With I(3I0)p Tele/BI = YES you define that the IP stages trip without delay after pickup if the binary
input was activated. For I(3I0)p Tele/BI = NO the set delays are always active.
If the ΙP stage, when switching the line onto a fault, is to retrip without delay or with a short delay SOTF
Time DELAY (address 2680, see above under side title “General”), set parameter I(3I0)p SOTF (address
2671) to YES. We recommend, however, not to choose the sensitive setting for the fast tripping as switching
onto a fault typically causes a solid short circuit. It is important to avoid that the selected stage picks up due to
transients during line energization.
Overcurrent Stages ΙP, 3Ι0P for inverse-time O/C protection with ANSI characteristic
In the case of the inverse time overcurrent stages, various characteristics can be selected, depending on the
ordering version of the device and the configuration (address 126). With ANSI characteristics (address 126
Back-Up O/C = TOC ANSI) the following options are available in address 2661 ANSI Curve:
Inverse,
Short Inverse,
Long Inverse,
Moderately Inv.,
Very Inverse,
Extremely Inv. and
Definite Inv..
For the setting of the current thresholds Ip> (address 2640) and 3I0p PICKUP (address 2650) the same
considerations as for the overcurrent stages of the definite time protection (see above) apply. In this case, it
must be noted that a safety margin between the pickup threshold and the set value has already been incorpo-
rated. Pickup only occurs at a current which is approximately 10 % above the set value.
For the setting of the current thresholds Ip> (address 2640) and 3I0p PICKUP (address 2650), the same
considerations as for the overcurrent stages of the definite time protection (see above) apply. In this case, it
must be noted that a safety margin between the pickup threshold and the set value has already been incorpo-
rated. Pickup only occurs at a current which is approximately 10°% above the set value.
The above example shows that the maximum expected operating current may directly be applied as setting
here.
Primary: Set value ΙP = 630 A,
Secondary: Setting value ΙP = 5.25 A, d.h. (630 A/600 A) · 5 A.
The time multiplier setting Time Dial TD Ip (address 2643) is derived from the grading coordination plan
applicable to the network. If implemented as emergency overcurrent protection, shorter tripping times are
advisable (one grading time step above the fast tripping stage), as this function is only activated in the case of
the loss of the local measured voltage.
The time multiplier setting TimeDial TD3I0p (address 2653) can usually be set smaller according to a sepa-
rate earth fault grading plan. If only the phase currents are to be monitored, set the pickup value of the earth
fault stage to ∞.
In addition to the inverse-time delays, a delay of constant length can be set, if necessary. The settings T Ip
Add (address 2646 for phase currents) and T 3I0p Add (address 2656 for ground current) are added to the
times of the set characteristic curves.
The parameter I(3I0)p Tele/BI (address 2670) defines whether the time delays Time Dial TD Ip
(address 2643), including the additional delay T Ip Add (address 2646), and TimeDial TD3I0p (address
2653), including the additional delay T 3I0p Add (address 2656), can be bypassed by the binary input
>O/C
InstTRIP
(No. 7110). The binary input (if allocated) is applied to all stages of the time-overcurrent protec-
tion. With I(3I0)p Tele/BI = YES you define that the IP stages trip without delay after pickup if the binary
input was activated. For I(3I0)p Tele/BI = NO the set delays are always active.
If the ΙP stage, when switching the line onto a fault, is to retrip without delay or with a short delay SOTF
Time DELAY (address 2680, see above under side title “General”), set parameter I(3I0)p SOTF (address
Functions
2.11 Overcurrent protection (optional)
SIPROTEC 4, 7SA522, Manual 209
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2671) to YES. We recommend, however, not to choose the sensitive setting for the fast tripping as switching
onto a fault typically causes a solid short circuit. It is important to avoid that the selected stage picks up due to
transients during line energization.
Additional stage Ιph>>>
When using the Ι>>> stage as stub fault protection, the pickup values Iph> STUB (address 2630) and 3I0>
STUB (address 2632) are usually not critical since the protection function is only activated when the line
isolator is open, which implies that each measured current should be a fault current. With a 11/2 circuit breaker
arrangement, however, it is possible that high short circuit currents flow from busbar A to busbar B or to
feeder 2 via the current transformers. These currents could cause different transformation errors in the two
current transformer sets ΙA and ΙB, especially in the saturation range. The protection should therefore not be
set unnecessarily sensitive. If the minimum short circuit currents on the busbars are known, the pickup value
Iph> STUB is set somewhat (approx. 10 %) below the minimum two-phase short-circuit current, 3I0> STUB
is set below the minimum single-phase current. If only the phase currents are to be monitored, set the pickup
value of the residual current stage to ∞ .
The times T Iph STUB (address 2631) and T 3I0 STUB (address 2633) are set to 0 s for this application, so
that the protection triggers with open isolator.
If this stage is applied differently, similar considerations as for the other overcurrent stages apply.
The parameter I-STUB Telep/BI (address 2634) determines, whether the time delays
>O/C InstTRIP
can be bypassed by the binary input T Iph STUB (address 2631) and T 3I0 STUB (address 2633) is
possible. The binary input (if allocated) is applied to all stages of the time-overcurrent protection. With I-
STUB Telep/BI = YES you determine that the Ι>>>-stages trip without delay after pickup if the binary input
was activated. For I-STUB Telep/BI = NO the set delays are always active
If the Ι>>>-stage, when switching the line onto a fault, is to trip without delay or with a short delay, SOTF
Time DELAY (address 2680, see above under margin heading “General”) set the parameter I-STUB SOTF
(address 2635) to YES. When used as stub fault protection, select the setting NO since the effect of this protec-
tion function solely depends on the position of the isolator.
Settings
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
2601 Operating Mode ON:with VT loss
ON:always activ
OFF
ON:with VT loss Operating mode
2610 Iph>> 1A 0.05 .. 50.00 A; ∞ 2.00 A Iph>> Pickup
5A 0.25 .. 250.00 A; ∞ 10.00 A
2611 T Iph>> 0.00 .. 30.00 sec; ∞ 0.30 sec T Iph>> Time delay
2612 3I0>> PICKUP 1A 0.05 .. 25.00 A; ∞ 0.50 A 3I0>> Pickup
5A 0.25 .. 125.00 A; ∞ 2.50 A
2613 T 3I0>> 0.00 .. 30.00 sec; ∞ 2.00 sec T 3I0>> Time delay
2614 I>> InstTrip BI NO
YES
YES Instantaneous trip via BI
2615 I>> SOTF NO
YES
NO Instantaneous trip after
SwitchOnToFault
2620 Iph> 1A 0.05 .. 50.00 A; ∞ 1.50 A Iph> Pickup
5A 0.25 .. 250.00 A; ∞ 7.50 A
2621 T Iph> 0.00 .. 30.00 sec; ∞ 0.50 sec T Iph> Time delay
2622 3I0> 1A 0.05 .. 25.00 A; ∞ 0.20 A 3I0> Pickup
5A 0.25 .. 125.00 A; ∞ 1.00 A
2.11.4
Functions
2.11 Overcurrent protection (optional)
210 SIPROTEC 4, 7SA522, Manual
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Addr. Parameter C Setting Options Default Setting Comments
2623 T 3I0> 0.00 .. 30.00 sec; ∞ 2.00 sec T 3I0> Time delay
2624 I> Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
2625 I> SOTF NO
YES
NO Instantaneous trip after
SwitchOnToFault
2630 Iph> STUB 1A 0.05 .. 50.00 A; ∞ 1.50 A Iph> STUB Pickup
5A 0.25 .. 250.00 A; ∞ 7.50 A
2631 T Iph STUB 0.00 .. 30.00 sec; ∞ 0.30 sec T Iph STUB Time delay
2632 3I0> STUB 1A 0.05 .. 25.00 A; ∞ 0.20 A 3I0> STUB Pickup
5A 0.25 .. 125.00 A; ∞ 1.00 A
2633 T 3I0 STUB 0.00 .. 30.00 sec; ∞ 2.00 sec T 3I0 STUB Time delay
2634 I-STUB Telep/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
2635 I-STUB SOTF NO
YES
NO Instantaneous trip after
SwitchOnToFault
2640 Ip> 1A 0.10 .. 4.00 A; ∞ ∞ A Ip> Pickup
5A 0.50 .. 20.00 A; ∞ ∞ A
2642 T Ip Time Dial 0.05 .. 3.00 sec; ∞ 0.50 sec T Ip Time Dial
2643 Time Dial TD Ip 0.50 .. 15.00 ; ∞ 5.00 Time Dial TD Ip
2646 T Ip Add 0.00 .. 30.00 sec 0.00 sec T Ip Additional Time Delay
2650 3I0p PICKUP 1A 0.05 .. 4.00 A; ∞ ∞ A 3I0p Pickup
5A 0.25 .. 20.00 A; ∞ ∞ A
2652 T 3I0p TimeDial 0.05 .. 3.00 sec; ∞ 0.50 sec T 3I0p Time Dial
2653 TimeDial TD3I0p 0.50 .. 15.00 ; ∞ 5.00 Time Dial TD 3I0p
2656 T 3I0p Add 0.00 .. 30.00 sec 0.00 sec T 3I0p Additional Time
Delay
2660 IEC Curve Normal Inverse
Very Inverse
Extremely Inv.
LongTimeInverse
Normal Inverse IEC Curve
2661 ANSI Curve Inverse
Short Inverse
Long Inverse
Moderately Inv.
Very Inverse
Extremely Inv.
Definite Inv.
Inverse ANSI Curve
2670 I(3I0)p Tele/BI NO
YES
NO Instantaneous trip via Tele-
prot./BI
2671 I(3I0)p SOTF NO
YES
NO Instantaneous trip after
SwitchOnToFault
2680 SOTF Time DELAY 0.00 .. 30.00 sec 0.00 sec Trip time delay after SOTF
Functions
2.11 Overcurrent protection (optional)
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Information List
No. Information Type of
Informa-
tion
Comments
2054 Emer. mode OUT Emergency mode
7104 >BLOCK O/C I>> SP >BLOCK Backup OverCurrent I>>
7105 >BLOCK O/C I> SP >BLOCK Backup OverCurrent I>
7106 >BLOCK O/C Ip SP >BLOCK Backup OverCurrent Ip
7110 >O/C InstTRIP SP >Backup OverCurrent InstantaneousTrip
7130 >BLOCK I-STUB SP >BLOCK I-STUB
7131 >I-STUB ENABLE SP >Enable I-STUB-Bus function
7151 O/C OFF OUT Backup O/C is switched OFF
7152 O/C BLOCK OUT Backup O/C is BLOCKED
7153 O/C ACTIVE OUT Backup O/C is ACTIVE
7161 O/C PICKUP OUT Backup O/C PICKED UP
7162 O/C Pickup L1 OUT Backup O/C PICKUP L1
7163 O/C Pickup L2 OUT Backup O/C PICKUP L2
7164 O/C Pickup L3 OUT Backup O/C PICKUP L3
7165 O/C Pickup E OUT Backup O/C PICKUP EARTH
7171 O/C PU only E OUT Backup O/C Pickup - Only EARTH
7172 O/C PU 1p. L1 OUT Backup O/C Pickup - Only L1
7173 O/C Pickup L1E OUT Backup O/C Pickup L1E
7174 O/C PU 1p. L2 OUT Backup O/C Pickup - Only L2
7175 O/C Pickup L2E OUT Backup O/C Pickup L2E
7176 O/C Pickup L12 OUT Backup O/C Pickup L12
7177 O/C Pickup L12E OUT Backup O/C Pickup L12E
7178 O/C PU 1p. L3 OUT Backup O/C Pickup - Only L3
7179 O/C Pickup L3E OUT Backup O/C Pickup L3E
7180 O/C Pickup L31 OUT Backup O/C Pickup L31
7181 O/C Pickup L31E OUT Backup O/C Pickup L31E
7182 O/C Pickup L23 OUT Backup O/C Pickup L23
7183 O/C Pickup L23E OUT Backup O/C Pickup L23E
7184 O/C Pickup L123 OUT Backup O/C Pickup L123
7185 O/C PickupL123E OUT Backup O/C Pickup L123E
7191 O/C PICKUP I>> OUT Backup O/C Pickup I>>
7192 O/C PICKUP I> OUT Backup O/C Pickup I>
7193 O/C PICKUP Ip OUT Backup O/C Pickup Ip
7201 I-STUB PICKUP OUT O/C I-STUB Pickup
7211 O/C TRIP OUT Backup O/C General TRIP command
7212 O/C TRIP 1p.L1 OUT Backup O/C TRIP - Only L1
7213 O/C TRIP 1p.L2 OUT Backup O/C TRIP - Only L2
7214 O/C TRIP 1p.L3 OUT Backup O/C TRIP - Only L3
7215 O/C TRIP L123 OUT Backup O/C TRIP Phases L123
7221 O/C TRIP I>> OUT Backup O/C TRIP I>>
7222 O/C TRIP I> OUT Backup O/C TRIP I>
7223 O/C TRIP Ip OUT Backup O/C TRIP Ip
7235 I-STUB TRIP OUT O/C I-STUB TRIP
2.11.5
Functions
2.11 Overcurrent protection (optional)
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Instantaneous high-current switch-on-to-fault protection (SOTF)
The instantaneous high-current switch-onto-fault protection function is provided to disconnect immediately,
and without any time delay, feeders that are switched onto a high-current fault. It is primarily used as fast
protection in the event of energizing the feeder while the earth switch is closed, but can also be used every
time the feeder is energized —in other words also following automatic reclosure— (selectable).
The energization of the feeder is reported to the protection by the circuit breaker state recognition function.
This function is described in detail in Section 2.20.1 Function Control.
Functional Description
Pickup
The high-current pickup function measures each phase current and compares it with the set value I>>>
(address 2404). The currents are numerically filtered to eliminate the DC component. If the measured current
is more than twice the set value, the protection automatically reverts to the unfiltered measured values,
thereby allowing extremely fast tripping. DC current components in the fault current and in the CT secondary
circuit following the switching off of large currents have virtually no influence on the high-current pickup
operation.
The high-current switch-onto-fault protection can operate separately for each phase or in three phases.
Following manual closure of the circuit breaker it always operates three-phase via the release signal “Energiza-
tion”, which is derived from thecentral state recognition in the device, assuming that the manual closure can
be recognized there (see Section 2.20.1 Function Control, “Generation of the energization signal”,
Figure 2-170).
If further criteria were determined during the configuration of the recognition of line energization (address
1134 Line Closure, refer to Section 2.1.4.1 Setting Notes) the release signal “SOTF-O/C Release Lx” may be
issued phase segregated, following three phase closure the release of all three phases is given. The phase
segregated release only applies to devices that can trip single-pole, and is then important in conjunction with
single-pole automatic reclosure.
Tripping is always three-pole. The phase selectivity only applies to the pick-up due to the coupling of the high
current criterion with the circuit breaker pole which is closed.
In order to generate a trip command as quickly as possible after an energisation, the fast switch-onto-fault
protection is released selectively for each phase after a pole is detected open for the set time T DELAY SOTF
(address 1133).
The following figure shows the logic diagram.
[logikdiagramm-sab-wlk-310702, 1, en_GB]
Figure 2-108 Logic diagram of the high-current switch-onto-fault protection
2.12
2.12.1
Functions
2.12 Instantaneous high-current switch-on-to-fault protection (SOTF)
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Setting Notes
Requirement
A prerequisite for the operation of the switch-onto-fault protection is that in address 124 SOTF Overcurr. =
Enabled was set during the configuration of the device scope of functions. At address 2401 FCT SOTF-O/C
it can also be switched ON or OFF.
Pickup Value
The magnitude of the current which causes pick-up of the switch-onto-fault function is set as I>>> in address
2404. The setting value should be selected large enough to ensure that the protection does not under any
circumstances pick up due to a line overload or due to a current increase e.g. resulting from an automatic
reclosure dead time on a parallel feeder. It is recommended to set at least 2.5 times the rated current of the
feeder.
Settings
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
2401 FCT SOTF-O/C ON
OFF
ON Inst. High Speed SOTF-O/C
is
2404 I>>> 1A 0.10 .. 25.00 A 2.50 A I>>> Pickup
5A 0.50 .. 125.00 A 12.50 A
Information List
No. Information Type of
Informa-
tion
Comments
4253 >BLOCK SOTF-O/C SP >BLOCK Instantaneous SOTF Overcurrent
4271 SOTF-O/C OFF OUT SOTF-O/C is switched OFF
4272 SOTF-O/C BLOCK OUT SOTF-O/C is BLOCKED
4273 SOTF-O/C ACTIVE OUT SOTF-O/C is ACTIVE
4281 SOTF-O/C PICKUP OUT SOTF-O/C PICKED UP
4282 SOF O/CpickupL1 OUT SOTF-O/C Pickup L1
4283 SOF O/CpickupL2 OUT SOTF-O/C Pickup L2
4284 SOF O/CpickupL3 OUT SOTF-O/C Pickup L3
4295 SOF O/CtripL123 OUT SOTF-O/C TRIP command L123
2.12.2
2.12.3
2.12.4
Functions
2.12 Instantaneous high-current switch-on-to-fault protection (SOTF)
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Automatic reclosure function (optional)
Experience shows that about 85% of the arc faults on overhead lines are extinguished automatically after
being tripped by the protection. The line can therefore be re-energised. Reclosure is performed by an auto-
matic reclose function (AR).
Automatic reclosure function is only permitted on overhead lines because the possibility of extinguishing a
fault arc automatically only exists there. It must not be used in any other case. If the protected object consists
of a mixture of overhead lines and other equipment (e.g. overhead line in block with a transformer or over-
head line/cable), it must be ensured that reclosure can only be performed in the event of a fault on the over-
head line.
If the circuit breaker poles can be operated individually, a 1-pole automatic reclosure is usually initiated in the
case of 1-phase faults and a 3-pole automatic reclosure in the case of multi-phase faults in the network with
earthed system star point. If the fault still exists after reclosure (arc not extinguished or metallic short-circuit),
the protection issues a final trip. In some systems several reclosing attempts are performed.
In the model with 1-pole tripping the 7SA522 allows phase-selective 1-pole tripping. A 1- and 3-pole, one- and
multi-shot automatic reclosure is integrated depending on the order variant.
The 7SA522 can also operate in conjunction with an external automatic reclosure device. In this case, the
signal exchange between 7SA522 and the external reclosure device must be effected via binary inputs and
outputs.
It is also possible to initiate the integrated auto reclose function by an external protection device (e.g. a
backup protection). The use of two 7SA522 with automatic reclosure function or the use of one 7SA522 with
an automatic reclosure function and a second protection with its own automatic reclosure function is also
possible.
Functional Description
Reclosure is performed by an automatic reclosure circuit (ARC). An example of the normal time sequence of a
double reclosure is shown in the figure below.
[ablaufdia-2-mal-we-wirkzeit-wlk-310702, 1, en_GB]
Figure 2-109 Timing diagram of a double-shot reclosure with action time (2nd reclosure successful)
The integrated automatic reclosing function allows up to 8 reclosing attempts. The first four reclose cycles
may operate with different parameters (action and dead times, 1-/3-pole). The parameters of the fourth cycle
apply to the fifth cycle and onwards.
2.13
2.13.1
Functions
2.13 Automatic reclosure function (optional)
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Activation and deactivation
The automatic reclosure function can be switched on and off by means of the parameter 3401 AUTO
RECLOSE via the system interface (if available) and via binary inputs (if allocated). The switch states are saved
internally (refer to Figure 2-110) and secured against loss of auxiliary supply. Basically, it can only be switched
on from where it had previously been switched off. To be active, the function must be switched on from all
three switching sources.
Alteration of the switching state via setting or system interface is not possible during a running fault.
[logik-ein-aus-wiedereinschaltautomatik-st-290803, 1, en_GB]
Figure 2-110 Activation and deactivation of the auto-reclosure function
Selectivity before Reclosure
In order that automatic reclosure function can be successful, all faults on the entire overhead line must be
cleared at all line ends simultaneously — as fast as possible.
In the distance protection, for example, the overreach zone Z1B may be released before the first reclosure.
This implies that faults up to the zone reach limit of Z1B are tripped without delay for the first cycle
(Figure 2-111). A limited unselectivity in favour of fast simultaneous tripping is accepted here because a reclo-
sure will be performed in any case. The normal stages of the distance protection (Z1, Z2, etc.) and the normal
grading of the other short-circuit functions are independent of the automatic reclosure function function.
[reichweitenstrg-vor-we-dis-wlk-310702, 1, en_GB]
Figure 2-111 Reach control before first reclosure, using distance protection
If the distance protection is operated with one of the signal transmission methods described in Section
2.6 Teleprotection for distance protection the signal transmission logic controls the overreaching zone, i.e. it
determines whether a non-delayed trip (or delayed with T1B) is permitted in the event of faults in the over-
reaching zone (i.e. up to the reach limit of zone Z1B) at both line ends simultaneously. Whether the automatic
reclosure device is ready for reclosure or not is irrelevant, because the teleprotection function ensures the
selectivity over 100% of the line length and fast, simultaneous tripping. The same applies for the earth fault-
direction comparison protection (Section 2.8 Teleprotection for earth fault overcurrent protection (optional)).
Functions
2.13 Automatic reclosure function (optional)
216 SIPROTEC 4, 7SA522, Manual
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If, however, the signal transmission is switched off or the transmission path is disturbed, the internal auto-
matic reclosure circuit can determine whether the overreaching zone (Z1B in the distance protection) is
released for fast tripping. If no reclosure is expected (e.g. circuit breaker not ready) the normal grading of the
distance protection (i.e. fast tripping only for faults in zone Z1) must apply to retain selectivity..
Fast tripping before reclosure is also possible with multiple reclosures. Appropriate links between the output
signals (e.g. 2nd reclosure ready:
AR 2.CycZoneRel
) and the inputs for enabling/releasing non-delayed trip-
ping of the protection functions can be established via the binary inputs and outputs or the integrated userde-
finable logic functions (CFC).
Mixed Lines Overhead Line/Cable
In the distance protection, it is possible to use the distance zone signals to distinguish between cable and
overhead line faults to a certain extent. The automatic reclosure circuit can then be blocked by appropriate
signals generated by means of the user-programmable logic functions (CFC) if there is a fault in the cable
section.
Initiation
Initiation of the automatic reclosure function means storing the first trip signal of a power system fault that
was generated by a protection function which operates with the automatic reclosure function. In case of
multiple reclosure, initiation therefore only takes place once, with the first trip command. This storing of the
first trip signal is the prerequisite for all subsequent activities of the automatic reclosure function. The starting
is important when the first trip command has not appeared before expiry of an action time (see below under
“Action times”).
Automatic reclosure function is not started if the circuit breaker has not been ready for at least one OPEN-
CLOSE- OPEN–cycle at the instant of the first trip command. This can be achieved by setting parameters. For
further information, please refer to “Interrogation of Circuit Breaker Ready State”.
Each short-circuit protection function can be parameterized as to whether it should operate with the auto-
matic reclose function or not, i.e. whether it should start the reclose function or not. The same goes for
external trip commands applied via binary input and/or the trip commands generated by the teleprotection via
permissive or intertrip signals.
Those protection and monitoring functions in the device which do not respond to short-circuits or similar
conditions (e.g. an overload protection) do not initiate the automatic reclosure function because a reclosure
will be of no use here. The circuit breaker failure protection must not start the automatic reclosure function
either.
Action Times
It is often desirable to neutralise the ready–for–reclosure–state if the short-circuit condition was sustained for
a certain time, e.g. because it is assumed that the arc has burned in to such an extent that there is no longer
any chance of automatic arc extinction during the reclose dead time. Also for the sake of selectivity (see
above), faults that are usually cleared after a time delay should not lead to reclosure. It is therefore recom-
mended to use action times in conjunction with the distance protection.
The automatic reclosure function of the 7SA522 can be operated with or without action times (configuration
parameter AR control mode, address 134, see Section 2.1.1.2 Setting Notes). No starting signal is neces-
sary from the protection functions or external protection devices that operate without action time. Initiation
takes place as soon as the first trip command appears.
When operating with action time, an action time is available for each reclose cycle. The action times are
always started by the general starting signal (with logic OR combination of all internal and external protection
functions which can start the automatic reclose function). If no trip command is present before the action
time expires, the corresponding reclosure cycle is not carried out.
For each reclosure cycle, it can be specified whether or not it should allow the initiation. Following the first
general pickup, only those action times are relevant whose cycles allow starting because the other cycles are
not allowed to initiate. By means of the action times and the permission to start the recloser (permission to be
the first cycle that is executed), it is possible to determine which reclose cycles are executed depending on the
time it takes the protection function to trip.
Example 1: 3 cycles are set. Starting of the automatic reclosure function is allowed for at least the first cycle.
The action times are set as follows:
Functions
2.13 Automatic reclosure function (optional)
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•1.WE: T WIRK = 0.2 s;
•2.WE: T WIRK = 0.8 s;
•3.WE: T WIRK = 1.2 s;
Since reclosure is ready before the fault occurs, the first trip of a time overcurrent protection following a fault
is fast, i.e. before the end of any action time. This starts the automatic reclose function. After unsuccessful
reclosure, the 2nd cycle would then become active; but the time overcurrent protection does not trip in this
example until after 1s according to its grading time. Since the action time for the second cycle was exceeded
here, the second cycle is blocked. The 3rd cycle with its parameters is therefore carried out now. If the trip
command appeared more than 1.2 s after the 1st reclosure, there would be no further reclosure.
Example 2: 3 cycles are set. Starting is only allowed for the first. The action times are set as in example 1. The
first protection trip takes place 0.5 s after starting. Since the action time for the 1st cycle has already expired
at this time, this cannot start the automatic reclose function. As the 2nd and 3rd cycles are not permitted to
start the reclose function they will also not be initiated. Therefore no reclosure takes place as no starting took
place.
Example 3: 3 cycles are set. At least the first two cycles are set such that they can start the recloser. The action
times are set as in example 1. The first protection trip takes place 0.5 s after starting. Since the action time for
the 1st cycle has already expired at this time, it cannot start the automatic reclosure function, but the 2nd
cycle, for which initiating is allowed, is activated immediately. This 2nd cycle therefore starts the automatic
reclosure function, the 1st cycle is practically skipped.
Operating modes of the automatic reclosure function
The dead times — these are the times from elimination of the fault (drop off of the trip command or signaling
via auxiliary contacts) to the initiation of the automatic close command — may vary depending on the auto-
matic reclosure function operating mode selected when determining the function scope and the resulting
signals of the starting protection functions.
In control mode TRIP... (With TRIP command ...), 1-polige or 1-/3-polige reclose cycles are possible if the
device and the circuit breaker are suitable. In this case, different dead times (for every AR cycle) are possible
after 1-pole tripping and after 3-pole tripping. The protection function that issues the trip command deter-
mines the type of trip: 1-pole or 3-pole. The dead time is controlled dependent on this.
In control mode PICKUP ... ... (With PICKUP...), different dead times can be set for every reclose cycle
after 1-, 2- und 3-phasigen faults. The pickup diagram of the protection functions at the instant when the trip
command disappears is the decisive factor. This mode allows the dead time to be made dependent on the type
of fault in the case of 3-pole tripping applications.
Blocking reclosure
Different conditions lead to blocking of the automatic reclosure function. No reclosure is possible, for
example, if it is blocked via a binary input. If the automatic reclosure function has not yet been started, it
cannot be started at all. If a reclosure cycle is already in progress, dynamic blocking takes place (see below).
Each individual cycle may also be blocked via binary input. In this case the cycle concerned is declared as
invalid and will be skipped in the sequence of permissible cycles. If blocking takes place while the cycle
concerned is already running, this leads to aborting of the reclosure, i.e. no reclosure takes place even if other
valid cycles have been parameterized.
Internal blocking signals, with a limited duration, arise during the course of the reclose cycles:
The reclaim time T-RECLAIM (address 3403) is started with each automatic reclosure command, the only
exception is the ADT mode where the reclaim time can be disabled by setting it to 0 s. If the reclosure is
successful, all functions of the automatic reclosure function return to the idle state at the end of the reclaim
time; a fault after expiry of the reclaim time is treated as a new fault in the power system. If the reclaim time is
disabled in ADT mode, each new trip after reclosing is considered as a new fault. If one of the protection func-
tions causes another trip during the reclaim time, the next reclosure cycle will be started if multiple reclosure
has been set. If no further reclosure attempts are permitted, the last reclosure is regarded as unsuccessful in
case of another trip during the reclaim time. The automatic reclosure function is blocked dynamically.
The dynamic lock-out locks the reclosure for the duration of the dynamic lock-out time (0.5 s). This occurs, for
example, after a endgültigen trip or other events which block the auto reclose function after it has been
Functions
2.13 Automatic reclosure function (optional)
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started. Restarting is blocked during this time. When this time expires, the automatic reclosure function
returns to its quiescent state and is ready for a new fault in the network.
If the circuit breaker is closed manually (by the control discrepancy switch connected to a binary input, the
local control functions or via one of the serial interfaces), the automatic reclosure function is blocked for a
manual-close-blocking time T-BLOCK MC, address 3404. If a trip command occurs during this time, it can be
assumed that a metallic short-circuit is present (e.g. closed earth switch). Every trip command within this time
is therefore final. With the user definable logic functions (CFC) further control functions can be processed in
the same way as a manual–close command.
Interrogation of the Circuit Breaker Ready State
A precondition for automatic reclosure function following clearance of a short-circuit is that the circuit breaker
is ready for at least one OPEN-CLOSE-OPEN-cycle when the automatic reclosure circuit is started (i.e. at the
time of the first trip command). The readiness of the circuit breaker is signaled to the device via the binary
input
>CB1 Ready
(No. 371). If no such signal is available, the circuit breaker interrogation can be
suppressed (presetting of address 3402) as automatic reclosure function would otherwise not be possible at
all.
In the event of a single cycle reclosure this interrogation is usually sufficient. Since, for example, the air pres-
sure or the spring tension for the circuit breaker mechanism drops after the trip, no further interrogation
should take place.
For multiple reclosing attempts it is highly recommended to monitor the circuit breaker condition not only
prior to the first, but also before each following reclosing attempt. Reclosure will be blocked until the binary
input indicates that the circuit breaker is ready to complete another CLOSE-TRIP cycle.
The time needed by the circuit breaker to regain the ready state can be monitored by the 7SA522. This moni-
toring time CB TIME OUT (address 3409) starts as soon as the CB indicates the not ready state. The dead
time may be extended if the ready state is not indicated when it expires. However, if the circuit breaker does
not indicate its ready status for a longer period than the monitoring time, reclosure is dynamically blocked
(see also above under margin heading “Reclosure Blocking”).
Processing the circuit breaker auxiliary contacts
If the circuit breaker auxiliary contacts are connected to the device, the reaction of the circuit breaker is also
checked for plausibility.
In the case of 1-pole tripping this applies to each individual circuit breaker pole. This assumes that the auxiliary
contacts are connected to the appropriate binary inputs for each pole (
>CB1 Pole L1
, No. 366;
>CB1 Pole
L2
, No. 367;
>CB1 Pole L3
, No. 368).
If, instead of the individual pole auxiliary contacts, the series connections of the normally open and normally
closed contacts are used, the CB is assumed to have all three poles open when the series connection of the
normally closed contacts is closed (binary input
>CB1 3p Open
, No 411). All three poles are assumed closed
when the series connection of the normally open contacts is closed (binary input
>CB1 3p Closed
, No.
410). If none of these input indications is active, it is assumed that the circuit breaker is open at one pole
(even if this condition also exists theoretically when two poles are open).
The device continuously checks the position of the circuit breaker: As long as the auxiliary contacts indicate
that the CB is not closed (3-pole), the automatic reclosure function cannot be started. This ensures that a close
command can only be issued if the CB has previously tripped (out of the closed state).
The valid dead time begins when the trip command disappears or, in addition, when signals taken from the CB
auxiliary contacts indicate that the CB (pole) has opened.
If, after a 1-pole trip command, the CB has opened 3-pole, this is considered as a 3-pole tripping. If 3-pole
reclose cycles are allowed, the dead time for 3-pole tripping becomes active in the operating mode with trip
command (see margin heading “Operating modes of the automatic reclosure”, above). If 3-pole cycles are not
allowed, the reclosure is blocked dynamically. The trip command is final.
The latter also applies if the CB trips two poles following a 1-pole trip command. The device can only detect
this if the auxiliary contacts of each pole are connected individually. The device immediately initiates 3-pole
coupling which results in a 3-pole trip command.
If the CB auxiliary contacts indicate that at least one further pole has opened during the dead time after 1-pole
tripping, a 3-pole reclose cycle is initiated with the dead time for 3-pole reclosure provided that this is
permitted. If the auxiliary contacts are connected for each pole individually, the device can detect a two-pole
Functions
2.13 Automatic reclosure function (optional)
SIPROTEC 4, 7SA522, Manual 219
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open CB. In this case the device immediately sends a 3-pole trip command provided that the forced 3-pole trip
is activated (see Section 2.13.2 Setting Notes at margin heading “Forced 3-pole trip”).
Sequence of a 3-pole reclose cycle
If the automatic reclosure function is ready, the fault protection trips 3-pole for all faults inside the stage
selected for reclosure. The automatic reclosure function is started. When the trip command resets or the
circuit breaker opens (auxiliary contact criterion) an adjustable dead time starts. At the end of this dead time,
the circuit breaker receives a close command. At the same time, the (adjustable) dead time is started. If, when
configuring the protection functions, at address 134 AR control mode = with Pickup was set, different
dead times can be parameterised depending on the type of fault recognised by the protection.
If the fault is cleared (successful reclosure), the reclaim time expires and all functions return to their quiescent
state. The fault is cleared.
If the fault has not been eliminated (unsuccessful reclosure), the short-circuit protection initiates a final trip
following a protection stage active without reclosure. Any fault during the reclaim time leads to a final trip.
After unsuccessful reclosure (final tripping) the automatic reclosure function is blocked dynamically (see also
margin heading “Reclose Block”, above).
The sequence above applies for single reclosure cycles. In 7SA522 multiple reclosure (up to 8 shots) is also
possible (see below).
Sequence of a 1-pole reclose cycle
1-pole reclose cycles are only possible with the appropriate device version and if this was selected during the
configuration of the protection functions (address 110 Trip mode, see also Section 2.1.1.2 Setting Notes).
Of course, the circuit breaker must also be suitable for 1-pole tripping.
If the automatic reclosure function is ready, the short-circuit protection trips 1-pole for all 1-phase faults inside
the stage(s) selected for reclosure. Under the general settings (address 1156 Trip2phFlt, see also Section
2.1.4.1 Setting Notes) it can also be selected that 1-pole tripping takes place for two-phase faults without
earth. 1-pole tripping is of course only possible by short-circuit protection functions which can determine the
faulty phase.
If multiple-phase faults occur, the fault protection issues a final 3-pole trip with the stage that is valid without
reclosure. Any 3-pole trip is final. The automatic reclosure function is blocked dynamically (see also margin
heading “Blocking reclosure”, above).
The automatic reclosure function is started in the case of 1-pole tripping. The (adjustable) dead time for the 1-
pole reclose cycle starts with reset of the trip command or opening of the circuit breaker pole (auxiliary
contact criterion). After expiry of the dead time, the circuit breaker receives a close command. At the same
time, the (adjustable) reclaim time is started. If the reclosure is blocked during the dead time following a 1-
pole trip, immediate 3-pole tripping can take place as an option (forced 3-pole trip).
If the fault is cleared (successful reclosure), the reclaim time expires and all functions return to their quiescent
state. The fault is cleared.
If the fault has not been eliminated (unsuccessful reclosure), the short-circuit protection initiates a final 3-pole
trip with the protection stage that is valid without reclosure. All faults during the reclaim time also lead to a
final 3-pole trip.
After unsuccessful reclosure (final tripping) the automatic reclosure function is blocked dynamically (see also
margin heading “Reclose Block”, above).
The sequence above applies for single reclosure cycles. In 7SA522 multiple reclosure (up to 8 shots) is also
possible (see below).
Sequence of a 1-pole and 3-pole Reclose Cycle
This operating mode is only possible with the appropriate device version if selected during configuration of
the protection functions (address 110, see also Section 2.1.1.2 Setting Notes). Also, the circuit breaker must
be suitable for 1- pole tripping.
If the automatic reclosure function is ready, the short-circuit protection trips 1-pole for 1-phase faults and 3-
pole for multi-phase faults. Under the general settings (address 1156 Trip2phFlt, see also Section
2.1.4.1 Setting Notes) 1- pole tripping for two-phase faults without earth can be selected. 1-pole tripping is
Functions
2.13 Automatic reclosure function (optional)
220 SIPROTEC 4, 7SA522, Manual
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only possible for short-circuit protection functions that can determine the faulted phase. The valid protection
stage selected for reclosure ready state applies for all fault types.
The automatic reclosure function is started at the moment of tripping. Depending on the type of fault, the
(adjustable) dead time for the 1-pole reclose cycle or the (separately adjustable) dead time for the 3-pole
reclose cycle starts following the reset of the trip command or opening of the circuit breaker (pole) (auxiliary
contact criterion). After expiry of the dead time, the circuit breaker receives a close command. At the same
time, the (adjustable) reclaim time is started. If the reclosure is blocked during the dead time following a 1-
pole trip, immediate 3-pole tripping can take place as an option (forced 3-pole trip).
If the fault is cleared (successful reclosure), the reclaim time expires and all functions return to their quiescent
state. The fault is cleared.
If the fault has not been eliminated (unsuccessful reclosure), the short-circuit protection initiates a final 3-pole
trip with the protection stage that is valid without reclosure. All faults during the reclaim time also lead to a
final 3-pole trip.
After unsuccessful reclosure (final tripping), the automatic reclosure function is blocked dynamically (see also
margin heading “Reclose Block”, above).
The sequence above applies for single reclosure cycles. In 7SA522 multiple reclosure (up to 8 shots) is also
possible (see below).
Multiple reclosure
If a short-circuit still exists after a reclosure attempt, further reclosure attempts can be made. Up to 8 reclosure
attempts are possible with the automatic reclosure function integrated in the 7SA522.
The first four reclosure cycles are independent of each other. Each one has separate action and dead times,
can operate with 1- or 3-pole trip and can be blocked separately via binary inputs. The parameters and inter-
vention possibilities of the fourth cycle also apply to the fifth cycle and onwards.
The sequence is the same in principle as in the different reclosure programs described above. However, if the
first reclosure attempt was unsuccessful, the reclosure function is not blocked, but instead the next reclose
cycle is started. The appropriate dead time starts with the reset of the trip command or opening of the circuit
breaker (pole) (auxiliary contact criterion). The circuit breaker receives a new close command after expiry of
the dead time. At the same time the reclaim time is started.
The reclaim time is reset with each new trip command after reclosure and is started again with the next close
command until the set maximum number of permissible auto-reclose cycles has been reached.
If one of the reclosing attempts is successful, i.e. the fault disappeared after reclosure, the blocking time
expires and the automatic reclosing system is reset. The fault is cleared.
If none of the cycles is successful, the short-circuit protection initiates a final 3-pole trip after the last permis-
sible reclosure, following a protection stage that is valid without auto-reclosure. The automatic reclosing func-
tion is blocked dynamically (see also above under margin heading “Blocking the Reclosing Function”).
Handling Evolving Faults
When 1-pole or 1-and 3-pole reclose cycles are executed in the network, particular attention must be paid to
sequential faults.
Evolving faults are faults which occur during the dead time after clearance of the first fault.
There are various ways of handling sequential faults in the 7SA522depending on the requirements of the
network:
To detect an evolving fault, you can select either the trip command of a protection function during the dead
time or every further pickup as the criterion for an evolving fault.
There are also various selectable possibilities for the response of the internal auto- reclose function to a
detected evolving fault.
•EV. FLT. MODE blocks AR:
The reclosure is blocked as soon as a sequential fault is detected. The tripping by the sequential fault is
always 3-pole. This applies irrespective of whether 3-pole cycles have been permitted or not. There are
no further reclosure attempts; the automatic reclosure function is blocked dynamically (see also margin
heading “Blocking reclosure”, above).
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2.13 Automatic reclosure function (optional)
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•EV. FLT. MODE starts 3p AR:
As soon as a sequential fault is detected, the recloser switches to a 3-pole cycle. Each trip command is 3-
pole. The separately settable dead time for sequential faults starts with the clearance of the sequential
fault; after the dead time the circuit breaker receives a close command. The further sequence is the same
as for 1- and 3-pole cycles.
The complete dead time in this case consists of the part of the dead time for the 1-pole reclosure up to
the clearance of the sequential fault plus the dead time for the sequential fault. This makes sense
because the duration of the 3-pole dead time is most important for the stability of the network.
If reclosure is blocked due to a sequential fault without the protection issuing a 3-pole trip command (e.g. for
sequential fault detection with starting), the device can send a 3-pole trip command so that the circuit breaker
does not remain open with one pole (forced 3-pole trip).
Forced 3-pole trip
If reclosure is blocked during the dead time of a 1-pole cycle without a 3-pole trip command having been initi-
ated, the breaker would remain open at one pole. In most cases, the circuit breaker is equipped with a pole
discrepancy supervision which will trip the remaining poles after a few seconds. By setting a parameter, you
can achieve that the tripping logic of the device immediately sends a 3-pole trip command in this case. This
forced 3-pole trip pre-empts the pole discrepancy supervision of the CB because the forced 3-pole trip of the
device is initiated as soon as the reclosure is blocked following a 1-pole trip or if the CB auxiliary contacts
report an implausible breaker state.
When different internal protection functions initiate a 1-pole trip in different phases, the device will issue a 3-
pole trip command due to the tripping logic (Section 2.20.1 Function Control), independent of this forced 3-
pole trip. This is also true for trip commands given via the direct local trip inputs (Section 2.10 External direct
and remote tripping) or the reception of a remote trip (Section 2.5 Remote signals via protection data inter-
face (optional)) since these signals directly affect the tripping logic of the device.
If the device trips 1-pole and if an external trip command in another phase only reaches the device via one of
the binary inputs, e.g.
>Trip L1 AR
to the internal automatic reclosure function, this is not routed to the
tripping logic. In this case, 3-pole trip is ensured only if the forced 3-pole trip is effective.
The forced 3-pole trip is also activated when only 3-pole cycles are allowed, but a 1-pole trip is signalled exter-
nally via a binary input.
Dead Line Check (DLC)
If the voltage of a disconnected phase does not disappear following a trip, reclosure can be prevented. A
prerequisite for this function is that the voltage transformers are connected on the line side of the circuit
breaker. To select this function the dead line check must be activated. The automatic reclosure function then
checks the disconnected line for no-voltage: the line must have been without voltage for at least an adequate
measuring time during the dead time. If this was not the case, the reclosure is blocked dynamically.
This no-voltage check on the line is of advantage if a small generator (e.g. wind generator) is connected along
the line.
Reduced Dead Time (RDT)
If automatic reclosure function is performed in connection with time-graded protection, non-selective tripping
before reclosure is often unavoidable in order to achieve fast, simultaneous tripping at all line ends. 7SA522
has a “reduced dead time (RDT” procedure which reduces the effect of the short-circuit on healthy line sections
to a minimum. All phase-to-phase and phase-to-earth voltages are measured for the reduced dead time proce-
dure. These voltages must rise above the threshold U-live> (address 3440) for the voltage measuring time T
U-stable (address 3438). The value set for U-live> is appropriately converted for the phase-to-phase
voltages. The voltage transformers must be located on the line side of the circuit breaker.
In the event of a short-circuit close to one of the line ends, the surrounding lines can initially be tripped
because, for example, a distance protection detects the fault in its overreaching zone Z1B (Figure 2-112,
mounting location III). If the network is meshed and there is at least one other infeed on busbar B, the voltage
there returns immediately after clearance of the fault. For 1-pole tripping it is sufficient if there is an earthed
transformer with delta winding connected at busbar B which ensures symmetry of the voltages and thus
induces a return voltage in the open phase. This allows a distinction between the faulty line and the unfaulted
line to be made as follows:
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Since line B - C is only tripped singled-ended at C, it receives a return voltage from the end B which is not
tripped so that at C the open phase(s) also has(have) voltage. If the device detects this at position III, reclosure
can take place immediately or in a shorter time (to ensure sufficient voltage measuring time). The healthy line
B - C is then back in operation.
Line A–B is tripped at both ends. No voltage is therefore present identifying the line as the faulted one at both
ends. The normal dead time comes into service here.
[beispiel-verkuerzte-we-wlk-310702, 1, en_GB]
Figure 2-112 Example of a reduced dead time (RDT)
A, B, C Busbars
I, II, III Relay locations
X Tripped circuit breakers
Adaptive Dead Time (ADT)
In all the previous alternatives it was assumed that defined and equal dead times were set at both line ends, if
necessary for different fault types and/or reclose cycles.
It is also possible to set the dead times (for different fault types and/or reclose cycles, if necessary) at one line
end only and to configure the adaptive dead time at the other end(s). This requires that the voltage trans-
formers are located on the line side of the circuit breaker or that a close command can be sent to the remote
line end.
Figure 2-113 shows an example with voltage measurement. It is assumed that device I operates with defined
dead times whereas the adaptive dead time is configured at position II. It is important that the line is at least
fed from busbar A, i.e. the side with the defined dead times.
When using the adaptive dead time, the automatic reclosing function at line end II decides autonomously
whether to allow reclosing or not. Its decision is based on the line voltage at end II, which was reapplied from
end I following reclosure. Device II will thus initiate reclosing as soon as it is evident that the line has been
reenergized from end I. All phase-to-phase and phase-to-earth voltages are monitored.
In the illustrated example, the lines are disconnected at positions I, II and III. In I reclosure takes place after the
configured dead time. At position III a reduced dead time can be used (see above) if there is also an infeed on
busbar B.
If the fault has been cleared (successful reclosure), line A - B is re-connected to the voltage at busbar A
through position I. Device II detects this voltage and also recloses after a short delay (to ensure a sufficient
voltage measuring time). The fault is cleared.
If the fault has not been cleared after reclosure at I (unsuccessful reclosure), the line will be disconnected
again in position I with the result that no healthy voltage is detected at location II so that the circuit breaker
there does not reclose.
In the case of multiple reclosure the sequence may be repeated several times following an unsuccessful reclo-
sure until one of the reclosure attempts is successful or a final trip takes place.
Functions
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[beispiel-asp-wlk-310702, 1, en_GB]
Figure 2-113 Example of adaptive dead time (ADT)
A, B, C Busbars
I, II, III Relay locations
X Tripped circuit breakers
As is shown by the example, the adaptive dead time has the following advantages:
•The circuit breaker at position II is not reclosed if the fault persists and is not unnecessarily stressed as a
result.
•With non-selective tripping by overreach at position III no further trip and reclose cycles occur here
because the short-circuit path via busbar B and position II remains interrupted even in the event of
several reclosure attempts.
•At position I overreach is allowed in the case of multiple reclosures and even in the event of final tripping
because the line remains open at position II and therefore no actual overreach can occur at I.
The adaptive dead time also includes the reduced dead time because the criteria are the same. There is no
need to set the reduced dead time as well.
CLOSE Command Transmission (Remote-CLOSE)
With close command transmission via the digital connection paths the dead times are only set at one line end.
The other line end (or line ends in lines with more than two ends) is set to “Adaptive Dead Time (ADT)”. The
latter merely responds to the close commands received from the transmitting end.
At the sending line end, the transmission of the close command is delayed until it is sure that the local reclo-
sure was successful. This means that the device waits whether a local pickup still occurs after reclosing. This
delay prevents unnecessary closing at the remote end on the one hand but also increases the time until reclo-
sure takes place there. This is not critical for a 1-pole interruption or in radial or meshed networks if no
stability problems are expected under these conditions.
[awe-inter-ein-ws-wlk-310702, 1, en_GB]
Figure 2-114 AR Remote-Close function via protection data interface
The close command can be transmitted by a teleprotection scheme using the protection data interfaces
(ordering variant). When the indication
AR Remote Close
is output, this information is transmitted at the
same time to the remote end via the protection data interface. The information is ORed with the information
of the binary input
>AR RemoteClose
and made available to the automatic reclosure function.
(Figure 2-114).
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2.13 Automatic reclosure function (optional)
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Connecting an External Auto-Reclosure Device
If the 7SA522 has to work with an external reclosure device, the binary inputs and outputs provided for this
purpose must be taken into consideration. The following inputs and outputs are recommended:
Binary inputs:
383
>Enable ARzones
With this binary input, the external reclosure device controls stages of the indi-
vidual short-circuit protection functions which are active before reclosure (e.g.
overreaching zone in the distance protection). This input is not required if no
overreaching stage is used (e.g. differential protection or comparison mode with
distance protection, see also above margin heading “Selectivity before Reclo-
sure”).
382
>Only 1ph AR
The external reclosure device is only programmed for 1 pole; the stages of the
individual protection functions that are activated before reclosure via No. 383
only do so in the case of 1-phase faults; in the event of multiple-phase faults
these stages of the individual short-circuit protection functions do not operate.
This input is not required if no overreaching stage is used (e.g. differential protec-
tion or comparison mode with distance protection, see also margin heading
“Selectivity before Reclosure”, above).
381
>1p Trip Perm
The external reclosure device allows 1-pole tripping (logic inversion or 3- pole
coupling). If this input is not assigned or not routed (matrix), the protection func-
tions trip 3-pole for all faults. If the external reclosure device cannot supply this
signal but supplies a “3-pole coupling” signal instead, this must be taken into
account in the allocation of the binary inputs: the signal must be inverted in this
case (L-active = active without voltage).
Binary outputs:
501
Relay PICKUP
Start of protection device, general (if required by external recloser device).
512
Relay TRIP 1pL1
Trip of the device 1-pole L1.
513
Relay TRIP 1pL2
Trip of the device 1-pole L2.
514
Relay TRIP 1pL3
Trip of the device 1-pole L3.
515
Relay TRIP 3ph.
Trip of the device 3-pole.
Figure 2-115 for example, shows the interconnection between a 7SA522 and an external reclosure device
with a mode selector switch.
Depending on the external reclosure device requirements, the three 1-pole indications (No. 512, 513, 514)
can be combined to one “1-pole tripping” output; No. 515 sends the “3-pole tripping” signal to the external
device.
In case of exclusively 3-pole reclose cycles, the general pickup signal (No. 501, if required by the external
reclosure device) and trip signal (No. 511) of 7SA522 (see Figure 2-116) are usually sufficient.
Functions
2.13 Automatic reclosure function (optional)
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[anschlussbsp-ext-weger-1-o-3-pol-we-wlk-310702, 1, en_GB]
Figure 2-115 Connection example with external auto-reclosure device for 1-/3-pole AR with mode selector
switch
[anschlussbsp-ext-weger-3-pol-we-wlk-310702, 1, en_GB]
Figure 2-116 Connection example with external reclosure device for 3-pole AR
Control of the internal automatic reclosure by an external protection device
If the 7SA522 is equipped with the internal automatic reclosure function, this can also be controlled by an
external protection device. This is of use, for example, on line ends with redundant protection or additional
back-up protection when the second protection is used for the same line end and has to work with the auto-
matic reclosure function integrated in the 7SA522.
The binary inputs and outputs provided for this functionality must be considered in this case. It must be
decided whether the internal automatic reclosure function is to be controlled by the starting (pickup) or by the
trip command of the external protection (see also above under “Control Mode of the Automatic Reclosure”).
If the automatic reclosure function is controlled by the trip command, the following inputs and outputs are
recommended:
The automatic reclosure function is started via the Binary inputs:
2711
>AR Start
Generalanregung für die Wiedereinschaltautomatik (nur für Wirkzeit benötigt),
2712
>Trip L1 AR
Auslösekommando L1 für die Wiedereinschaltautomatik,
2713
>Trip L2 AR
Auslösekommando L2 für die Wiedereinschaltautomatik,
2714
>Trip L3 AR
Auslösekommando L3 für die Wiedereinschaltautomatik.
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The general pickup is decisive for starting the action times. It is also required if the automatic reclosing func-
tion has to detect sequential faults via pickup. In other cases, this input information is irrelevant.
The trip commands decide whether the dead time is activated for 1-pole or 3-pole reclose cycles or whether
the reclosure is blocked in the event of a 3-pole trip (depending on the configured dead times).
Figure 2-117 shows the interconnection between the internal automatic reclosure function of the 7SA522 and
an external protection device, as a connection example for 1-pole cylces.
To achieve 3-pole coupling of the external protection and to release, if necessary, its accelerated stages before
reclosure, the following output functions are suitable:
2864
AR 1p Trip Perm
Internal automatic reclosure function ready for 1-pole reclose cycle, i.e. allows
1-pole tripping (logic inversion of the 3-pole coupling).
2889
AR 1.CycZoneRel
Internal automatic reclosure function ready for the first reclose cycle, i.e.
releases the stage of the external protection device for reclosure, the corre-
sponding outputs can be used for other cycles. This output can be omitted if
the external protection does not require an overreaching stage (e.g. differential
protection or comparison mode with distance protection).
2820
AR Program1pole
Internal automatic reclosure function is programmed for one pole, i.e. only
recloses after 1-pole tripping. This output can be omitted if no overreaching
stage is required (e.g. differential protection or comparison mode with distance
protection).
Instead of the 3-phase-segregated trip commands, the 1-pole and 3-pole tripping may also be signalled to the
internal automatic reclosure function - provided that the external protection device is capable of this -, i.e.
assign the following binary inputs of the 7SA522:
2711
>AR Start
General fault detection for the internal automatic reclosure function (only
required for action time),
2715
>Trip 1pole AR
Trip command 1-pole for the internal automatic reclosure function,
2716
>Trip 3pole AR
Trip command 3-pole for the internal automatic reclosure function.
If only 3-pole reclosure cycles are to be executed, it is sufficient to assign the binary input
>Trip 3pole AR
(No. 2716) for the trip signal. Figure 2-118 shows an example. Any overreaching stages of the external protec-
tion are enabled again by
AR 1.CycZoneRel
(No. 2889) and of further cycles, if applicable.
[anschlussbsp-ext-schutzger-1-o-3-pol-we-wlk-310702, 1, en_GB]
Figure 2-117 Connection example with external protection device for 1-/3-pole reclosure; AR control mode =
with TRIP
Functions
2.13 Automatic reclosure function (optional)
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[anschlussbsp-ext-schutzger-3-pol-we-wlk-310702, 1, en_GB]
Figure 2-118 Connection example with external protection device for 3-pole reclosure; AR control mode =
with TRIP
But if the internal automatic reclose function is controlled by the pickup (only possible for 3-pole tripping: 110
Trip mode = 3pole only), the phase-selective pickup signals of the external protection must be connected
if distinction shall be made between different types of fault. The general trip command then suffices for trip-
ping (No. 2746). Figure 2-119 shows a connection example.
[anschlussbsp-ext-schutzger-fehlerab-pause-wlk-310702, 1, en_GB]
Figure 2-119 Connection example with external protection device for fault detection dependent dead time
— dead time control by pickup signals of the protection device; AR control mode = with
PICKUP
2 Protection Relays with 2 Automatic Reclosure Circuits
If redundant protection is provided for a line and each protection operates with its own automatic reclosure
function, a certain signal exchange between the two combinations is necessary. The connection example in
Figure 2-120 shows the necessary cross-connections.
If the auxiliary contacts of the circuit breaker are connected to the correct phases, a 3-pole coupling by the
7SA522 is ensured when more than one CB pole is tripped. This requires the activation of the forced 3-pole
trip (see Section 2.13.2 Setting Notes at margin heading “Forced 3-pole trip”). An external automatic 3-pole
Functions
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coupling is therefore unnecessary if the above conditions are met. This prevents 2-pole tripping under all
circumstances.
For the connection according to Figure 2-120 it must be considered that the cross connections to the second
protection must be interrupted during the check of one of the two protection systems with protection moni-
toring equipment. This is done, for example, by means of a test switch installed in between.
Alternatively, the variant with a minimum cross connection according to Figure 2-121 can be applied. In this
case, the following information should be considered:
•The switching state of the circuit breaker must be connected in a phase-selective way via the auxiliary
contacts to the corresponding binary inputs of both protection systems in case of a 1-pole reclosure. If
only 3- pole tripping is possible, the 3-pole status is sufficient.
•In order to prevent that a very quick response (1-pole) of a protection leads to an undesired 3-pole
coupling of a second protection, a “software filter time” for the binary inputs of the auxiliary contacts is to
be set (refer to Figure 2-122).
[anschlussbsp-2-schutzeinri-2-wes-wlk-310702, 1, en_GB]
Figure 2-120 Connection example for 2 protection devices with 2 automatic reclosure functions
BI Binary inputs
M Signal output
K Command
*) for all protection functions operating with AR.
Functions
2.13 Automatic reclosure function (optional)
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[anschlussbsp-2-schutzger-int-awe-100413, 1, en_GB]
Figure 2-121 Connection example for 2 protection devices with internal automatic reclosure function and
minimum cross connection
[digsi-einstellung-sw-filterzeit-090410-wlk, 1, en_GB]
Figure 2-122 Setting of the software filter time
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Setting Notes
General
If no reclosure is required on the feeder to which the 7SA522 distance protection is applied (e.g. for cables,
transformers, motors or similar), the automatic reclosure function must be inhibited during configuration of
the device (see Section 2.1.1.2 Setting Notes, address 133). The automatic reclosure function is then fully
disabled, i.e. the automatic reclosure is not processed in the 7SA522. No signals regarding the automatic
reclosure function are generated, and the binary inputs for the automatic reclosure function are ignored. All
settings of the automatic reclosure function are inaccessible and of no significance.
But if the internal automatic reclosure function is to be used, the type of reclosure must be selected during the
configuration of the device functions (see Section 2.1.1.2 Setting Notes) in address 133 Auto Reclose and
in address 134 die AR control mode mode.
Up to 8 reclosure attempts are allowed with the integrated automatic reclosure function in the 7SA522.
Whereas the settings in address 3401 to 3441 are common to all reclosure cycles, the individual settings of
the cycles are made from address 3450 onwards. It is possible to set different individual parameters for the
first four reclose cycles. From the fifth cycle on the parameters for the fourth cycle apply.
The automatic reclosing function can be turned ON- or OFF under address 3401 AUTO RECLOSE.
A prerequisite for automatic reclosure taking place after a trip due to a short-circuit is that the circuit breaker is
ready for at least one OPEN-CLOSE-OPEN cycle at the time the automatic reclosure circuit is started, i.e. at the
time of the first trip command. The readiness of the circuit breaker is signalled to the device via the binary
input
>CB1 Ready
(No. 371). If no such signal is available, leave the setting under address 3402 CB?
1.TRIP = NO because no automatic reclosure would be possible at all otherwise. If circuit breaker interroga-
tion is possible, you should set CB? 1.TRIP = YES.
Furthermore, the circuit breaker ready state can also be interrogated prior to every reclosure. This is set when
setting the individual reclose cycles (see below).
To check that the ready status of the circuit breaker is regained during the dead times, you can set a circuit
breaker ready monitoring time under address 3409 CB TIME OUT. The time is set slightly longer than the
recovery time of the circuit breaker after an OPEN-CLOSE-OPEN cycle. If the circuit breaker is not ready again
by the time this timer expires, no reclosure takes place and the automatic reclosure function is blocked
dynamically.
Waiting for the circuit breaker to be ready can cause an increase of the dead times. Interrogation of a
synchronism check (if used) can also delay reclosure. To avoid uncontrolled prolongation, it is possible to set a
maximum prolongation of the dead time in this case in address 3411 T-DEAD EXT.. This prolongation is
unlimited if the setting ∞ is applied. This parameter can only be altered in DIGSI at Display Additional
Settings. Remember that longer dead times are only permissible after 3-pole tripping when no stability prob-
lems occuror a synchronism check takes place before reclosure.
T-RECLAIM (address 3403) is the time after which the fault is considered eliminated following successful
reclosure. If a protection function provokes a new trip before this time has elapsed, the next reclosing cycle is
started in case of multiple reclosure. If no further reclosing attempt is allowed, the last reclosure will be
considered failed in the event of a new trip. The reclaim time must therefore be longer than the longest
response time of a protection function which can start the automatic reclosure function. When operating the
AR in ADT mode, it is possible to deactivate the reclaim time by setting it to 0 s.
A few seconds are generally sufficient. In areas with frequent thunderstorms or storms, a shorter blocking
time may be necessary to avoid feeder lockout due to sequential lightning strikes or cable flashovers.
A longer reclaim time should be chosen where circuit breaker supervision is not possible (see above) during
multiple reclosures, e.g. because of missing auxiliary contacts and information on the circuit breaker ready
status. In this case, the reclaim time should be longer than the time required for the circuit breaker mecha-
nism to be ready.
The blocking duration following manual-close detection T-BLOCK MC (address 3404) must ensure the circuit
breaker to open and close reliably (0.5 s to 1 s). If a fault is detected by a protection function within this time
after closing of the circuit breaker was detected, no reclosure takes place and a final 3-pole trip command is
issued. If this is not desired, address 3404 is set to 0.
The options for handling evolving faults are described in Section 2.13 Automatic reclosure function (optional)
under margin heading “Handling Evolving Faults”. The treatment of sequential faults is not necessary on line
2.13.2
Functions
2.13 Automatic reclosure function (optional)
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ends where the adaptive dead time is applied (address 133 Auto Reclose = ADT). The addresses 3406 and
3407 are then of no consequence and therefore not accessible.
The detection of an evolving fault can be defined under address 3406 EV. FLT. RECOG.. EV. FLT.
RECOG. with PICKUP means that, during a dead time, every pickup of a protection function will be inter-
preted as an evolving fault. With EV. FLT. RECOG. with TRIP a fault during a dead time is only inter-
preted as an evolving fault if it has led to a trip command by a protection function. This may also include trip
commands which are received from an external device via a binary input or which have been transmitted from
another end of the protected object. If an external protection device operates together with the internal auto-
reclosure, evolving fault detection with pickup presupposes that a pickup signal from the external device is
also connected to the 7SA522; otherwise an evolving fault can only be detected with the external trip
command even if with PICKUP was set here.
The reaction in response to sequential faults can be selected at address 3407. EV. FLT. MODE blocks AR
means that no reclosure is performed after detection of a sequential fault. This is always useful when only 1-
pole reclosure is to take place or when stability problems are expected due to the subsequent 3-pole dead
time. If a 3-pole reclose cycle is to be initiated by tripping of the sequential fault, set EV. FLT. MODE =
starts 3p AR. In this case a separately adjustable 3-pole dead time is started with the 3-pole trip command
due to the sequential fault. This is only useful if 3-pole reclosure is also permitted.
Address 3408 T-Start MONITOR monitors the reaction of the circuit breaker after a trip command. If the CB
has not opened during this time (from the beginning of the trip command), the automatic reclosure is blocked
dynamically. The criterion for circuit breaker opening is the position of the circuit breaker auxiliary contact or
the disappearance of the trip command. If a circuit breaker failure protection (internal or external) is used on
the feeder, this time should be shorter than the delay time of the circuit breaker failure protection so that no
reclosure takes place if the circuit breaker fails.
i
i
NOTE
If the circuit breaker failure protection (BF) should perform a 1-pole TRIP repetition, the time setting of
parameter 3408 T-Start MONITOR must be longer than the time set for parameter 3903 1p-RETRIP
(T1).
To enable that the busbar is tripped by the circuit breaker failure protection without preceding 3-pole
coupling of the trip command (by AR or BF), the time set for 3408 T-Start MONITOR also has to be
longer than the time set for 3906 T2. In this case, the AR must be blocked by a signal from the BF to
prevent the AR from reclosing after a busbar TRIP. It is recommended to connect the signal 1494
BF T2-
TRIP(bus)
to the AR input 2703
>AR block
via CFC.
If the reclosure command is transmitted to the opposite end, this transmission can be delayed by the time
setting in address 3410 T RemoteClose. This transmission is only possible if the device operates with adap-
tive dead time at the remote end (address 133 Auto Reclose = ADT). This parameter is otherwise irrelevant.
On the one hand, this delay serves to prevent the remote end device from reclosing unnecessarily when local
reclosure is unsuccessful. On the other hand, it should be noted that the line is not available for energy trans-
port until the remote end has also closed. Therefore this delay must be added to the dead time for considera-
tion of the network stability.
Configuration of auto-reclosure
This configuration concerns the interaction between the protection and supplementary functions of the device
and the automatic reclosure function. Here, you can determine which functions of the device should start the
automatic reclosure and which not.
address 3420 AR w/ DIST., i.e. with distance protection
address 3421 AR w/ SOTF-O/C, i.e. with high-current fast tripping
address 3422 AR w/ W/I, i.e. with weak–infeed trip function
address 3423 AR w/ EF-O/C, i.e. with earth fault protection for earthed systems
address 3424 AR w/ DTT, i.e. with externally fed trip command
address 3425 AR w/ BackUpO/C, i.e. with time overcurrent protection
Functions
2.13 Automatic reclosure function (optional)
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For the functions which should start the auto-reclosure function, the corresponding address is set to YES, for
the others to NO. The other functions cannot start the automatic reclosure because reclosure is not reasonable
here.
Forced 3-pole trip
If a blocking of the auto-reclosure occurs during the dead time of a 1-pole cycle without a previous 3-pole trip
command, the circuit breaker remains open at one pole. With address 3430 AR TRIP 3pole it is possible to
determine that the tripping logic of the device issues a 3-pole trip command in this case (pole discrepancy
prevention for the CB poles). Set this address to YES if the CB can be tripped 1-pole and if it has no pole
discrepancy protection. Nevertheless, the device preempts the pole discrepancy supervision of the CB because
the forced 3-pole trip of the device is immediately initiated as soon as the reclosure is blocked following a 1-
pole trip or if the CB auxiliary contacts report an implausible circuit breaker state (see also Section 2.13 Auto-
matic reclosure function (optional) at margin heading “Processing the circuit breaker auxiliary contacts”). The
forced 3-pole trip is also activated when only 3-pole cycles are allowed, but a 1-pole trip is signaled externally
via a binary input.
The forced 3-pole trip is unnecessary if only a common 3-pole control of the CB is possible.
Dead line check / Reduced dead time
Under 3431 the dead line check or the reduced dead time function can be activated. Either the one or the
other can be used as the two options are contradictory. The voltage transformers must be connected to the
line side of the circuit breaker if either of these modes is to be used. If this is not the case or if neither of the
two functions is used, set DLC or RDT = WITHOUT. If the adaptive dead time is used (see below), the param-
eters mentioned here are omitted because the adaptive dead time implies the properties of the reduced dead
time.
DLC or RDT = DLC means that the dead line check of the line voltage is used. It only allows reclosing after it
has been verified in advance that the line is dead. In this case, the phase-to-earth voltage limit is set in address
3441 U-dead< below which the line is considered voltage-free (disconnected). The setting is applied in Volts
secondary. This value can be entered as a primary value when parameterizing with a PC and DIGSI. Address
3438 T U-stable determines the measuring time available for determining the no-voltage condition.
Address 3440 is irrelevant here.
DLC or RDT = RDT means that the reduced dead time is used. This is described in detail in Section
2.13 Automatic reclosure function (optional) at margin heading “Reduced Dead Time (RDT)”. In this case, the
phase-to-earth voltage limit is set in address 3440 U-live> above which the line is considered fault-free. The
setting must be smaller than the lowest expected operating voltage. The setting is applied in Volts secondary.
This value can be entered as a primary value when parameterizing with a PC and DIGSI. Address 3438 T U-
stable defines the measuring time used to determine the voltage. It should be longer than any transient
oscillations resulting from line energization. Address 3441 is irrelevant here.
Adaptive dead time (ADT)
When operating with adaptive dead time, it must be ensured in advance that one end per line operates with
defined dead times and has an infeed. The other (or the others in multi-branch lines) may operate with adap-
tive dead time. It is essential that the voltage transformers are located on the line side of the circuit breaker.
Details about this function can be found in Section 2.13 Automatic reclosure function (optional) at margin
heading “Adaptive Dead Time (ADT) and Close Command-transfer (Remote-CLOSE)”.
For the line end with defined dead times the number of desired reclose cycles must be set during the configu-
ration of the protection functions (Section 2.1.1 Functional Scope) in address 133 Auto Reclose. For the
devices operating with adaptive dead time Auto Reclose = ADT must be set during the configuration of the
protection functions under address 133. Only the parameters described below are interrogated in the latter
case. No settings are then made for the individual reclosure cycles. The adaptive dead time implies function-
ality of reduced dead time.
The adaptive dead time may be voltage-controlled or Remote–CLOSE–controlled. Both are possible at the
same time. In the first case, reclosure takes place as soon as the returning voltage, after reclosure at the
remote end, is detected. For this purpose the device must be connected to voltage transformers located on
the line side. In the case of Remote-CLOSE, the autoreclosure waits until the Remote-CLOSE command is
received from the remote end.
Functions
2.13 Automatic reclosure function (optional)
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The action time T-ACTION ADT (address 3433) is started after any protection function has triggered the
automatic reclosing function. The trip command must occur during this time. If no trip command is issued
until the action time has expired, reclosing will not be initiated. Depending on the configuration of the protec-
tion functions (see Section 2.1.1.2 Setting Notes), the action time may also be omitted; this applies especially
when an initiating protection function has no fault detection signal.
The dead times are determined by the reclosure command of the device at the line end with the defined dead
times. In cases where this reclosure command does not appear, e.g. because the reclosure was in the mean-
time blocked at this end, the readiness of the local device must return to the quiescent state at some time.
This takes place after the maximum wait time T-MAX ADT (address 3434). It must be long enough to include
the last reclosure of the remote end. In the case of single-shot reclosing, the sum of the maximum dead time
plus reclaim time of the other device is sufficient. In the case of multiple reclosure, the worst case is that all
reclosures of the other end except the last one are unsuccessful. The time of all these cycles must be taken
into account. To save having to make exact calculations, it is possible to use the sum of all dead times and all
protection operating times plus one reclaim time.
Under address 3435 ADT 1p allowed allowed it can be determined whether 1-pole tripping is allowed
(provided that 1-pole tripping is possible). If NO, the protection trips 3-pole for all fault types. If YES, the actual
trip signal of the starting protection functions is decisive. If the reclaim time is unequal to 0 s and 1-pole trip-
ping is allowed, 1- pole tripping will be prevented during the reclaim time. Each fault is thus disconnected in
three poles while the reclaim time is active.
Address 3403 T-RECLAIM allows disabling the reclaim time in ADT mode. In doing so, the ADT cycle including
its settings and release conditions is restarted after unsuccessful automatic reclosing. If the reclaim time is
activated, the 1-pole trip permission at address 3435 and the protection releases are disabled while the
reclaim time is running.
Under address 3436 ADT CB? CLOSE it can be determined whether circuit breaker ready is interrogated
before reclosure after an adaptive dead time. With the setting YES, the dead time may be extended if the
circuit breaker is not ready for a CLOSE–OPEN–cycle when the dead time expires. The maximum extension
that is possible is the circuit breaker monitoring time; this was set for all reclosure cycles under address 3409
(see above). Details about the circuit breaker monitoring can be found in the function description, Section
2.13 Automatic reclosure function (optional), at margin heading “Interrogation of the Circuit Breaker Ready
State”.
If there is a danger of stability problems in the network during a 3-pole reclosure cycle, set address 3437 ADT
SynRequest to YES. In this case a check is made before reclosure following a 3-pole trip whether the
voltages of feeder and busbar are sufficiently synchronous. This is only done on condition that either the
internal synchronism and voltage check functions are available, or that an external device is available for
synchronism and voltage check. If only 1-pole reclose cycles are executed or if no stability problems are
expected during 3-pole dead times (e.g. due to closely meshed networks or in radial networks), set address
3437 to NO.
Addresses 3438 and 3440 are only significant if the voltage-controlled adaptive dead time is used. 3440 U-
live> is the phase-to-earth voltage limit above which the line is considered to be fault-free. The setting must
be smaller than the lowest expected operating voltage. The setting is applied in volts secondary. This value
can be entered as a primary value when parameterising with a PC and DIGSI. Address 3438 T U-stable
defines the measuring time used to determine the voltage. It should be longer than any transient oscillations
resulting from line energization.
1st reclose cycle
If working on a line with adaptive dead time, no further parameters are needed for the individual reclose
cycles in this case. All the following parameters assigned to the individual cycles are then superfluous and
inaccessible.
Address3450 1.AR: STARTis only available if the automatic reclosing function works in the operating mode
with action time, i.e. is set during configuration of the protection functions (see Section 2.1.1.2 Setting Notes)
Address 134 AR control mode = Pickup w/ Tact or Trip w/ Tact (the first setting only applies to 3-
pole tripping). It determines whether automatic reclosure should be started at all with the first cycle. This
address is included mainly due to the uniformity of the parameters for every reclosure attempt and is set to
YES for the first cycle. If several cycles are performed, you can (at AR control mode = Trip ...) set this
parameter and different action times to control the effectiveness of the cycles. In Section 2.13 Automatic
reclosure function (optional) notes and examples are at margin heading “Action times”.
Functions
2.13 Automatic reclosure function (optional)
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The action time 1.AR: T-ACTION (address 3451) is started after a protection function has triggered the
automatic reclosing function. The trip command must occur during this time. If no trip command is issued
until the action time has expired, reclosing will not be initiated. Depending on the configuration of the protec-
tion functions, the action time may also be omitted; this applies especially when an initiating protection func-
tion has no fault detection signal.
Depending on the configured operating mode of the automatic reclosure (address 134 AR control mode)
only the addresses 3456 and 3457 (if AR control mode = TRIP...) or the addresses 3453 to 3455 are
available (if AR control mode = Pickup. ...).
In AR control mode = TRIP ... you can set different dead times for 1-pole and 3-pole reclose cycles.
Whether 1-pole or 3-pole tripping is triggered depends solely on the initiating protection functions. 1-pole trip-
ping is of course only possible if the device and the corresponding protection function are also capable of 1-
pole tripping:
Table 2-7 AR control mode = TRIP ...
3456 1.AR Tdead1Trip is the dead time after 1-pole tripping.
3457 1.AR Tdead3Trip is the dead time after 3-pole tripping.
If you only want to allow a 1-pole reclose cycle, set the dead time for 3-pole tripping to ∞. If you only want to
allow a 3-pole reclose cycle, set the dead time for 1-pole tripping to ∞, the protection then trips 3-pole for
each fault type.
The dead time after 1-pole tripping (if set) 1.AR Tdead1Trip (address 3456) should be long enough for the
short-circuit arc to be extinguished and the surrounding air to be de-ionized so that the reclosure promises to
be successful. The longer the line, the longer is this time due to the charging of the conductor capacitances.
Standard durations are between 0.9 s and 1.5 s.
For 3-pole tripping (address 3457 1.AR Tdead3Trip) the network stability is the main concern. Since the
disconnected line cannot transfer any synchronizing forces, only a short dead time is often permitted. Usual
values are 0.3 s to 0.6 s. If the device is operating with a synchronism check (compare Section
2.14 Synchronism and voltage check (optional)) a longer time may be tolerated under certain circumstances.
Longer 3-pole dead times are also possible in radial networks.
For AR control mode = TRIP ... it is possible to make the dead times dependent on the type of fault
detected by the initiating protection function(s).
Table 2-8 AR control mode = Trip ...
3453 1.AR Tdead 1Flt is the dead time after 1-phase pickup.
3454 1.AR Tdead 2Flt is the dead time after 2-phase pickup.
3455 1.AR Tdead 3Flt is the dead time after 3-phase pickup.
If the dead time is to be the same for all fault types, set all three parameters the same. Note that these settings
only cause different dead times for different pickups. The tripping can only be 3-pole.
If, when setting the reaction to sequential faults (see above at “General”) you have set address 3407 EV.
FLT. MODE starts 3p AR you can set a separate dead time for the 3-pole dead time after clearance of the
sequential fault 1.AR: Tdead EV. (address 3458). Stability aspects are also decisive here. Normally the
setting constraints are similar to address3457 1.AR Tdead3Trip.
Under address 3459 1.AR: CB? CLOSE it can be determined whether the readiness of the circuit breaker
("circuit breaker ready") is interrogated before this first reclosure. With the setting YES, the dead time may be
extended if the circuit breaker is not ready for a CLOSE–OPEN–cycle when the dead time expires. The
maximum extension that is possible is the circuit breaker monitoring time; this was set for all reclosure cycles
under address 3409 CB TIME OUT (see above). Details about the circuit breaker monitoring can be found in
the function description, Section 2.13 Automatic reclosure function (optional), at margin heading “Interroga-
tion of the Circuit Breaker Ready State”.
If there is a danger of stability problems in the network during a 3-pole reclosure cycle, set address3460 1.AR
SynRequest to YES. In this case, it is verified before each reclosure following a 3-pole trip whether the
voltages of feeder and busbar are sufficiently synchronous. This is only done on condition that either the
internal synchronism and voltage check functions are available, or that an external device is available for
synchronism and voltage check. If only 1-pole reclose cycles are executed or if no stability problems are
Functions
2.13 Automatic reclosure function (optional)
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expected during 3-pole dead times (e.g. due to closely meshed networks or in radial networks), set
address3460 to NO.
2nd to 4th Reclose Cycle
If several cycles have been set in the configuration of the scope of protection functions, you can set individual
reclosure parameters for the 2nd to 4th cycles. The same options are available as for the first cycle. Again, only
some of the parameters shown below will be available depending on the selections made during configura-
tion of the scope of protection functions.
For the 2nd cycle:
3461 2.AR: START Start in 2nd cycle generally allowed
3462 2.AR: T-ACTION Action time for the 2nd cycle
3464 2.AR Tdead 1Flt Dead time after 1-phase pickup
3465 2.AR Tdead 2Flt Dead time after 2-phase pickup
3466 2.AR Tdead 3Flt Dead time after 3-phase pickup
3467 2.AR Tdead1Trip Dead time after 1-pole tripping
3468 2.AR Tdead3Trip Dead time after 3-pole tripping
3469 2.AR: Tdead EV. Dead time after evolving fault
3470 2.AR: CB? CLOSE CB ready interrogation before reclosing
3471 2.AR SynRequest Sync. check after 3-pole tripping
For the 3rd cycle:
3472 3.AR: START Start in 3rd cycle generally allowed
3473 3.AR: T-ACTION Action time for the 3rd cycle
3475 3.AR Tdead 1Flt Dead time after 1-phase pickup
3476 3.AR Tdead 2Flt Dead time after 2-phase pickup
3477 3.AR Tdead 3Flt Dead time after 3-phase pickup
3478 3.AR Tdead1Trip Dead time after 1-pole tripping
3479 3.AR Tdead3Trip Dead time after 3-pole tripping
3480 3.AR: Tdead EV. Dead time after evolving fault
3481 3.AR: CB? CLOSE CB ready interrogation before reclosing
3482 3.AR SynRequest Sync. check after 3-pole tripping
For the 4th cycle:
3483 4.AR: START Start in 4th cycle generally allowed
3484 4.AR: T-ACTION Action time for the 4th cycle
3486 4.AR Tdead 1Flt Dead time after 1-phase pickup
3487 4.AR Tdead 2Flt Dead time after 2-phase pickup
3488 4.AR Tdead 3Flt Dead time after 3-phase pickup
3489 4.AR Tdead1Trip Dead time after 1-pole tripping
3490 4.AR Tdead3Trip Dead time after 3-pole tripping
3491 4.AR: Tdead EV. Dead time after evolving fault
3492 4.AR: CB? CLOSE CB ready interrogation before reclosing
3493 4.AR SynRequest Sync. check after 3-pole tripping
5th to 8th Reclose Cycle
If more than four cycles were set during configuration of the functional scope, the dead times preceding the
fifth (5th) through the ninth (9th) reclosing attempts are equal to the open circuit breaker time which
precedes the fourth (4th) reclosing attempt.
Functions
2.13 Automatic reclosure function (optional)
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Notes on the Information List
The most important information about automatic reclosure is briefly explained insofar as it was not mentioned
in the following lists or described in detail in the preceding text.
>BLK 1.AR-cycle
(No. 2742) to
>BLK 4.-n. AR
(No. 2745)
The respective auto-reclose cycle is blocked. If the blocking state already exists when the automatic reclosure
function is initiated, the blocked cycle is not executed and may be skipped (if other cycles are permitted). The
same applies if the automatic reclosure function is started (running), but not internally blocked. If the block
signal of a cycle appears while this cycle is being executed (in progress), the automatic reclosure function is
blocked dynamically; no further automatic reclosures cycles are then executed.
AR 1.CycZoneRel
(No. 2889) to
AR 4.CycZoneRel
(No. 2892)
The automatic reclosure is ready for the respective reclosure cycle. This information indicates which cycle will
be run next. For example, external protection functions can use this information to release accelerated or
overreaching trip stages prior to the corresponding reclose cycle.
AR is blocked
(No. 2783)
The automatic reclosure is blocked (e.g. circuit breaker not ready). This information indicates to the opera-
tional information system that in the event of an upcoming system fault there will be a final trip, i.e. without
reclosure. If the automatic reclosure has been started, this information does not appear.
AR not ready
(No. 2784)
The automatic reclosure is not ready for reclosure at the moment. In addition to the
AR is blocked
mentioned above (No. 2783)there are also obstructions during the course of the auto-reclosure cycles such as
“action time” elapsed or “last reclaim time running”. This information is particularly helpful during testing
because no protection test cycle with reclosure may be initiated during this state.
AR in progress
(No. 2801)
This information appears following the start of the automatic reclosure function, i.e. with the first trip
command that can start the automatic reclosure function. If this reclosure was successful (or any in the case of
multiple cycles), the information is reset with the expiry of the last reclaim time. If no reclosure was successful
or if reclosure was blocked, it ends with the last – the final – trip command.
AR Sync.Request
(No. 2865)
Measuring request to an external synchronism check device. The information appears at the end of a dead
time subsequent to 3-pole tripping if a synchronism request was parameterized for the corresponding cycle.
Reclosure only takes place when the synchronism check device has provided the release signal
>Sync.release
(No. 2731.
>Sync.release
(No. 2731)
Release of reclosure by an external synchronism check device if this was requested by the output information
AR Sync.Request
(No. 2865).
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
3401 AUTO RECLOSE OFF
ON
ON Auto-Reclose function
3402 CB? 1.TRIP YES
NO
NO CB ready interrogation at 1st trip
3403 T-RECLAIM 0.50 .. 300.00 sec 3.00 sec Reclaim time after successful AR
cycle
3403 T-RECLAIM 0.50 .. 300.00 sec; 0 3.00 sec Reclaim time after successful AR
cycle
3404 T-BLOCK MC 0.50 .. 300.00 sec; 0 1.00 sec AR blocking duration after manual
close
2.13.3
Functions
2.13 Automatic reclosure function (optional)
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Addr. Parameter Setting Options Default Setting Comments
3406 EV. FLT. RECOG. with PICKUP
with TRIP
with TRIP Evolving fault recognition
3407 EV. FLT. MODE blocks AR
starts 3p AR
starts 3p AR Evolving fault (during the dead
time)
3408 T-Start MONITOR 0.01 .. 300.00 sec 0.20 sec AR start-signal monitoring time
3409 CB TIME OUT 0.01 .. 300.00 sec 3.00 sec Circuit Breaker (CB) Supervision
Time
3410 T RemoteClose 0.00 .. 300.00 sec; ∞ ∞ sec Send delay for remote close
command
3411A T-DEAD EXT. 0.50 .. 300.00 sec; ∞ ∞ sec Maximum dead time extension
3420 AR w/ DIST. YES
NO
YES AR with distance protection
3421 AR w/ SOTF-O/C YES
NO
YES AR with switch-onto-fault overcur-
rent
3422 AR w/ W/I YES
NO
YES AR with weak infeed tripping
3423 AR w/ EF-O/C YES
NO
YES AR with earth fault overcurrent
prot.
3424 AR w/ DTT YES
NO
YES AR with direct transfer trip
3425 AR w/ BackUpO/C YES
NO
YES AR with back-up overcurrent
3430 AR TRIP 3pole YES
NO
YES 3pole TRIP by AR
3430 AR TRIP 3pole YES
NO
YES 3pole TRIP by AR
3431 DLC or RDT WITHOUT
RDT
DLC
WITHOUT Dead Line Check or Reduced Dead
Time
3433 T-ACTION ADT 0.01 .. 300.00 sec; ∞ 0.20 sec Action time
3434 T-MAX ADT 0.50 .. 3000.00 sec 5.00 sec Maximum dead time
3435 ADT 1p allowed YES
NO
NO 1pole TRIP allowed
3436 ADT CB? CLOSE YES
NO
NO CB ready interrogation before
reclosing
3437 ADT SynRequest YES
NO
NO Request for synchro-check after
3pole AR
3438 T U-stable 0.10 .. 30.00 sec 0.10 sec Supervision time for dead/ live
voltage
3438 T U-stable 0.10 .. 30.00 sec 0.10 sec Supervision time for dead/ live
voltage
3440 U-live> 30 .. 90 V 48 V Voltage threshold for live line or
bus
3440 U-live> 30 .. 90 V 48 V Voltage threshold for live line or
bus
3441 U-dead< 2 .. 70 V 30 V Voltage threshold for dead line or
bus
3441 U-dead< 2 .. 70 V 30 V Voltage threshold for dead line or
bus
Functions
2.13 Automatic reclosure function (optional)
238 SIPROTEC 4, 7SA522, Manual
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Addr. Parameter Setting Options Default Setting Comments
3450 1.AR: START YES
NO
YES Start of AR allowed in this cycle
3451 1.AR: T-ACTION 0.01 .. 300.00 sec; ∞ 0.20 sec Action time
3453 1.AR Tdead 1Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 1phase faults
3454 1.AR Tdead 2Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 2phase faults
3455 1.AR Tdead 3Flt 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3phase faults
3456 1.AR Tdead1Trip 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 1pole trip
3457 1.AR Tdead3Trip 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3pole trip
3458 1.AR: Tdead EV. 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving fault
3459 1.AR: CB? CLOSE YES
NO
NO CB ready interrogation before
reclosing
3460 1.AR SynRequest YES
NO
NO Request for synchro-check after
3pole AR
3461 2.AR: START YES
NO
NO AR start allowed in this cycle
3462 2.AR: T-ACTION 0.01 .. 300.00 sec; ∞ 0.20 sec Action time
3464 2.AR Tdead 1Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 1phase faults
3465 2.AR Tdead 2Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 2phase faults
3466 2.AR Tdead 3Flt 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3phase faults
3467 2.AR Tdead1Trip 0.01 .. 1800.00 sec; ∞ ∞ sec Dead time after 1pole trip
3468 2.AR Tdead3Trip 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3pole trip
3469 2.AR: Tdead EV. 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving fault
3470 2.AR: CB? CLOSE YES
NO
NO CB ready interrogation before
reclosing
3471 2.AR SynRequest YES
NO
NO Request for synchro-check after
3pole AR
3472 3.AR: START YES
NO
NO AR start allowed in this cycle
3473 3.AR: T-ACTION 0.01 .. 300.00 sec; ∞ 0.20 sec Action time
3475 3.AR Tdead 1Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 1phase faults
3476 3.AR Tdead 2Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 2phase faults
3477 3.AR Tdead 3Flt 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3phase faults
3478 3.AR Tdead1Trip 0.01 .. 1800.00 sec; ∞ ∞ sec Dead time after 1pole trip
3479 3.AR Tdead3Trip 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3pole trip
3480 3.AR: Tdead EV. 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving fault
3481 3.AR: CB? CLOSE YES
NO
NO CB ready interrogation before
reclosing
3482 3.AR SynRequest YES
NO
NO Request for synchro-check after
3pole AR
3483 4.AR: START YES
NO
NO AR start allowed in this cycle
3484 4.AR: T-ACTION 0.01 .. 300.00 sec; ∞ 0.20 sec Action time
3486 4.AR Tdead 1Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 1phase faults
3487 4.AR Tdead 2Flt 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 2phase faults
3488 4.AR Tdead 3Flt 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3phase faults
3489 4.AR Tdead1Trip 0.01 .. 1800.00 sec; ∞ ∞ sec Dead time after 1pole trip
3490 4.AR Tdead3Trip 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3pole trip
Functions
2.13 Automatic reclosure function (optional)
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Addr. Parameter Setting Options Default Setting Comments
3491 4.AR: Tdead EV. 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving fault
3492 4.AR: CB? CLOSE YES
NO
NO CB ready interrogation before
reclosing
3493 4.AR SynRequest YES
NO
NO Request for synchro-check after
3pole AR
Information List
No. Information Type of
Informa-
tion
Comments
2701 >AR on SP >AR: Switch on auto-reclose function
2702 >AR off SP >AR: Switch off auto-reclose function
2703 >AR block SP >AR: Block auto-reclose function
2711 >AR Start SP >External start of internal Auto reclose
2712 >Trip L1 AR SP >AR: External trip L1 for AR start
2713 >Trip L2 AR SP >AR: External trip L2 for AR start
2714 >Trip L3 AR SP >AR: External trip L3 for AR start
2715 >Trip 1pole AR SP >AR: External 1pole trip for AR start
2716 >Trip 3pole AR SP >AR: External 3pole trip for AR start
2727 >AR RemoteClose SP >AR: Remote Close signal
2731 >Sync.release SP >AR: Sync. release from ext. sync.-check
2737 >BLOCK 1pole AR SP >AR: Block 1pole AR-cycle
2738 >BLOCK 3pole AR SP >AR: Block 3pole AR-cycle
2739 >BLK 1phase AR SP >AR: Block 1phase-fault AR-cycle
2740 >BLK 2phase AR SP >AR: Block 2phase-fault AR-cycle
2741 >BLK 3phase AR SP >AR: Block 3phase-fault AR-cycle
2742 >BLK 1.AR-cycle SP >AR: Block 1st AR-cycle
2743 >BLK 2.AR-cycle SP >AR: Block 2nd AR-cycle
2744 >BLK 3.AR-cycle SP >AR: Block 3rd AR-cycle
2745 >BLK 4.-n. AR SP >AR: Block 4th and higher AR-cycles
2746 >Trip for AR SP >AR: External Trip for AR start
2747 >Pickup L1 AR SP >AR: External pickup L1 for AR start
2748 >Pickup L2 AR SP >AR: External pickup L2 for AR start
2749 >Pickup L3 AR SP >AR: External pickup L3 for AR start
2750 >Pickup 1ph AR SP >AR: External pickup 1phase for AR start
2751 >Pickup 2ph AR SP >AR: External pickup 2phase for AR start
2752 >Pickup 3ph AR SP >AR: External pickup 3phase for AR start
2781 AR off OUT AR: Auto-reclose is switched off
2782 AR on IntSP AR: Auto-reclose is switched on
2783 AR is blocked OUT AR: Auto-reclose is blocked
2784 AR not ready OUT AR: Auto-reclose is not ready
2787 CB not ready OUT AR: Circuit breaker not ready
2788 AR T-CBreadyExp OUT AR: CB ready monitoring window expired
2796 AR on/off BI IntSP AR: Auto-reclose ON/OFF via BI
2801 AR in progress OUT AR: Auto-reclose in progress
2809 AR T-Start Exp OUT AR: Start-signal monitoring time expired
2.13.4
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2.13 Automatic reclosure function (optional)
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No. Information Type of
Informa-
tion
Comments
2810 AR TdeadMax Exp OUT AR: Maximum dead time expired
2818 AR evolving Flt OUT AR: Evolving fault recognition
2820 AR Program1pole OUT AR is set to operate after 1p trip only
2821 AR Td. evol.Flt OUT AR dead time after evolving fault
2839 AR Tdead 1pTrip OUT AR dead time after 1pole trip running
2840 AR Tdead 3pTrip OUT AR dead time after 3pole trip running
2841 AR Tdead 1pFlt OUT AR dead time after 1phase fault running
2842 AR Tdead 2pFlt OUT AR dead time after 2phase fault running
2843 AR Tdead 3pFlt OUT AR dead time after 3phase fault running
2844 AR 1stCyc. run. OUT AR 1st cycle running
2845 AR 2ndCyc. run. OUT AR 2nd cycle running
2846 AR 3rdCyc. run. OUT AR 3rd cycle running
2847 AR 4thCyc. run. OUT AR 4th or higher cycle running
2848 AR ADT run. OUT AR cycle is running in ADT mode
2851 AR CLOSE Cmd. OUT AR: Close command
2852 AR Close1.Cyc1p OUT AR: Close command after 1pole, 1st cycle
2853 AR Close1.Cyc3p OUT AR: Close command after 3pole, 1st cycle
2854 AR Close 2.Cyc OUT AR: Close command 2nd cycle (and higher)
2857 AR CLOSE RDT TD OUT AR: RDT Close command after TDEADxTRIP
2861 AR T-Recl. run. OUT AR: Reclaim time is running
2862 AR successful OUT AR successful
2864 AR 1p Trip Perm OUT AR: 1pole trip permitted by internal AR
2865 AR Sync.Request OUT AR: Synchro-check request
2871 AR TRIP 3pole OUT AR: TRIP command 3pole
2889 AR 1.CycZoneRel OUT AR 1st cycle zone extension release
2890 AR 2.CycZoneRel OUT AR 2nd cycle zone extension release
2891 AR 3.CycZoneRel OUT AR 3rd cycle zone extension release
2892 AR 4.CycZoneRel OUT AR 4th cycle zone extension release
2893 AR Zone Release OUT AR zone extension (general)
2894 AR Remote Close OUT AR Remote close signal send
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Synchronism and voltage check (optional)
The synchronism and voltage check function ensures, when switching a line onto a busbar, that the stability of
the network is not endangered. The voltage of the feeder to be energized is compared to that of the busbar to
check conformances in terms of magnitude, phase angle and frequency within certain tolerances. Optionally,
deenergization of the feeder can be checked before it is connected to an energized busbar (or vice versa).
The synchronism check can either be conducted only for automatic reclosure, only for manual closure (this
includes also closing via control command) or in both cases. Different close permission (release) criteria can
also be programmed for automatic and manual closure.
Synchro check is also possible without external matching transformers if a power transformer is located
between the measuring points.
Closing is released for synchronous or asynchronous system conditions. In the latter case, the device deter-
mines the time for issuing the close command such that the voltages are identical the instant the breaker
poles make contact.
Functional Description
General
For comparing the two voltages, the synchro check uses the voltages Usy1 and Usy2. If the voltage transformers
for the protection functions (Usy1) are connected to the feeder side, Usy2 has to be connected to a busbar
voltage. If, however, the voltage transformers for the protection functions Usy1 are connected to the busbar
side, the Usy2 has to be connected to a feeder voltage.
Usy2 can be any phase-to-earth or phase-to-phase voltage (see Section 2.1.2.1 Setting Notes margin heading
“Voltage Connection”).
[synchronkontr-einschalten-wlk-310702, 1, en_GB]
Figure 2-123 Synchronism check on closing - example
If a power transformer is located between the feeder voltage transformers and the busbar voltage trans-
formers (Figure 2-124), its vector group can be compensated for by the 7SA522 relay, so that no external
matching transformers are necessary.
2.14
2.14.1
Functions
2.14 Synchronism and voltage check (optional)
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[synchronkontr-trafo-wlk-310702, 1, en_GB]
Figure 2-124 Synchronism check across a transformer - example
The synchronism check function in the 7SA522 usually operates in conjunction with the integrated automatic
reclose, manual close, and the control functions of the relay. It is also possible to employ an external auto-
matic reclosing system. In such a case signal exchange between the devices is accomplished via binary inputs
and outputs (see Figure 2-125).
When closing via the integrated control function, the configured interlocking conditions may have to be veri-
fied before checking the conditions for synchronism. After the synchronism check grants the release, the inter-
locking conditions are not checked a second time.
Furthermore, switching is possible under synchronous or asynchronous system conditions or both.
Synchronous switching means that the closing command is issued as soon as the following critical values lie
within the set tolerances:
•Voltage magnitude difference AR maxVolt.Diff (address 3511) or MC maxVolt.Diff (address
3531)
•Angle difference AR maxAngleDiff (address 3513) or MC maxAngleDiff (Adresse 3533)
•Frequency difference AR maxFreq.Diff (address 3512) or MC maxFreq.Diff (address 3532)
For switching under asynchronous system conditions, the device determines the time for issuing the ON
command from the current angle and frequency difference such that the angle difference of the voltages
(between busbar and feeder) is almost 0° at the instant the poles make contact. For this purpose, the device
requires the parameter (address 239 T-CB close) with the set circuit breaker closing time. Different
frequency limit thresholds apply to switching under synchronous and asynchronous conditions. If closing is
permitted exclusively under synchronous system conditions, the frequency difference limit for this condition
can be set. If closing is permitted under synchronous as well as under asynchronous system conditions, a
frequency difference below 0.01 Hz is treated as a synchronous condition, a higher frequency difference value
can then be set for closing under asynchronous system conditions.
The synchro check function only operates when it is requested to do so. Various possibilities exist for this
purpose:
•Measuring request from the internal automatic reclosure device. If the internal automatic reclosing func-
tion is set accordingly (one or more reclosing attempts set to synchronism check, see also Section
2.13.2 Setting Notes), the measuring request is accomplished internally. The release conditions for auto-
matic reclosing apply (parameter AR...).
•Request to execute a check synchronism measurement from an external automatic reclosure device. The
measuring request must be activated via the binary input
>Sync. Start AR
(No. 2906). The release
conditions for automatic reclosing apply (parameter AR...).
•Measuring request from the manual CLOSE detection. The manual CLOSE detection of the central func-
tion control (Section 2.20.1 Function Control) issues a measuring request provided that this was config-
ured in the power system data 2 (Section 2.1.4.1 Setting Notes, address 1151). This requires that the
device is informed of the manual closing via binary input
>Manual Close
(No. 356). The release condi-
tions for manual closure apply (parameter MC...).
Functions
2.14 Synchronism and voltage check (optional)
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•Request to execute a check synchronism measurement from an external closing command. Binary input
>Sync. Start MC
(No. 2905) fulfills this purpose. Unlike
>Manual Close
(see previous paragraph),
this merely affects the measuring request to the synchronism check function, but not other integrated
manual CLOSE functions such as instantaneous tripping when switching onto a fault (e.g. overreaching
zone for distance protection or accelerated tripping of a time overcurrent stage). The release conditions
for manual closure apply (parameter MC...).
•Measuring request from the integrated control function via control keys or via the serial interface using
DIGSI on a PC or from a control centre. The release conditions for manual closure apply (parameter
MC...).
The synchronism-check function gives permission for passage
Sync. release
(No. 2951) of the closing
command to the required function. Furthermore, a separate closing command is available as output indication
Sync.CloseCmd
(No. 2961).
The check of the release conditions is limited by an adjustable synchronous monitoring time T-SYN. DURA-
TION. The configured conditions must be fulfilled within this time. If they are not, the synchronism will not be
checked. A new synchronism check sequence requires a new request.
The device generates messages if, after a request to check synchronism, the conditions for release are not
fulfilled, i.e. if the absolute voltage difference AR maxVolt.Diff or MC maxVolt.Diff, frequency differ-
ence AR maxFreq.Diff or MC maxFreq.Diff or angle difference AR maxAngleDiff or MC maxAngle-
Diff lie outside the permissible limit values. A precondition for these indications is that voltages within the
operating range of the relay are available. When a closing command originates from the integrated control
function and the conditions for synchronism are not fulfilled, the command is cancelled, i.e. the control func-
tion outputs “CO– ” (refer also to Section 2.22.1 Control Authorization).
Functions
2.14 Synchronism and voltage check (optional)
244 SIPROTEC 4, 7SA522, Manual
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[logik-synchrocheck-seite1, 1, en_GB]
Functions
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[logik-synchrocheck-seite2-280404-st, 1, en_GB]
Figure 2-125 Synchro check logic
Operating modes
The closing check for automatic reclosing is possible in one of the following operating modes:
AR SYNC-CHECK Released at synchronism, that is when the critical
values AR maxVolt.Diff, AR maxFreq.Diff, AR
maxAngleDiff are within the set limits.
AR Usy1<Usy2> Released if measuring point Usy1< is de-energized
and the measuring point Usy2> is energized.
AR Usy1>Usy2< Released if measuring point Usy1> is energized and
the measuring point Usy2< is de-energized.
AR Usy1<Usy2< Released if measuring point Usy1< is de-energized
and the measuring point Usy2< is also de-energized.
AR OVERRIDE Released without any check.
The closing check for manual reclosing is possible in one of the following operating modes:
Functions
2.14 Synchronism and voltage check (optional)
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MC SYNCHR Released at synchronism, that is when the critical
values MC maxVolt.Diff, MC maxFreq.Diff, MC
maxAngleDiff are within the set limits.
MC Usy1< Usy2> Released if measuring point Usy1< is de-energized
and the measuring point Usy2> is energized.
MC Usy1> Usy2< Released if measuring point Usy1> is energized and
the measuring point Usy2< is de-energized.
MC Usy1< Usy2< Released if measuring point Usy1< is de-energized
and the measuring point Usy2< is also de-energized.
MC OVERRIDE Released without any check.
Each of these conditions can be enabled or disabled individually; combinations are also possible, e.g. release if
AR Usy1<Usy2> or AR Usy1>Usy2< are fulfilled). Combination of AR OVERRIDE with other parameters is,
of course, not reasonable (see also Figure 2-125).
The release conditions can be configured individually for automatic reclosing or for manual closing or for
closing via control commands. For example, manual closing and closing via control command can be allowed
in cases of synchronism or dead line, while, before an automatic reclose attempt dead line conditions are only
checked at one line end and after the automatic reclose attempt only synchronism at the other end.
Non-energized switching
To release the closing command to couple a dead overhead line to a live busbar, the following conditions are
checked:
•Is the feeder voltage below the set value Dead Volt. Thr.?
•Is the busbar voltage above the setting value Live Volt. Thr., but below the maximum voltage
Umax?
•Is the frequency within the permitted operating range fN ± 3 Hz?
After successful check the closing command is released.
Corresponding conditions apply when switching a live line onto a dead busbar or a dead line onto a dead
busbar.
Closing under synchronous system conditions
Before releasing a closing command under synchronous conditions, the following conditions are checked:
•Is the busbar voltage above the setting value Live Volt. Thr., but below the maximum voltage
Umax?
•Is the feeder voltage above the setting value Live Volt. Thr. but below the maximum voltage
Umax?
•Is the voltage difference |Usy1 – Usy2| within the permissible tolerance AR maxVolt.Diff or MC
maxVolt.Diff?
•Are the two frequencies fsy1 und fsy2 within the permitted operating range fN ± 3 Hz?
•Does the frequency difference |fsy1 – fsy2| lie within the permissible tolerance AR maxFreq.Diff or MC
maxFreq.Diff?
•Is the angle difference |φsy1 – φsy2| within the permissible tolerance AR maxAngleDiff or MC maxAn-
gleDiff?
To check whether these conditions are fulfilled for a certain minimum time, you can set this minimum time as
T SYNC-STAB Checking the synchronism conditions can also be confined to the a maximum monitoring time
T-SYN. DURATION. This implies that the conditions must be fulfilled within the time T-SYN. DURATION for
the duration of T SYNC-STAB. If this is the case, the closing release is granted.
Functions
2.14 Synchronism and voltage check (optional)
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Closing under asynchronous system conditions
Before releasing a closing command under asynchronous conditions, the following conditions are checked:
•Is the busbar voltage above the setting value Live Volt. Thr., but below the maximum voltage
Umax?
•Is the feeder voltage above the setting value Live Volt. Thr. but below the maximum voltage
Umax?
•Is the voltage difference |Usy1 – Usy2|within the permissible tolerance AR maxVolt.Diff or MC
maxVolt.Diff?
•Are the two frequencies fsy1 und fsy2within the permitted operating range fN ± 3 Hz?
•Is the frequency difference |fsy1 – fsy2| within the permissible tolerance AR maxFreq.Diff or MC
maxFreq.Diff?
When the check has been terminated successfully, the device determines the next synchronizing time from
the angle difference and the frequency difference. The close command is issued at synchronization time
minus the operating time of the circuit breaker.
Setting Notes
Preconditions
When setting the general power system data (Power system data 1, refer to Section 2.1.2.1 Setting Notes) a
number of parameters regarding the measured quantities and the operating mode of the synchronism check
function must be applied.
This concerns the following parameters:
203 Unom PRIMARY primary rated voltage of the voltage transformers of
the protection functions (phase-to-phase) in kV,
measuring point Usy1;
204 Unom SECONDARY secondary rated voltage of the protection functions
(phase-to-phase) in V, measuring point Usy1;
210 U4 transformer voltage measurement input U4 must be set to Usy2
transf.;
212 Usy2 connection voltage connection of measuring point Usy2 (e.g. UL1–
L2),
214 φ Usy2-Usy1 phase displacement between the voltages Usy2 and
Usy1 if a transformer is switched in between;
215 Usy1/Usy2 ratio ratio between the secondary voltage Usy1 and voltage
Usy2 under nominal condition;
230 Rated Frequency the operating range of the synchronism check refers
to the nominal frequency of the power system (fN±3
Hz);
1103 FullScaleVolt. nominal operational voltage of the primary power
system (phase-phase) in kV;
and, if switching under asynchronous system conditions is allowed,
239 T-CB close the closing time of the circuit breaker.
2.14.2
Functions
2.14 Synchronism and voltage check (optional)
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!
WARNING
Switching under Asynchronous System Conditions!
Closing under asynchronous system conditions requires the closing time of the circuit breaker to be
set correctly in the Power System Data 1 (address 239).
²Otherwise, faulty synchronization may occur.
General
The synchronism check can only operate if during the configuration of the device scope (address 135) it has
been set to Enabled and the parameter U4 transformer (address 210) to Usy2 transf..
The measured values of the synchronism check (636
Udiff =
, 637
Usy1=
, 638
Usy2=
, 647
F-diff=
, 649
F-sy1 =
, 646
F-sy2 =
and 648
φdif=
) are only available if the synchronism check is in service.
Different interrogation conditions can be parameterized for automatic reclosure on the one hand and for
manual closure on the other hand. Each closing command is considered a manual reclosure if it was initiated
via the integrated control function or via a serial interface.
The general limit values for synchronism check are set at address 3501 to 3508. Additionally, addresses 3510
to 3519 are relevant for automatic reclosure, addresses 3530 to 3539 are relevant for manual closure. More-
over, address 3509 is relevant for closure via the integrated control function.
At address 3501 FCT Synchronism you switch the entire synchronism check function ON- or OFF. If
switched off, the synchronism check does not verify the synchronization conditions and it finds keine Frei-
gabe. You can also set ON:w/o CloseCmd: The CLOSE command is in this case not included in the common
device alarm
Relay CLOSE
(No 510); but the alarm
Sync.CloseCmd
(No 2961) is issued.
Address 3502 Dead Volt. Thr. indicates the voltage threshold below which the feeder or the busbar can
safely be considered de-energized (for checking a de-energized feeder or busbar). The setting is applied in
Volts secondary. This value can be entered as a primary value when parameterising with a PC and DIGSI.
Depending on the VT connection these are phase-to-earth voltages or phase-to-phase voltages.
Address 3503 Live Volt. Thr. indicates the voltage above which the feeder or busbar is regarded as
being definitely energized (for energized line or busbar check and for the lower limit of synchronism check). It
must be set below the minimum operational undervoltage to be expected. The setting is applied in Volts
secondary. This value can be entered as a primary value when parameterising with a PC and DIGSI. Depending
on the VT connection these are phase-to-earth voltages or phase-to-phase voltages.
The maximum permissible voltage for the operating range of the synchronism check function is set in address
3504 Umax. The setting is applied in Volts secondary. This value can be entered as a primary value when
parameterising with a PC and DIGSI. Depending on the VT connection these are phase-to-earth voltages or
phase-to-phase voltages.
Verification of the release conditions via synchronism check can be limited to a configurable synchronous
monitoring time T-SYN. DURATION (address 3507). The configured conditions must be fulfilled within this
time. If not, closure will not be released. If this time is set to ∞ , the conditions will be checked until they are
fulfilled or the measurement request is cancelled.
For switching under synchronous conditions you can specify a delay time T SYNC-STAB (address 3508).
During this time the voltage criteria must at least be fulfilled before closing is released.
Synchronism conditions for automatic reclosure
Addresses 3510 to 3519 are relevant to the check conditions before automatic reclosure of the circuit breaker.
When setting the parameters for the internal automatic reclosing function (Section 2.13.2 Setting Notes it is
decided with which automatic reclosing cycle synchronism and voltage check should be carried out.
Address 3510 Op.mode with AR determines whether closing under asynchronous system conditions is
allowed for automatic reclosure. Set this parameter to with T-CB close to allow asynchronous closing; the
relay will then consider the circuit breaker closing time before determining the correct instant for the close
command. Remember that closing under asynchronous system conditions is allowed only if the circuit breaker
Functions
2.14 Synchronism and voltage check (optional)
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closing time is set correctly (see above under “Preconditions”)! If you wish to permit automatic reclosure only
under synchronous system conditions, set this address to w/o T-CB close.
The permissible difference between the voltages is set in address 3511 AR maxVolt.Diff. The setting is
applied in Volts secondary. This value can be entered as a primary value when parameterising with a PC and
DIGSI. Depending on the VT connection these are phase-to-earth voltages or phase-to-phase voltages.
The permissible frequency difference between the voltages is set at address 3512 AR maxFreq.Diffthe
permissible phase angle difference at address 3513 AR maxAngleDiff.
The further release conditions for automatic reclosing are set at addresses 3515 to 3519.
The following addresses mean:
3515 AR SYNC-CHECK both measuring points Usy1 and Usy2 must be ener-
gized (Live Volt. Thr., address 3503); the
synchronism conditions are checked, i.e. AR
maxVolt.Diff (address 3511), AR maxFreq.Diff
(address 3512) and AR maxAngleDiff (address
3513). This parameter can only be altered in DIGSI at
Display Additional Settings;
3516 AR Usy1<Usy2> the measuring point Usy1 must be de-energized Dead
Volt. Thr., address 3502), the measuring point
Usy2 must be energized (Live Volt. Thr., address
3503) ;
3517 AR Usy1>Usy2< the measuring point Usy1 must be energized (Live
Volt. Thr., address 3503), the measuring point
Usy2 must be de-energized (Dead Volt. Thr.,
address 3502);
3518 AR Usy1<Usy2< both measuring points Usy1 and Usy2 must be de-ener-
gized ( Dead Volt. Thr., address 3502);
3519 AR OVERRIDE automatic reclosure is released without any check.
The five possible release conditions are independent of one another and can be combined.
Synchronism conditions for manual closure and control command
Addresses 3530 to 3539 are relevant to the check conditions before manual closure and closing via control
command of the circuit breaker. When setting the general protection data (Power System Data 2, Section
2.1.4.1 Setting Notes it was already decided at address 1151 whether synchronism and voltage check should
be carried out before manual closing. With the following setting in address MAN. CLOSE = w/o Sync-
check, no checks are performed before manual closing.
For commands through the integrated control (local, DIGSI, serial interface), address 3509 SyncCB deter-
mines whether synchronism checks will be performed or not. This address also informs the device to which
switching device of the control the synchronizing request refers. You can select from the switching devices
which are available for the integrated control. Choose the circuit breaker to be operated via the synchronism
check. This is usually the circuit breaker which is operated in case of manual closing or automatic reclosure. If
you set SyncCB = none here, a CLOSE command via the integrated control will be carried out without
synchronism check.
Address 3530 Op.mode with MC determines whether closing under asynchronous system conditions is
allowed for manual closing or reclosure via control command. Set this parameter to with T-CB close to
allow asynchronous closing; the relay will then consider the circuit breaker closing time before determining
the correct instant for closing. Remember that closing under asynchronous system conditions is allowed only
if the circuit breaker closing time is set correctly (see above under “Preconditions”)! If you wish to permit
manual closure or closing via control command only under synchronous system conditions, set this address to
w/o T-CB close .
The permissible difference between the voltages is set in address 3531 MC maxVolt.Diff. The setting is
applied in Volts secondary. This value can be entered as a primary value when parameterising with a PC and
DIGSI. Depending on the VT connection these are phase-to-earth voltages or phase-to-phase voltages.
Functions
2.14 Synchronism and voltage check (optional)
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The permissible frequency difference between the voltages is set at address 3532 MC maxFreq.Diffthe
permissible phase angle difference at address 3533 MC maxAngleDiff.
The further release conditions for manual reclosing or reclosure via control command are set under addresses
3535 to 3539.
The following addresses mean:
3535 MC SYNCHR both measuring points Usy1 and Usy2 must be energized (Live Volt.
Thr., address 3503); the synchronism conditions are checked, i.e. MC
maxVolt.Diff (address 3531), MC maxFreq.Diff (address 3532)
and MC maxAngleDiff (address 3533). This parameter can only be
altered in DIGSI at Display Additional Settings;
3536 MC Usy1< Usy2> the measuring point Usy1 must be de-energized Dead Volt. Thr.,
address 3502), the measuring point Usy2 must be energized (Live
Volt. Thr., address 3503) ;
3537 MC Usy1> Usy2< the measuring point Usy1 must be energized (Live Volt. Thr.,
address 3503), the measuring point Usy2 must be de-energized (Dead
Volt. Thr., address 3502);
3538 MC Usy1< Usy2< both measuring points Usy1 and Usy2 must be de-energized ( Dead
Volt. Thr., address 3502);
3539 MC OVERRIDE manual closing or closing via control command is released without any
check.
The five possible release conditions are independent of one another and can be combined.
i
i
NOTE
The closing functions of the device issue individual output indications for the corresponding close
command. Be sure that the output indications are assigned to the correct output relays.
No 2851
AR CLOSE Cmd.
for CLOSE via command of the automatic reclosure,
No 562
Man.Close Cmd
for manual CLOSE via binary input,
No. 2961
Sync.CloseCmd
for CLOSE via synchronism check (not required if synchronism check releases
the other CLOSE commands),
No 7329
CB1-TEST close
for CLOSE by circuit breaker test
additionally CLOSE command via control, e.g.
Brk Close
No 510
Relay CLOSE
general CLOSE command. It comprises all CLOSE commands described above.
Notes on the Information List
The most important information messages of the device are briefly explained below, except those already
detailed in the following lists or in the previous paragraphs.
>Sync. Start MC
(No. 2905)
Binary input which enables direct initiation of the synchronism check with setting parameters for manual
close. This initiation with setting parameters for manual close always has precedence if binary inputs
>Sync.
Start MC
(No 2905) and
>Sync. Start AR
(No 2906, see below), are activated at the same time.
>Sync. Start AR
(No. 2906)
Measuring request from an external automatic reclosure device. The parameters of synchronism check set for
automatic reclosure are valid here.
Sync. req.CNTRL
(No. 2936)
Measurement request of the control function; this request is evaluated on event-triggered basis and only
generated if the control issues a measurement request.
Sync. release
(No. 2951)
Release signal to an external automatic reclosure device.
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Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
3501 FCT Synchronism ON
OFF
ON:w/o CloseCmd
ON Synchronism and Voltage Check
function
3502 Dead Volt. Thr. 1 .. 100 V 5 V Voltage threshold dead line / bus
3503 Live Volt. Thr. 20 .. 125 V 90 V Voltage threshold live line / bus
3504 Umax 20 .. 140 V 110 V Maximum permissible voltage
3507 T-SYN. DURATION 0.01 .. 600.00 sec; ∞ 1.00 sec Maximum duration of
synchronism-check
3508 T SYNC-STAB 0.00 .. 30.00 sec 0.00 sec Synchronous condition stability
timer
3509 SyncCB (Einstellmöglichkeiten
anwendungsabhängig)
none Synchronizable circuit breaker
3510 Op.mode with AR with T-CB close
w/o T-CB close
w/o T-CB close Operating mode with AR
3511 AR maxVolt.Diff 1.0 .. 60.0 V 2.0 V Maximum voltage difference
3512 AR maxFreq.Diff 0.03 .. 2.00 Hz 0.10 Hz Maximum frequency difference
3513 AR maxAngleDiff 2 .. 80 ° 10 ° Maximum angle difference
3515A AR SYNC-CHECK YES
NO
YES AR at Usy2>, Usy1>, and Synchr.
3516 AR Usy1<Usy2> YES
NO
NO AR at Usy1< and Usy2>
3517 AR Usy1>Usy2< YES
NO
NO AR at Usy1> and Usy2<
3518 AR Usy1<Usy2< YES
NO
NO AR at Usy1< and Usy2<
3519 AR OVERRIDE YES
NO
NO Override of any check before AR
3530 Op.mode with MC with T-CB close
w/o T-CB close
w/o T-CB close Operating mode with Man.Cl
3531 MC maxVolt.Diff 1.0 .. 60.0 V 2.0 V Maximum voltage difference
3532 MC maxFreq.Diff 0.03 .. 2.00 Hz 0.10 Hz Maximum frequency difference
3533 MC maxAngleDiff 2 .. 80 ° 10 ° Maximum angle difference
3535A MC SYNCHR YES
NO
YES Manual Close at Usy2>, Usy1>,
and Synchr
3536 MC Usy1< Usy2> YES
NO
NO Manual Close at Usy1< and Usy2>
3537 MC Usy1> Usy2< YES
NO
NO Manual Close at Usy1> and Usy2<
3538 MC Usy1< Usy2< YES
NO
NO Manual Close at Usy1< and Usy2<
3539 MC OVERRIDE YES
NO
NO Override of any check before
Man.Cl
2.14.3
Functions
2.14 Synchronism and voltage check (optional)
252 SIPROTEC 4, 7SA522, Manual
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Addr. Parameter Setting Options Default Setting Comments
3501 FCT Synchronism ON
OFF
ON:w/o CloseCmd
ON Synchronism and Voltage Check
function
3502 Dead Volt. Thr. 1 .. 100 V 5 V Voltage threshold dead line / bus
3503 Live Volt. Thr. 20 .. 125 V 90 V Voltage threshold live line / bus
3504 Umax 20 .. 140 V 110 V Maximum permissible voltage
3507 T-SYN. DURATION 0.01 .. 600.00 sec 1.00 sec Maximum duration of
synchronism-check
3508 T SYNC-STAB 0.00 .. 30.00 sec 0.00 sec Synchronous condition stability
timer
3509 SyncCB (Einstellmöglichkeiten
anwendungsabhängig)
none Synchronizable circuit breaker
3510 Op.mode with AR with T-CB close
w/o T-CB close
w/o T-CB close Operating mode with AR
3511 AR maxVolt.Diff 1.0 .. 60.0 V 2.0 V Maximum voltage difference
3512 AR maxFreq.Diff 0.03 .. 2.00 Hz 0.10 Hz Maximum frequency difference
3513 AR maxAngleDiff 2 .. 80 ° 10 ° Maximum angle difference
3515A AR SYNC-CHECK YES
NO
YES AR at Usy2>, Usy1>, and Synchr.
3516 AR Usy1<Usy2> YES
NO
NO AR at Usy1< and Usy2>
3517 AR Usy1>Usy2< YES
NO
NO AR at Usy1> and Usy2<
3518 AR Usy1<Usy2< YES
NO
NO AR at Usy1< and Usy2<
3519 AR OVERRIDE YES
NO
NO Override of any check before AR
3530 Op.mode with MC with T-CB close
w/o T-CB close
w/o T-CB close Operating mode with Man.Cl
3531 MC maxVolt.Diff 1.0 .. 60.0 V 2.0 V Maximum voltage difference
3532 MC maxFreq.Diff 0.03 .. 2.00 Hz 0.10 Hz Maximum frequency difference
3533 MC maxAngleDiff 2 .. 80 ° 10 ° Maximum angle difference
3535A MC SYNCHR YES
NO
YES Manual Close at Usy2>, Usy1>,
and Synchr
3536 MC Usy1< Usy2> YES
NO
NO Manual Close at Usy1< and Usy2>
3537 MC Usy1> Usy2< YES
NO
NO Manual Close at Usy1> and Usy2<
3538 MC Usy1< Usy2< YES
NO
NO Manual Close at Usy1< and Usy2<
3539 MC OVERRIDE YES
NO
NO Override of any check before
Man.Cl
Functions
2.14 Synchronism and voltage check (optional)
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Information List
No. Information Type of
Informa-
tion
Comments
2901 >Sync. on SP >Switch on synchro-check function
2902 >Sync. off SP >Switch off synchro-check function
2903 >BLOCK Sync. SP >BLOCK synchro-check function
2905 >Sync. Start MC SP >Start synchro-check for Manual Close
2906 >Sync. Start AR SP >Start synchro-check for AR
2907 >Sync. synch SP >Sync-Prog. Live bus / live line / Sync
2908 >Usy1>Usy2< SP >Sync-Prog. Usy1>Usy2<
2909 >Usy1<Usy2> SP >Sync-Prog. Usy1<Usy2>
2910 >Usy1<Usy2< SP >Sync-Prog. Usy1<Usy2<
2911 >Sync. o/ride SP >Sync-Prog. Override ( bypass )
2930 Sync. on/off BI IntSP Synchro-check ON/OFF via BI
2931 Sync. OFF OUT Synchro-check is switched OFF
2932 Sync. BLOCK OUT Synchro-check is BLOCKED
2934 Sync. faulty OUT Synchro-check function faulty
2935 Sync.Tsup.Exp OUT Synchro-check supervision time expired
2936 Sync. req.CNTRL OUT Synchro-check request by control
2941 Sync. running OUT Synchronization is running
2942 Sync.Override OUT Synchro-check override/bypass
2943 Synchronism OUT Synchronism detected
2944 SYNC Usy1>Usy2< OUT SYNC Condition Usy1>Usy2< true
2945 SYNC Usy1<Usy2> OUT SYNC Condition Usy1<Usy2> true
2946 SYNC Usy1<Usy2< OUT SYNC Condition Usy1<Usy2< true
2947 Sync. Udiff> OUT Sync. Voltage diff. greater than limit
2948 Sync. fdiff> OUT Sync. Freq. diff. greater than limit
2949 Sync. φ-diff> OUT Sync. Angle diff. greater than limit
2951 Sync. release OUT Synchronism release (to ext. AR)
2961 Sync.CloseCmd OUT Close command from synchro-check
2970 SYNC fsy2>> OUT SYNC frequency fsy2 > (fn + 3Hz)
2971 SYNC fsy2<< OUT SYNC frequency fsy2 < (fn + 3Hz)
2972 SYNC fsy1>> OUT SYNC frequency fsy1 > (fn + 3Hz)
2973 SYNC fsy1<< OUT SYNC frequency fsy1 < (fn + 3Hz)
2974 SYNC Usy2>> OUT SYNC voltage Usy2 >Umax (P.3504)
2975 SYNC Usy2<< OUT SYNC voltage Usy2 < U> (P.3503)
2976 SYNC Usy1>> OUT SYNC voltage Usy1 >Umax (P.3504)
2977 SYNC Usy1<< OUT SYNC voltage Usy1 < U> (P.3503)
2978 SYNC Usy2>Usy1 OUT SYNC Udiff too large (Usy2>Usy1)
2979 SYNC Usy2<Usy1 OUT SYNC Udiff too large (Usy2<Usy1)
2980 SYNC fsy2>fsy1 OUT SYNC fdiff too large (fsy2>fsy1)
2981 SYNC fsy2<fsy1 OUT SYNC fdiff too large (fsy2<fsy1)
2982 SYNC φsy2>φsy1 OUT SYNC PHIdiff too large (PHIsy2>PHIsy1)
2983 SYNC φsy2<φsy1 OUT SYNC PHIdiff too large (PHIsy2<PHIsy1)
2.14.4
Functions
2.14 Synchronism and voltage check (optional)
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Under and over-voltage protection (optional)
Voltage protection has the function of protecting electrical equipment against undervoltage and overvoltage.
Both operational states are unfavourable as overvoltage may cause, for example, insulation problems or
undervoltage may cause stability problems.
The overvoltage protection in the 7SA522 detects the phase voltages UL1-E, UL2-E and UL3-E, the phase-to-phase
voltages UL1-L2, UL2-L3 and UL3-L1, as well as the displacement voltage 3U0. Instead of the displacement voltage
any other voltage that is connected to the fourth voltage input U4 of the device can be detected. Furthermore,
the device calculates the positive sequence system voltage and the negative sequence system voltage so that
the symmetrical components are also monitored. Here compounding is also possible which calculates the
voltage at the remote line end.
The undervoltage protection can also use the phase voltages UL1-E, UL2-E and UL3-E, the phase-to-phase voltages
UL1-L2, UL2-L3 and UL3-L1, as well as the positive sequence components.
These voltage protection functions can be combined according to the user's requirements. They can be
switched on or off separately, or used for alarm purposes only. In the latter case, the respective trip commands
do not appear. Each voltage protection function is dual-stage, i.e. it is provided with two threshold settings
each with the appropriate times delay.
Abnormally high voltages often occur e.g. in low loaded, long distance transmission lines, in islanded systems
when generator voltage regulation fails, or after full load shutdown of a generator with the generator discon-
nected from the system. Even if compensation reactors are used to avoid line overvoltages by compensation
of the line capacitance and thus reduction of the overvoltage, the overvoltage will endanger the insulation if
the reactors fail (e.g. due to fault clearance). The line must be de-energised within a very short time.
The undervoltage protection can be applied, for example, for disconnection or load shedding tasks in a
system. Furthermore, this protection scheme can detect impending stability problems. With induction
machines undervoltages have an effect on the stability and permissible torque thresholds.
Overvoltage Protection
Phase-to-earth overvoltage
Figure 2-126 depicts the logic diagram of the phase voltage stages. The fundamental component is numeri-
cally filtered from each of the three measuring voltages so that harmonics or transient voltage peaks are
largely eliminated. Two threshold stages Uph-e> (address3702) and Uph-e>> (address 3704) are compared
with the voltages. If a phase voltage exceeds these thresholds, it is indicated in a phase-segregated way. In
addition there is a general pickup indication for each stage
Uph-e> Pickup
and
Uph-e>> Pickup
. The
drop out to pick up ratio can be set (Uph-e>(>) RESET (address3709)).
Every stage starts a time delay which is common to all phases. Expiry of the respective time delay T Uph-e>
(address3703) or T Uph-e>> (address3705) is signaled and normally results in the trip command
Uph-
e>(>) TRIP
.
The phase-to-earth overvoltage protection can be blocked via a binary input
>Uph-e>(>) BLK
.
2.15
2.15.1
Functions
2.15 Under and over-voltage protection (optional)
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[logikdia-ueberspgschutz-phasenspg-wlk-310702, 1, en_GB]
Figure 2-126 Logic diagram of the overvoltage protection for phase voltage
Phase-to-phase overvoltage
The phase-to-phase overvoltage protection operates just like the phase-to-earth protection except that it
detects phase-to-phase voltages. Accordingly, phase-to-phase voltages which have exceeded one of the stage
thresholds Uph-ph> (address 3712) or Uph-ph>> (address3714 are also indicated. Beyond this, applies in
principle. Figure 2-126.
The phase-to-phase overvoltage protection can also be blocked via a binary input
>Uph-ph>(>) BLK
.
Functions
2.15 Under and over-voltage protection (optional)
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Overvoltage positive sequence system U1
The device calculates the positive sequence system according to its defining equation
U1 = 1/3·(UL1 + a·UL2 + a2·UL3)
where a = ej120°.
The resulting positive sequence voltage is fed to the two threshold stages U1> (address 3732) and U1>>
(address 3734) (see Figure 2-127). Combined with the associated time delays T U1> (address 3733) and T
U1>> (address 3735), these stages form a two-stage overvoltage protection based on the positive sequence
system. Here too, the drop-out to pickup ratio can be set.
The overvoltage protection for the positive sequence system can also be blocked via a binary input
>U1>(>)
BLK
.
[logikdia-ueberspgschutz-spgmitsys-wlk-310702, 1, en_GB]
Figure 2-127 Logic diagram of the overvoltage protection for the positive sequence voltage system
Overvoltage protectionU1 with configurable compounding
The overvoltage protection for the positive sequence system may optionally operate with compounding. The
compounding calculates the positive sequence system of the voltage at the remote line end. This option is
thus particularly well suited for detecting a steady-state voltage increase caused by long transmission lines
operating at weak load or no load due to the capacitance per unit length (Ferranti effect). In this case the
overvoltage condition exists at the other line end but it can only be removed by switching off the local line
end.
For calculating the voltage at the opposite line end, the device requires the line data (inductance per unit
length, capacitance per unit length, line angle, line length) which were entered in the Power System Data 2
(Section 2.1.4.1 Setting Notes) during configuration.
Compounding is only available if address 137 is set to Enabl. w. comp.. In this case the calculated voltage
at the other line end is also indicated in the operational measured values.
Functions
2.15 Under and over-voltage protection (optional)
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i
i
NOTE
Compounding is not suited for lines with series capacitors.
The voltage at the remote line end is calculated from the voltage measured at the local line end and the
flowing current by means of a PI equivalent circuit diagram (refer also to Figure 2-128).
[formel-kompoundierung-wlk-210802, 1, en_GB]
with
UEnd the calculated voltage at the remote line end,
UMeas the measured voltage at the local line end,
ΙMeas the measured current at the local line end,
CLthe line capacitance,
RLthe line resistance,
LLthe line inductance.
[ersatzschaltbild-kompoundierung-wlk-210802, 1, en_GB]
Figure 2-128 PI equivalent diagram for compounding
Overvoltage negative sequence system U2
The device calculates the negative sequence system voltages according to its defining equation:
U2 = 1/3·(UL1 + a2·UL2 + a·UL3)
where a = ej120°.
The resulting negative sequence voltage is fed to the two threshold stages U2> (address 3742) and U2>>
(address 3744). Figure 2-129 shows the logic diagram. Combined with the associated time delays T U2>
(address 3743) and T U2>> (address 3745), these stages form a two-stage overvoltage protection for the
negative sequence system. Here too, the drop-out to pickup ratio can be set.
Functions
2.15 Under and over-voltage protection (optional)
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[logikdia-ueberspgschutz-u2-spggegsys-wlk-280802, 1, en_GB]
Figure 2-129 Logic diagram of the overvoltage protection for the negative sequence voltage system U2
The overvoltage protection for the negative sequence system can also be blocked via a binary input
>U2>(>)
BLK
. The stages of the negative sequence voltage protection are automatically blocked as soon as an asym-
metrical voltage failure was detected (“Fuse-Failure-Monitor”, also see Section 2.19.1 Measurement Supervi-
sion, margin heading “Fast Fuse Failure Monitor (Non-symmetrical Voltages)”)“ or when tripping of the MCB
for voltage transformers has been signalled via the binary input
>FAIL:Feeder VT
.
During the single-pole dead time, the stages of the negative-sequence overvoltage protection are automati-
cally blocked since the occurring negative sequence values are only influenced by the asymmetrical power
flow, not by the fault in the system. If the device cooperates with an external automatic reclosure function, or
if a singlepole tripping can be triggered by a different protection system (working in parallel), the overvoltage
protection for the negative sequence system must be blocked via a binary input during single-pole tripping.
Overvoltage zero-sequence system 3U0
Figure 2-130 depicts the logic diagram of the zero-sequence voltage stage. The fundamental component is
numerically filtered from the measuring voltage so that the harmonics or transient voltage peaks remain
largely eliminated.
The triple zero-sequence voltage 3·U0 is fed to the two threshold stages 3U0> (address 3722) and 3U0>>
(address 3724). Combined with the associated time delays T 3U0> (address 3723) and T 3U0>> (address
3725), these stages form a two-stage overvoltage protection for the zero-sequence system. Here too, the
dropout to pickup ratio can be set (3U0>(>) RESET, address 3U0>(>) RESET). Furthermore, a restraint
delay can be configured which is implemented by repeated measuring (approx. 3 periods).
The overvoltage protection for the zero-sequence system can also be blocked via a binary input
>3U0>(>)
BLK
. The stages of the zero-sequence voltage protection are automatically blocked as soon as an asymmetrical
voltage failure was detected (“Fuse-Failure-Monitor”, also see Section 2.19.1 Measurement Supervision,
margin heading “Fuse Failure Monitor (Non-symmetrical Voltages)”) or when the trip of the mcb for voltage
transformers has been signalled via the binary input
>FAIL:Feeder VT
(internal indication “internal
blocking”).
Functions
2.15 Under and over-voltage protection (optional)
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The stages of the zero-sequence voltage protection are automatically blocked during single-pole automatic
reclose dead time to avoid pickup with the asymmetrical power flow arising during this state. If the device
cooperates with an external automatic reclosure function, or if a single-pole tripping can be triggered by a
different protection system (working in parallel), the overvoltage protection for the zero-sequence system
must be blocked via a binary input during single-pole tripping.
According to Figure 2-130 the device calculates the voltage to be monitored:
3·U0 = UL1 + UL2 + UL3.
This applies if no suitable voltage is connected to the fourth measuring input U4.
However, if the displacement voltage Udelta of the voltage transformer set is directly connected to the fourth
measuring input U4 of the device and this information was entered during configuration, the device will auto-
matically use this voltage and calculate the triple zero-sequence voltage.
3·U0 = Uph / Udelta ·U4
Since the voltage transformation ratio of the voltage transformer set is usually
[spguebersetz-spgwdlr-wlk-310702, 1, en_GB]
the factor is set to Uph / Udelta = 3/√3 = √3 = 1.73. For more details, refer to Power System Data 1 in
Section 2.1.4.1 Setting Notes at margin heading “Voltage Connections” via address 211.
Functions
2.15 Under and over-voltage protection (optional)
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[logikdia-ueberspgschutz-nullspg-wlk-310702, 1, en_GB]
Figure 2-130 Logic diagram of the overvoltage protection for zero sequence voltage
Freely selectable single-phase voltage
As the zero-sequence voltage stages operate separately and independently of the other protection overvoltage
functions, they can be used for any other single-phase voltage. Therefore the fourth voltage input U4 of the
device must be assigned accordingly (also see Section 2.1.2 Power System Data 1 “Voltage Connection”).
The stages can be blocked via a binary input
>3U0>(>) BLK
. Internal blocking is not accomplished in this
application case.
Undervoltage Protection
Undervoltage Phase-to-earth
Figure 2-131 depicts the logic diagram of the phase voltage stages. The fundamental component is numeri-
cally filtered from each of the three measuring voltages so that harmonics or transient voltage peaks are
largely eliminated. Two threshold stages Uph-e< (address 3752) and Uph-e<< (address 3754) are compared
with the voltages. If the phase voltage falls below a threshold it is indicated in a phase-segregated way.
2.15.2
Functions
2.15 Under and over-voltage protection (optional)
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Furthermore, a general pickup indication
Uph-e< Pickup
and
Uph-e<< Pickup
is given. The drop-out to
pickup ratio can be set (Uph-e<(<) RESET, address 3759).
Every stage starts a time delay which is common to all phases. The expiry of the respective time delay T Uph-
e< (address 3753) or T Uph-e<< (address 3755) is signalled and usually results in the trip command
Uph-
e<(<) TRIP
.
Depending on the configuration of the substations, the voltage transformers are located on the busbar side or
on the outgoing feeder side. This results in a different behaviour of the undervoltage protection when the line
is de-energised. While the voltage usually remains present or reappears on the busbar side after a trip
command and opening of the circuit breaker, it becomes zero on the outgoing side. For the undervoltage
protection, this results in a pickup state being present if the voltage transformers are on the outgoing side. If
this pickup must be reset, the current can be used as an additional criterion (current supervision CURR.SUP.
Uphe<, address 3758) to achieve this result. Undervoltage will then only be detected if, together with the
undervoltage condition, the minimum current PoleOpenCurrent of the corresponding phase is also
exceeded. This condition is communicated by the central function control of the device.
The undervoltage protection phase-to-earth can be blocked via a binary input
Uph-e<(<) BLK
. The stages of
the undervoltage protection are then automatically blocked if a voltage failure is detected (“Fuse-Failure-
Monitor”, also see Section 2.19.1 Measurement Supervision) or if the trip of the mcb of the voltage trans-
formers is indicated (internal blocking) via the binary input
>FAIL:Feeder VT
.
Also during a single-pole automatic reclose dead time the stages of the undervoltage protection are automati-
cally blocked in the pole open state. If necessary, the current criterion will be considered, so that the stages do
not respond to the undervoltage of the disconnected phase when voltage transformers are located on the
outgoing side. Only such stages are blocked during the single-pole dead time that can actually generate a trip
command according to their setting.
Functions
2.15 Under and over-voltage protection (optional)
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[logikdia-unterspgschutz-phasenspg-wlk-310702, 1, en_GB]
Figure 2-131 Logic diagram of the undervoltage protection for phase voltages
Phase-to-phase undervoltage
Basically, the phase-to-phase undervoltage protection operates like the phase-to-earth protection except that
it detects phase-to-phase voltages. Accordingly, both phases are indicated during pickup of an undervoltage
stage the value fell below one of the stage thresholds Uph-ph< (address 3762) or Uph-ph<< (address 3764).
Beyond this, Figure 2-131 applies in principle.
It is sufficient for the current criterion that current flow is detected in one of the involved phases.
Functions
2.15 Under and over-voltage protection (optional)
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The phase-to-phase undervoltage protection can also be blocked via a binary input
>Uphph<(<) BLK
. There
is an automatic blocking if the measuring voltage failure was detected or voltage mcb tripping was indicated
(internal blocking of the phases affected by the voltage failure).
During single-pole dead time for automatic reclosure the stages of the undervoltage protection are automati-
cally blocked in the disconnected phase so that they do not respond to the undervoltage of the disconnected
phase provided that the voltage transformers are located on the outgoing side. Only such stages are blocked
during the single-pole dead time that can actually initiate tripping according to their setting.
Undervoltage positive sequence system U1
The device calculates the positive sequence system according to its defining equation
U1 = 1/3·(UL1 + a·UL2 + a2·UL3)
where a = ej120°.
The resulting positive sequence voltage is fed to the two threshold stages U1< (address 3772) and U1<<
(address 3774 (see Figure 2-132). Combined with the associated time delays T U1< (address 3773) and T
U1<< (address 3775). these stages form a two-stage undervoltage protection for the positive sequence
system.
The current can be used as an additional criterion for the undervoltage protection of the positive sequence
system (current supervision CURR.SUP.U1<, address 3778). An undervoltage is only detected if the current
flow is detected in at least one phase together with the undervoltage criterion.
The undervoltage protection for the positive sequence system can be blocked via the binary input
>U1<(<)
BLK
. The stages of the undervoltage protection are automatically blocked if voltage failure is detected (“Fuse-
Failure-Monitor”, also see Section 2.19.1 Measurement Supervision) or, if the trip of the mcb for the voltage
transformer is indicated via the binary input
>FAIL:Feeder VT
.
Functions
2.15 Under and over-voltage protection (optional)
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[logikdia-unterspgschutz-spgmitsys-wlk-310702, 1, en_GB]
Figure 2-132 Logic diagram of the undervoltage protection for positive sequence voltage system
During single-pole dead time for automatic reclosure, the stages of positive sequence undervoltage protection
are automatically blocked. In this way, the stages do not respond to the reduced positive sequence voltage
caused by the disconnected phase in case the voltage transformers are located on the outgoing side.
Setting Notes
General
The voltage protection can only operate if, when configuring the device scope (address 137), it has been set
to Enabled. Compounding is only available if (address 137) is set to Enabl. w. comp..
The overvoltage and undervoltage stages can detect phase-to-earth voltages, phase-to-phase voltages or the
positive sequence voltages; for overvoltage also the negative sequence voltage, zero-sequence voltage or a
different single-phase voltage can be used. Any combination is possible. Stages that are not required are
switched OFF.
2.15.3
Functions
2.15 Under and over-voltage protection (optional)
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i
i
NOTE
For overvoltage protection it is particularly important to observe the setting notes: NEVER set an over-
voltage stage (UL-E, UL-L, U1)lower than an undervoltage stage. This would put the device immediately into a
state of permanent pickup which cannot be reset by any measured value operation. As a result, operation
of the device would be impossible!
Phase-to-earth overvoltage
The phase voltage stages can be switched ON or OFF in address 3701 Uph-e>(>). In addition to this, you can
set Alarm Only, i.e. these stages operate and send alarms but do not generate any trip command. The
setting U>Alarm U>>Trip creates in addition also a trip command only for the U>> stage.
The settings of the voltage threshold and the timer values depend on the type of application. To detect steady-
state overvoltages on long lines carrying no load, set the Uph-e> stage (address 3702) to at least 5 % above
the maximum stationary phase-to-earth voltage expected during operation. Additionally, a high dropout to
pickup ratio is required (address 3709 Uph-e>(>) RESET = 0.98 presetting). This parameter can only be
changed in DIGSI at Display Additional Settings. The delay time T Uph-e> (address 3703) should be a few
seconds so that overvoltages with short duration do not cause tripping.
The Uph>> stage (address 3704) is provided for high overvoltages with short duration. Here an adequately
high pickup value is set, e.g. the 11/2-fold of the nominal phase-to-earth voltage. 0.1 s to 0.2 s are sufficient
for the delay time T Uph-e>> (address 3705).
Phase-to-phase overvoltage
Basically, the same considerations apply as for the phase voltage stages. These stages can be used instead of
the phase voltage stages or additionally. Depending on your choice, set address 3711 Uph-ph>(>) to ON,
OFF, Alarm Only or U>Alarm U>>Trip.
As phase-to-phase voltages are monitored, the phase-to-phase values are used for the settings Uph-ph>
(address 3712) and Uph-ph>> (address 3714).
For the delay times T Uph-ph> (address 3713) and T Uph-ph>> (address 3715) the same considerations
apply as above. The same is true for the pickup ratios (address 3719 Uphph>(>) RESET). The latter setting
can only be altered in DIGSI at Display Additional Settings.
Overvoltage positive sequence system U1
You can use the positive sequence voltage stages instead of or in addition to previously mentioned over-
voltage stages. Depending on your choice, set address 3731 U1>(>) to ON, OFF, Alarm Only or U>Alarm
U>>Trip.
For symmetrical voltages an increase of the positive sequence system corresponds to an AND gate of the
voltages. These stages are particularly suited to the detection of steady-state overvoltages on long, weak-
loaded transmission lines (Ferranti effect). Here too, the U1> stage (address 3732) with a longer delay time T
U1> (address 3733) is used for the detection of steady-state overvoltages (some seconds), the U1>> stage
(address 3734) with the short delay time T U1>> (address 3735) is used for the detection of high overvol-
tages that may jeopardise insulation.
Note that the positive sequence system is established according to its defining equation
U1 = 1/3·|UL1 + a·UL2 + a2·UL3|. For symmetrical voltages this is equivalent to a phase-to-earth voltage.
If the voltage at the remote line end is to be decisive for overvoltage detection, you can use the compounding
feature. This requires that address 137 U/O VOLTAGE is already set to Enabl. w. comp. (enabled with
compounding) when configuring the protection functions (Section 2.1.1.2 Setting Notes).
In addition, the compounding feature needs the line data which have been set in the Power System Data 2
(Section 2.1.4.1 Setting Notes): at address 1110 or 1112 x', address 1114 or 1115 c' and address 1111 or
1113 Line Length and address 1105 Line Angle. These data are vital for a correct compounding calcula-
tion. If the values provided here do not correspond to real conditions, the compounding may calculate a too
high voltage at the remote end causing the protection to pick up immediately as soon as the measured values
are applied. In this case, the pickup state can only be reset by switching off the measuring voltage.
Functions
2.15 Under and over-voltage protection (optional)
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Compounding can be switched ON or OFF separately for each of the U1 stages: for the U1> stage at address
3736 U1> Compound and for the U1>> stage at address 3737 U1>> Compound.
The dropout to pickup ratio (address 3739 U1>(>) RESET) is set as high as possible with regard to the detec-
tion of even small steady-state overvoltages. This parameter can only be altered in DIGSI at Display Additional
Settings.
Overvoltage negative sequence system U2
The negative sequence voltage stages detect asymmetrical voltages. If such voltages should cause tripping,
set address 3741 U2>(>) to ON. If such conditions will only be reported, set address 3741 U2>(>) to Alarm
Only. If only one stage is desired to generate a trip command, choose the setting U>Alarm U>>Trip. With
this setting a trip command is output by the 2nd stage only. If negative sequence voltage protection is not
required, set OFF.
This protection function also has two stages, one being U2> stage (address 3742) with a longer time delay T
U2> (address 3743) for steady-state asymmetrical voltages and the other being U2>> stage (address 3744)
with a short delay time T U2>> (address 3745) for high asymmetrical voltages.
Note that the negative sequence system is calculated according to its defining equation U2 = 1/3·|
UL1 + a2·UL2 + a·UL3|. For symmetrical voltages and two swapped phases this is equivalent to the phase-to-
earth voltage value.
The resetting ratio can be changed U2>(>) RESET using the address 3749. This parameter can only be
altered in DIGSI at Display Additional Settings.
Overvoltage zero-sequence system
The zero-sequence voltage stages can be switched in address 3721 3U0>(>) (or Ux) ON or OFF. In addi-
tion to this, you can set Alarm Only, i.e. these stages operate and also send alarms but do not generate any
trip command. If a trip command of the 2nd stage is still desired, the setting must be U>Alarm U>>Trip.
This protection function can be used for any other single-phase voltage which is connected to the fourth
voltage measurement input U4. Also see section 2.1.2.1 Setting Notes at margin heading “Voltage Connec-
tion”.
This protection function also has two stages. The settings of the voltage threshold and the timer values
depend on the type of application. Therefore, no general guidelines can be established. The stage 3U0>
(address 3722) is usually set with a high sensitivity and a longer delay time T 3U0> (address 3723). The
3U0>> stage (address 3724) and its delay time T 3U0>> (address 3725) enables a second stage to be imple-
mented with less sensitivity and a shorter delay time.
Similar considerations apply if this voltage stage is used for a different voltage at the measuring input U4.
The zero-voltage stages feature a special time stabilization due to repeated measurements allowing them to
be set rather sensitive. This stabilization can be disabled in address 3728 3U0>(>) Stabil. if a shorter
pickup time is required. This parameter can only be altered in DIGSI at Display Additional Settings. Please
consider that sensitive settings combined with short pickup times are not recommended.
The drop out to pick up ratio can be changed 3U0>(>) RESET using the address 3729. This parameter can
only be altered in DIGSI at Display Additional Settings.
When setting the voltage values please observe the following:
Functions
2.15 Under and over-voltage protection (optional)
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•If U4 is connected with Uen voltage of the set of voltage transformers and this is set as with the Power
System Data 1 (see Section 2.1.2.1 Setting Notes at margin heading “Voltage Connection”, address 210
U4 transformer = Udelta transf.), the device multiplies this voltage by the matching ratio Uph /
Udelta (address 211), usually with 1.73. Therefore the voltage measured is √3·Uen = 3·U0. When the
voltage triangle is fully displaced, the voltage will be √3 times the phase-to-phase voltage.
•If any other voltage is connected to U4 which is not used for voltage protection, and if this was already
set in the Power System Data 1 (refer also to Section 2.1.2.1 Setting Notes at margin heading “Voltage
Connection”, e.g. U4 transformer = Usy2 transf. or U4 transformer = Not connected), the
device calculates the zero-sequence voltage from the phase voltages according to its definition 3·U0 = |
UL1 + UL2 + UL3|. When the voltage triangle is fully displaced, the voltage will thus be √3 times the phase-
to-phase voltage.
•If any other AC voltage is connected to U4 which is used for voltage protection, and if this was already set
in the Power System Data 1 (Section 2.1.2.1 Setting Notes at margin heading “Voltage Connection”, U4
transformer = Ux transformer), this voltage will be used for the voltage stages without any further
factors. This “zero-sequence voltage protection” is then, in reality, a single-phase voltage protection for
any kind of voltage at U4. Note that with a sensitive setting, i.e. close to operational values that are to be
expected, not only the time delay T 3U0> (address 3723) must be set high, but also the reset ratio
3U0>(>) RESET(address 3729) must be set as high as possible.
Phase-to-earth undervoltage
The phase voltage stages can be switched ON or OFF in address 3751 Uph-e<(<). In addition to this, you can
set Alarm Only, i.e. these stages operate and send alarms but do not generate any trip command. You can
generate a trip command for the 2nd stage only in addition to the alarm by setting U<Alarm U<<Trip.
This undervoltage protection function has two stages. The Uph-e< stage (address 3752) with a longer setting
of the time T Uph-e< (address 3753) operates in the case of minor undervoltages. However, the value set
here must not be higher than the undervoltage permissible in operation. In the presence of higher voltage
dips, the Uph-e<< stage (address 3754) with the delay T Uph-e<< (address 3755) becomes active.
The dropout to pickup ratio Uph-e<(<) RESET can be set in address 3759. This parameter can only be
altered in DIGSI at Display Additional Settings.
The settings of the voltages and times depend on the intended use; therefore no general recommendations
for the settings can be given. For load shedding, for example, the values are often determined by a priority
grading coordination chart. In case of stability problems, the permissible levels and durations of overvoltages
must be observed. With induction machines undervoltages have an effect on the permissible torque thresh-
olds.
If the voltage transformers are located on the line side, the measuring voltages will be missing when the line is
disconnected. To avoid that the undervoltage levels in these cases are or remain picked up, the current crite-
rion CURR.SUP. Uphe< (address 3758) is switched ON. With busbar side voltage transformers it can be
switched OFF. However, if the busbar is dead, the undervoltage protection will pick up and expire and then
remain in a picked-up state. It must therefore be ensured in such cases that the protection is blocked by a
binary input.
Phase-to-phase undervoltage
Basically, the same considerations apply as for the phase voltage stages. These stages may replace the phase
voltage stages or be used additionally. Depending on your choice, set address 3761 Uph-ph<(<)to ON, OFF,
Alarm Only or U<Alarm U<<Trip.
As phase-to-phase voltages are monitored, the phase-to-phase values are used for the settings Uph-ph<
(address 3762) and Uph-ph<< (address 3764).
The corresponding time delays are T Uph-ph< (address 3763) and T Uphph<< (address 3765).
The dropout to pickup ratio Uphph<(<) RESET can be set in address 3769. This parameter can only be
altered in DIGSI at Display Additional Settings.
If the voltage transformers are located on the line side, the measuring voltages will be missing when the line is
disconnected. To avoid that the undervoltage levels in these cases are or remain picked up, the current crite-
rion CURR.SUP.Uphph< (address 3768) is switched ON. With busbar side voltage transformers it can be
Functions
2.15 Under and over-voltage protection (optional)
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switched OFF. However, if the busbar is dead, the undervoltage protection will pick up and expire and then
remain in a picked-up state. It must therefore be ensured in such cases that the protection is blocked by a
binary input.
Undervoltage positive sequence systemU1
The positive sequence undervoltage stages can be used instead of or in addition to previously mentioned
undervoltage stages. Depending on your choice, set address 3771 U1<(<) to ON, OFF, Alarm Only or
U<Alarm U<<Trip.
Basically, the same considerations apply as for the other undervoltage stages. Especially in case of stability
problems, the positive sequence system is advantageous, since the positive sequence system is relevant for
the limit of the stable energy transmission.
To achieve the two-stage condition, the U1< stage (address 3772) is combined with a greater time delay T
U1< (address 3773), and the U1<< stage (address U1<<) with a shorter time delay TT U1<< (address 3775).
Note that the positive sequence system is calculated according to its defining equation
U1 = 1/3·|UL1 + a·UL2 + a2·UL3|. For symmetrical voltages this is equivalent to a phase-to-earth voltage.
The dropout to pickup ratio U1<(<) RESET can be set in address 3779. This parameter can only be altered in
DIGSI at Display Additional Settings.
If the voltage transformers are located on the line side, the measuring voltages will be missing when the line is
disconnected. To avoid that the undervoltage levels in these cases are or remain picked up, the current crite-
rion CURR.SUP.U1< (address 3778) is switched ON. With busbar side voltage transformers it can be switched
OFF. However, if the busbar is dead, the undervoltage protection will pick up and expire and then remain in a
pickedup state. It must therefore be ensured in such cases that the protection is blocked by a binary input.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
3701 Uph-e>(>) OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode Uph-e over-
voltage prot.
3702 Uph-e> 1.0 .. 170.0 V; ∞ 85.0 V Uph-e> Pickup
3703 T Uph-e> 0.00 .. 100.00 sec; ∞ 2.00 sec T Uph-e> Time Delay
3704 Uph-e>> 1.0 .. 170.0 V; ∞ 100.0 V Uph-e>> Pickup
3705 T Uph-e>> 0.00 .. 100.00 sec; ∞ 1.00 sec T Uph-e>> Time Delay
3709A Uph-e>(>) RESET 0.30 .. 0.99 0.98 Uph-e>(>) Reset ratio
3711 Uph-ph>(>) OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode Uph-ph over-
voltage prot.
3712 Uph-ph> 2.0 .. 220.0 V; ∞ 150.0 V Uph-ph> Pickup
3713 T Uph-ph> 0.00 .. 100.00 sec; ∞ 2.00 sec T Uph-ph> Time Delay
3714 Uph-ph>> 2.0 .. 220.0 V; ∞ 175.0 V Uph-ph>> Pickup
3715 T Uph-ph>> 0.00 .. 100.00 sec; ∞ 1.00 sec T Uph-ph>> Time Delay
3719A Uphph>(>) RESET 0.30 .. 0.99 0.98 Uph-ph>(>) Reset ratio
3721 3U0>(>) (or Ux) OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode 3U0 (or Ux) over-
voltage
3722 3U0> 1.0 .. 220.0 V; ∞ 30.0 V 3U0> Pickup (or Ux>)
2.15.4
Functions
2.15 Under and over-voltage protection (optional)
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Addr. Parameter Setting Options Default Setting Comments
3723 T 3U0> 0.00 .. 100.00 sec; ∞ 2.00 sec T 3U0> Time Delay (or T Ux>)
3724 3U0>> 1.0 .. 220.0 V; ∞ 50.0 V 3U0>> Pickup (or Ux>>)
3725 T 3U0>> 0.00 .. 100.00 sec; ∞ 1.00 sec T 3U0>> Time Delay (or T Ux>>)
3728A 3U0>(>) Stabil. ON
OFF
ON 3U0>(>): Stabilization 3U0-Meas-
urement
3729A 3U0>(>) RESET 0.30 .. 0.99 0.95 3U0>(>) Reset ratio (or Ux)
3731 U1>(>) OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode U1 overvoltage
prot.
3732 U1> 2.0 .. 220.0 V; ∞ 150.0 V U1> Pickup
3733 T U1> 0.00 .. 100.00 sec; ∞ 2.00 sec T U1> Time Delay
3734 U1>> 2.0 .. 220.0 V; ∞ 175.0 V U1>> Pickup
3735 T U1>> 0.00 .. 100.00 sec; ∞ 1.00 sec T U1>> Time Delay
3736 U1> Compound OFF
ON
OFF U1> with Compounding
3737 U1>> Compound OFF
ON
OFF U1>> with Compounding
3739A U1>(>) RESET 0.30 .. 0.99 0.98 U1>(>) Reset ratio
3741 U2>(>) OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode U2 overvoltage
prot.
3742 U2> 2.0 .. 220.0 V; ∞ 30.0 V U2> Pickup
3743 T U2> 0.00 .. 100.00 sec; ∞ 2.00 sec T U2> Time Delay
3744 U2>> 2.0 .. 220.0 V; ∞ 50.0 V U2>> Pickup
3745 T U2>> 0.00 .. 100.00 sec; ∞ 1.00 sec T U2>> Time Delay
3749A U2>(>) RESET 0.30 .. 0.99 0.98 U2>(>) Reset ratio
3751 Uph-e<(<) OFF
Alarm Only
ON
U<Alarm U<<Trip
OFF Operating mode Uph-e under-
voltage prot.
3752 Uph-e< 1.0 .. 100.0 V; 0 30.0 V Uph-e< Pickup
3753 T Uph-e< 0.00 .. 100.00 sec; ∞ 2.00 sec T Uph-e< Time Delay
3754 Uph-e<< 1.0 .. 100.0 V; 0 10.0 V Uph-e<< Pickup
3755 T Uph-e<< 0.00 .. 100.00 sec; ∞ 1.00 sec T Uph-e<< Time Delay
3758 CURR.SUP. Uphe< ON
OFF
ON Current supervision (Uph-e)
3759A Uph-e<(<) RESET 1.01 .. 1.20 1.05 Uph-e<(<) Reset ratio
3761 Uph-ph<(<) OFF
Alarm Only
ON
U<Alarm U<<Trip
OFF Operating mode Uph-ph under-
voltage prot.
3762 Uph-ph< 1.0 .. 175.0 V; 0 50.0 V Uph-ph< Pickup
3763 T Uph-ph< 0.00 .. 100.00 sec; ∞ 2.00 sec T Uph-ph< Time Delay
3764 Uph-ph<< 1.0 .. 175.0 V; 0 17.0 V Uph-ph<< Pickup
3765 T Uphph<< 0.00 .. 100.00 sec; ∞ 1.00 sec T Uph-ph<< Time Delay
Functions
2.15 Under and over-voltage protection (optional)
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Addr. Parameter Setting Options Default Setting Comments
3768 CURR.SUP.Uphph< ON
OFF
ON Current supervision (Uph-ph)
3769A Uphph<(<) RESET 1.01 .. 1.20 1.05 Uph-ph<(<) Reset ratio
3771 U1<(<) OFF
Alarm Only
ON
U<Alarm U<<Trip
OFF Operating mode U1 undervoltage
prot.
3772 U1< 1.0 .. 100.0 V; 0 30.0 V U1< Pickup
3773 T U1< 0.00 .. 100.00 sec; ∞ 2.00 sec T U1< Time Delay
3774 U1<< 1.0 .. 100.0 V; 0 10.0 V U1<< Pickup
3775 T U1<< 0.00 .. 100.00 sec; ∞ 1.00 sec T U1<< Time Delay
3778 CURR.SUP.U1< ON
OFF
ON Current supervision (U1)
3779A U1<(<) RESET 1.01 .. 1.20 1.05 U1<(<) Reset ratio
Information List
No. Information Type of
Informa-
tion
Comments
234.2100 U<, U> blk IntSP U<, U> blocked via operation
10201 >Uph-e>(>) BLK SP >BLOCK Uph-e>(>) Overvolt. (phase-earth)
10202 >Uph-ph>(>) BLK SP >BLOCK Uph-ph>(>) Overvolt (phase-phase)
10203 >3U0>(>) BLK SP >BLOCK 3U0>(>) Overvolt. (zero sequence)
10204 >U1>(>) BLK SP >BLOCK U1>(>) Overvolt. (positive seq.)
10205 >U2>(>) BLK SP >BLOCK U2>(>) Overvolt. (negative seq.)
10206 >Uph-e<(<) BLK SP >BLOCK Uph-e<(<) Undervolt (phase-earth)
10207 >Uphph<(<) BLK SP >BLOCK Uphph<(<) Undervolt (phase-phase)
10208 >U1<(<) BLK SP >BLOCK U1<(<) Undervolt (positive seq.)
10215 Uph-e>(>) OFF OUT Uph-e>(>) Overvolt. is switched OFF
10216 Uph-e>(>) BLK OUT Uph-e>(>) Overvolt. is BLOCKED
10217 Uph-ph>(>) OFF OUT Uph-ph>(>) Overvolt. is switched OFF
10218 Uph-ph>(>) BLK OUT Uph-ph>(>) Overvolt. is BLOCKED
10219 3U0>(>) OFF OUT 3U0>(>) Overvolt. is switched OFF
10220 3U0>(>) BLK OUT 3U0>(>) Overvolt. is BLOCKED
10221 U1>(>) OFF OUT U1>(>) Overvolt. is switched OFF
10222 U1>(>) BLK OUT U1>(>) Overvolt. is BLOCKED
10223 U2>(>) OFF OUT U2>(>) Overvolt. is switched OFF
10224 U2>(>) BLK OUT U2>(>) Overvolt. is BLOCKED
10225 Uph-e<(<) OFF OUT Uph-e<(<) Undervolt. is switched OFF
10226 Uph-e<(<) BLK OUT Uph-e<(<) Undervolt. is BLOCKED
10227 Uph-ph<(<) OFF OUT Uph-ph<(<) Undervolt. is switched OFF
10228 Uph-ph<(<) BLK OUT Uphph<(<) Undervolt. is BLOCKED
10229 U1<(<) OFF OUT U1<(<) Undervolt. is switched OFF
10230 U1<(<) BLK OUT U1<(<) Undervolt. is BLOCKED
10231 U</> ACTIVE OUT Over-/Under-Voltage protection is ACTIVE
10240 Uph-e> Pickup OUT Uph-e> Pickup
2.15.5
Functions
2.15 Under and over-voltage protection (optional)
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No. Information Type of
Informa-
tion
Comments
10241 Uph-e>> Pickup OUT Uph-e>> Pickup
10242 Uph-e>(>) PU L1 OUT Uph-e>(>) Pickup L1
10243 Uph-e>(>) PU L2 OUT Uph-e>(>) Pickup L2
10244 Uph-e>(>) PU L3 OUT Uph-e>(>) Pickup L3
10245 Uph-e> TimeOut OUT Uph-e> TimeOut
10246 Uph-e>> TimeOut OUT Uph-e>> TimeOut
10247 Uph-e>(>) TRIP OUT Uph-e>(>) TRIP command
10248 Uph-e> PU L1 OUT Uph-e> Pickup L1
10249 Uph-e> PU L2 OUT Uph-e> Pickup L2
10250 Uph-e> PU L3 OUT Uph-e> Pickup L3
10251 Uph-e>> PU L1 OUT Uph-e>> Pickup L1
10252 Uph-e>> PU L2 OUT Uph-e>> Pickup L2
10253 Uph-e>> PU L3 OUT Uph-e>> Pickup L3
10255 Uphph> Pickup OUT Uph-ph> Pickup
10256 Uphph>> Pickup OUT Uph-ph>> Pickup
10257 Uphph>(>)PU L12 OUT Uph-ph>(>) Pickup L1-L2
10258 Uphph>(>)PU L23 OUT Uph-ph>(>) Pickup L2-L3
10259 Uphph>(>)PU L31 OUT Uph-ph>(>) Pickup L3-L1
10260 Uphph> TimeOut OUT Uph-ph> TimeOut
10261 Uphph>> TimeOut OUT Uph-ph>> TimeOut
10262 Uphph>(>) TRIP OUT Uph-ph>(>) TRIP command
10263 Uphph> PU L12 OUT Uph-ph> Pickup L1-L2
10264 Uphph> PU L23 OUT Uph-ph> Pickup L2-L3
10265 Uphph> PU L31 OUT Uph-ph> Pickup L3-L1
10266 Uphph>> PU L12 OUT Uph-ph>> Pickup L1-L2
10267 Uphph>> PU L23 OUT Uph-ph>> Pickup L2-L3
10268 Uphph>> PU L31 OUT Uph-ph>> Pickup L3-L1
10270 3U0> Pickup OUT 3U0> Pickup
10271 3U0>> Pickup OUT 3U0>> Pickup
10272 3U0> TimeOut OUT 3U0> TimeOut
10273 3U0>> TimeOut OUT 3U0>> TimeOut
10274 3U0>(>) TRIP OUT 3U0>(>) TRIP command
10280 U1> Pickup OUT U1> Pickup
10281 U1>> Pickup OUT U1>> Pickup
10282 U1> TimeOut OUT U1> TimeOut
10283 U1>> TimeOut OUT U1>> TimeOut
10284 U1>(>) TRIP OUT U1>(>) TRIP command
10290 U2> Pickup OUT U2> Pickup
10291 U2>> Pickup OUT U2>> Pickup
10292 U2> TimeOut OUT U2> TimeOut
10293 U2>> TimeOut OUT U2>> TimeOut
10294 U2>(>) TRIP OUT U2>(>) TRIP command
10300 U1< Pickup OUT U1< Pickup
10301 U1<< Pickup OUT U1<< Pickup
10302 U1< TimeOut OUT U1< TimeOut
Functions
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No. Information Type of
Informa-
tion
Comments
10303 U1<< TimeOut OUT U1<< TimeOut
10304 U1<(<) TRIP OUT U1<(<) TRIP command
10310 Uph-e< Pickup OUT Uph-e< Pickup
10311 Uph-e<< Pickup OUT Uph-e<< Pickup
10312 Uph-e<(<) PU L1 OUT Uph-e<(<) Pickup L1
10313 Uph-e<(<) PU L2 OUT Uph-e<(<) Pickup L2
10314 Uph-e<(<) PU L3 OUT Uph-e<(<) Pickup L3
10315 Uph-e< TimeOut OUT Uph-e< TimeOut
10316 Uph-e<< TimeOut OUT Uph-e<< TimeOut
10317 Uph-e<(<) TRIP OUT Uph-e<(<) TRIP command
10318 Uph-e< PU L1 OUT Uph-e< Pickup L1
10319 Uph-e< PU L2 OUT Uph-e< Pickup L2
10320 Uph-e< PU L3 OUT Uph-e< Pickup L3
10321 Uph-e<< PU L1 OUT Uph-e<< Pickup L1
10322 Uph-e<< PU L2 OUT Uph-e<< Pickup L2
10323 Uph-e<< PU L3 OUT Uph-e<< Pickup L3
10325 Uph-ph< Pickup OUT Uph-ph< Pickup
10326 Uph-ph<< Pickup OUT Uph-ph<< Pickup
10327 Uphph<(<)PU L12 OUT Uphph<(<) Pickup L1-L2
10328 Uphph<(<)PU L23 OUT Uphph<(<) Pickup L2-L3
10329 Uphph<(<)PU L31 OUT Uphph<(<) Pickup L3-L1
10330 Uphph< TimeOut OUT Uphph< TimeOut
10331 Uphph<< TimeOut OUT Uphph<< TimeOut
10332 Uphph<(<) TRIP OUT Uphph<(<) TRIP command
10333 Uphph< PU L12 OUT Uph-ph< Pickup L1-L2
10334 Uphph< PU L23 OUT Uph-ph< Pickup L2-L3
10335 Uphph< PU L31 OUT Uph-ph< Pickup L3-L1
10336 Uphph<< PU L12 OUT Uph-ph<< Pickup L1-L2
10337 Uphph<< PU L23 OUT Uph-ph<< Pickup L2-L3
10338 Uphph<< PU L31 OUT Uph-ph<< Pickup L3-L1
Functions
2.15 Under and over-voltage protection (optional)
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Frequency protection (optional)
The frequency protection function detects overfrequencies or underfrequencies in the system or in electrical
machines. If the frequency is outside the permissible range, appropriate actions are initiated such as load
shedding or separating the generator from the system.
Underfrequency is caused by increased real power demand of the loads or by a reduction of the generated
power e.g. in the event of disconnection from the network, generator failure or faulty operation of the power
frequency control. Underfrequency protection is also applied for generators which operate (temporarily) to an
island network. This is due to the fact that the reverse power protection cannot operate in case of a drive
power failure. The generator can be disconnected from the power system by means of the underfrequency
protection. Underfrequency also results in increased reactive power demand of inductive loads.
Overfrequency is caused for instance by load shedding, system disconnection or malfunction of the power
frequency control. There is also a risk of self-excitation for generators feeding long lines under no-load condi-
tions.
Functional Description
Frequency stages
Frequency protection consists of the four frequency stages f1 to f4 Each stage can be set as overfrequency
stage (f>) or as underfrequency stage (f<) with individual thresholds and time delays. This enables the stages
to be adapted to the particular application.
•If a stage is set to a value above the rated frequency, it is automatically interpreted to be an overfre-
quency stage f>.
•If a stage is set to a value below the rated frequency, it is automatically interpreted to be an underfre-
quency stage f<.
•If a stage is set exactly to the rated frequency, it is inactive.
Each stage can be blocked via binary input and also the entire frequency protection function can be blocked.
Frequency measurement
The largest of the 3 phase-to-phase voltages is used for frequency measurement. It must amount to at least 65
% of the nominal voltage set in parameter 204, Unom SECONDARY. Below that value frequency measurement
will not take place.
Numerical filters are used to calculate a virtual quantity from the measured voltage. This quantity is propor-
tional to the frequency and is practically linear in the specified range (fN ± 10 %). Filters and repeated meas-
urements ensure that the frequency measurement is free from harmonic and phase jumps influences.
An accurate and quick measurement result is obtained by considering also the frequency change. When
changing the frequency of the power system, the sign of the quotient Δf/dt remains unchanged during several
repeated measurements. If, however, a phase jump in the measured voltage temporarily simulates a
frequency deviation, the sign of Δf/dt will subsequently reverse. Thus the measurement results corrupted by a
phase jump are quickly discarded.
The dropout value of each frequency element is approximately 20 mHz below (for f>) or above (for f<) of the
pickup value.
Operating ranges
Frequency evaluation requires a measured quantity that can be processed. This implies that at least a suffi-
ciently high voltage is available and that the frequency of this voltage is within the working range of the
frequency protection.
The frequency protection automatically selects the largest of the phase-to-phase voltages. If all three voltages
are below the operating range of 65 % · UN (secondary), the frequency cannot be determined. In that case the
indication 5215
Freq UnderV Blk
is displayed. If the voltage falls below this minimum value after a
frequency stage has picked up, the picked up element will drop out. This implies also that all frequency stages
will drop out after a line has been switched off (with voltage transformers on line side).
2.16
2.16.1
Functions
2.16 Frequency protection (optional)
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When connecting a measuring voltage with a frequency outside the configured threshold of a frequency
stage, the frequency protection is immediately ready to operate. Since the filters of the frequency measure-
ment must first go through a transient state, the command output time may increase slightly (approx. 1
period). This is because a frequency stage picks up only if the frequency has been detected outside the config-
ured threshold in five consecutive measurements.
The frequency range is from 25 Hz to 70 Hz. If the frequency leaves this operating range, the frequency stages
will drop out. If the frequency returns into the operating range, the measurement can be resumed provided
that the measuring voltage is also inside the working range. But if the measuring voltage is switched off, the
picked up stage will drop out immediately.
Power swings
In interconnected networks, frequency deviations may also be caused by power swings. Depending on the
power swing frequency, the mounting location of the device and the setting of the frequency stages, power
swings may cause the frequency protection to pickup and even to trip. In such cases out-of-step trips cannot
be prevented by operating the distance protection with power swing blocking (see also Section 2.3 Power
swing detection (optional)). Rather, it is reasonable to block the frequency protection once power swings are
detected. This can be accomplished via binary inputs and binary outputs or by corresponding logic operations
using the user-defined logic (CFC). If, however, the power swing frequencies are known, tripping of the
frequency protection function can also be avoided by adapting the delay times of the frequency protection
correspondingly.
Pickup/tripping
Figure 2-133 shows the logic diagram for the frequency protection function.
Once the frequency was reliably detected to be outside the configured thresholds of a stage (above the setting
value for f> stages or below for f< stages), a pickup signal of the corresponding stage is generated. The deci-
sion is considered reliable if five measurements taken in intervals of 1/2 period yield one frequency outside the
set threshold.
After pickup, one delay time per stage can be started. When the associated time has elapsed, one trip
command per stage is issued. A picked up stage drops out if the cause of the pickup is no longer valid after
five measurements or if the measuring voltage was switched off or the frequency is outside the operating
range. When a frequency stage drops out, the tripping signal of of the corresponding frequency stage is imme-
diately terminated, but the trip command is maintained for at least the minimum command duration which
was set for all tripping functions of the device.
Each of the four frequency stages can be blocked individually by binary inputs. The blocking takes immediate
effect. It is also possible to block the entire frequency protection function via binary input.
Functions
2.16 Frequency protection (optional)
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[logikdiagramm-frequenzschutz-wlk-190802, 1, en_GB]
Figure 2-133 Logic diagram of the frequency protection
Setting Notes
General
Frequency protection is only in effect and accessible if address 136 FREQUENCY Prot. is set to Enabled. If
the function is not required, Disabled is to be set.
The frequency protection function features 4 frequency stages f1 to f4 each of which can function as overfre-
quency stage or underfrequency stage. Each stage can be set active or inactive. This is set in addresses:
•3601 O/U FREQ. f1 for frequency stage f1,
•3611 O/U FREQ. f2 for frequency stage f2,
•3621 O/U FREQ. f3 for frequency stage f3,
•3631 O/U FREQ. f4 for frequency stage f4.
The following 3 options are available:
2.16.2
Functions
2.16 Frequency protection (optional)
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•Stage OFF: The stage is ineffective;
•Stage ON: with Trip: The stage is effective and issues an alarm and a trip command (after time has
expired) following irregular frequency deviations;
•Stage ON: Alarm only: The stage is effective and issues an alarm but no trip command following irreg-
ular frequency deviations.
Pickup values, delay time
The configured pickup value determines whether a frequency stage is to respond to overfrequency or under-
frequency.
•If a stage is set to a value above the rated frequency, it is automatically interpreted to be an overfre-
quencystage f>.
•If a stage is set to a value below the rated frequency, it is automatically interpreted to be an underfre-
quency stage f<.
•If a stage is set exactly to the rated frequency, it is inactive.
A pickup value can be set for each stage according to above rules. The addresses and possible setting ranges
are determined by the nominal frequency as configured in the Power System Data 1 (Section 2.1.2.1 Setting
Notes) in Rated Frequency (address 230).
Please note that none of the frequency stages is set to less than 30 mHz above (for f>) or below (for f<) the
nominal frequency. Since the frequency stages have a hysteresis of approx. 20°mHz, it may otherwise happen
that the stage does not drop out when returning to the nominal frequency.
Only those addresses are accessible that match the configured nominal frequency. For each element, a trip
delay time can be set:
•address 3602 f1 PICKUP pickup value for frequency stage f1 at fN = 50 Hz,
address 3603 f1 PICKUP pickup value for frequency stage f1 at fN = 60 Hz,
address 3604 T f1 trip delay for frequency stage f1;
•address 3612 f2 PICKUP pickup value for frequency stage f2 at fN = 50 Hz,
address 3613 f2 PICKUP pickup value for frequency stage f2 at fN = 60 Hz,
address 3614 T f2 trip delay for frequency stage f2;
•address 3622 f3 PICKUP pickup value for frequency stage f3 at fN = 50 Hz,
address 3623 f3 PICKUP pickup value for frequency stage f3 at fN = 60 Hz,
address 3624 T f3 trip delay for frequency stage f3;
•address 3632 f4 PICKUP pickup value for frequency stage f4 at fN = 50 Hz,
address 3633 f4 PICKUP pickup value for frequency stage f4 at fN = 60 Hz,
address 3634 T f4 trip delay for frequency stage f4.
The set times are additional delay times not including the operating times (measuring time, dropout time) of
the protection function.
If underfrequency protection is used for load shedding purposes, then the frequency settings relative to other
feeder relays are generally based on the priority of the customers served by the protection relay. Normally, it is
required for load shedding a frecuency / time grading that takes into account the importance of the
consumers or consumer groups.
In interconnected networks, frequency deviations may also be caused by power swings. Depending on the
power swing frequency, the mounting location of the device and the setting of the frequency stages, it is
reasonable to block the entire frequency protection function or single stages once a power swing has been
detected. The delay times must then be co-ordinated thus that a power swing is detected before the
frequency protection trips.
Further application examples exist in the field of power stations. The frequency values to be set mainly
depend, also in these cases, on the specifications of the power system/power station operator. In this context,
the underfrequency protection also ensures the power station’s own demand by disconnecting it from the
Functions
2.16 Frequency protection (optional)
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power system on time. The turbo regulator regulates the machine set to the nominal speed. Consequently,
the station's own demands can be continuously supplied at nominal frequency
Since the dropout threshold is 20 mHz below or above the trip frequency, the resulting “minimum” trip
frequency is 30 mHz above or below the nominal frequency.
A frequency increase can, for example, occur due to a load shedding or malfunction of the speed regulation
(e.g. in a stand-alone system). In this way, the frequency protection can, for example, be used as overspeed
protection.
Settings
Addr. Parameter Setting Options Default Setting Comments
3601 O/U FREQ. f1 ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency Protection
stage f1
3602 f1 PICKUP 45.50 .. 54.50 Hz 49.50 Hz f1 Pickup
3603 f1 PICKUP 55.50 .. 64.50 Hz 59.50 Hz f1 Pickup
3604 T f1 0.00 .. 600.00 sec 60.00 sec T f1 Time Delay
3611 O/U FREQ. f2 ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency Protection
stage f2
3612 f2 PICKUP 45.50 .. 54.50 Hz 49.00 Hz f2 Pickup
3613 f2 PICKUP 55.50 .. 64.50 Hz 57.00 Hz f2 Pickup
3614 T f2 0.00 .. 600.00 sec 30.00 sec T f2 Time Delay
3621 O/U FREQ. f3 ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency Protection
stage f3
3622 f3 PICKUP 45.50 .. 54.50 Hz 47.50 Hz f3 Pickup
3623 f3 PICKUP 55.50 .. 64.50 Hz 59.50 Hz f3 Pickup
3624 T f3 0.00 .. 600.00 sec 3.00 sec T f3 Time Delay
3631 O/U FREQ. f4 ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency Protection
stage f4
3632 f4 PICKUP 45.50 .. 54.50 Hz 51.00 Hz f4 Pickup
3633 f4 PICKUP 55.50 .. 64.50 Hz 62.00 Hz f4 Pickup
3634 T f4 0.00 .. 600.00 sec 30.00 sec T f4 Time Delay
Information List
No. Information Type of
Informa-
tion
Comments
5203 >BLOCK Freq. SP >BLOCK frequency protection
5206 >BLOCK f1 SP >BLOCK frequency protection stage f1
5207 >BLOCK f2 SP >BLOCK frequency protection stage f2
5208 >BLOCK f3 SP >BLOCK frequency protection stage f3
5209 >BLOCK f4 SP >BLOCK frequency protection stage f4
5211 Freq. OFF OUT Frequency protection is switched OFF
5212 Freq. BLOCKED OUT Frequency protection is BLOCKED
5213 Freq. ACTIVE OUT Frequency protection is ACTIVE
2.16.3
2.16.4
Functions
2.16 Frequency protection (optional)
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No. Information Type of
Informa-
tion
Comments
5215 Freq UnderV Blk OUT Frequency protection undervoltage Blk
5232 f1 picked up OUT Frequency protection: f1 picked up
5233 f2 picked up OUT Frequency protection: f2 picked up
5234 f3 picked up OUT Frequency protection: f3 picked up
5235 f4 picked up OUT Frequency protection: f4 picked up
5236 f1 TRIP OUT Frequency protection: f1 TRIP
5237 f2 TRIP OUT Frequency protection: f2 TRIP
5238 f3 TRIP OUT Frequency protection: f3 TRIP
5239 f4 TRIP OUT Frequency protection: f4 TRIP
5240 Time Out f1 OUT Frequency protection: TimeOut Stage f1
5241 Time Out f2 OUT Frequency protection: TimeOut Stage f2
5242 Time Out f3 OUT Frequency protection: TimeOut Stage f3
5243 Time Out f4 OUT Frequency protection: TimeOut Stage f4
Functions
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Fault locator
The measurement of the distance to a fault is an important supplement to the protection functions. Availa-
bility of the line for power transmission within the system can be increased when the fault is located.
Functional Description
Initiation Conditions
The fault location function in the 7SA522 distance protection is independent of the distance measurement. It
has a separate measured value memory and dedicated filter algorithms. The short-circuit protection merely
has to provide a start command to determine the valid measuring loop and the best suited time interval for
storing the measured quantities.
The fault location function can be triggered by the trip command of the short-circuit protection, or also by
each fault detection. In the latter case, a fault location calculation is also possible if a different protection
device clears the fault. For a fault outside the protected line, the fault location information is not always
correct, as the measured values can be distorted by e.g. intermediate infeeds.
Determination of the Fault Location
The measured value pairs of fault currents and fault voltages (in intervals of 1/20 period) are stored in a cyclic
buffer and frozen shortly after the trip command is issued before any distortion of the measured values occurs
due to the opening of the circuit breaker even with very fast circuit breakers. Filtering of the measured values
and the number of impedance calculations are automatically adapted to the number of stabilized measured
value pairs in the determined data window. If a sufficient data window with stabilized values could not be
determined, the annunciation
Flt.Loc.invalid
is issued.
The evaluation of the measured values in the short-circuit loops is carried out after the short-circuit has been
cleared. Short-circuit loops are those which caused the trip. In the event of tripping by the earth fault protec-
tion, the three phase–earth loops are evaluated.
Output of the Fault Locator
The fault locator issues the following results:
•The short-circuit loop which was used to determine the fault reactance,
•Fault reactance X in Ω primary and Ω secondary,
•Fault resistance R in Ω primary and Ω secondary,
•The distance to fault d in kilometers or miles of the line proportional to the reactance, converted on the
basis of the set line reactance per unit line length,
•The distance to fault d in % of the line length, calculated on the basis of the set reactance per unit length
and the set line length.
The fault location indicated in per cent can, at the same time, be output as BCD-code (Binary Coded Decimal).
This, however, must have been preset in address 138 during the configuration of the protection functions
(Section 2.1.1.2 Setting Notes). A further prerequisite is that the required number of binary outputs is allo-
cated for this purpose.
10 output relays are needed. They are classified as follows:
•4 outputs for the units (1·20 + 1·21 + 1·22 + 1·23),
•4 outputs for the tens (10·20 + 10·21 + 10·22 + 10·23),
•1 output for the hundreds (100·20),
•1 output for the ready-state annunciation
BCD dist. VALID
(No. 1152).
Once a fault was located, the corresponding binary outputs pick up. Then the output
BCD dist. VALID
signals that the data are now valid. The duration can be set. In the event of a new fault, the data of the former
fault are cleared automatically.
2.17
2.17.1
Functions
2.17 Fault locator
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The output range extends from 0 % to 195 %. Output “197” means that a negative fault was detected. Output
“199” describes an overflow, i. e. the calculated value is higher than the maximum possible value of 195 %.
i
i
NOTE
The distance information in kilometers, miles or percent is only accurate for homogenous line sections. If
the line is made up of several sections with different reactances per unit length, e.g. overhead line-cable
sections, the reactance calculated by the fault location function can be evaluated for a separate calculation
of the fault distance.
Parallel Line Measured Value Correction (optional)
In the case of earth faults on double circuit lines, the measured values obtained for calculation of the impe-
dance are influenced by the mutual coupling of the earth impedance of both parallel lines. This causes meas-
uring errors in the result of the impedance computation unless special measures are taken. The device is
therefore provided with a parallel line compensation function. This function takes the earth current of the
parallel line into consideration when solving the line equation, thereby compensating for the coupling influ-
ence as was the case with the derivation of the distance by the distance protection (refer to Section
2.2.1 Distance protection, general settings under “Parallel Line Measured Value Correction”). The earth current
of the parallel line must, of course, be connected to the device and the current input Ι4 must be configured
accordingly during the setting of the Power System Data 1 (Section 2.1.2.1 Setting Notes under “Current
Transformer Connection”).
The parallel line compensation only applies to faults on the protected feeder. For external faults, including
those on the parallel line, compensation is impossible.
Correction of Measured Values for Load Current on Double-end Fed Lines
When faults occur on loaded lines fed from both ends (Figure 2-134), the fault voltage UF1 is influenced not
only by the source voltage E1, but also by the source voltage E2, when both voltages are applied to the
common earth resistance RF. This causes measuring errors in the result of the impedance computation unless
special measures are taken, since the current component ΙF2 cannot be seen at the measuring point M. For
long heavily loaded lines, this can give a significant error in the X–component of the fault impedance (the
determining factor for the distance calculation).
A load compensation feature in 7SA522 is provided for the fault location calculation which largely corrects this
measurement inaccuracy for single-phase short-circuits. Correction for the R–component of the fault impe-
dance is not possible; but the resultant inaccuracy is not critical, since only the X–component is critical for the
distance to fault indication.
Load compensation is effective for single–phase faults. Positive and zero phase sequence components are
used in the compensation.
Load compensation can be switched on or off. Switching it off is useful, for example, during relay testing in
order to avoid influences caused by the test quantities.
[fehlerstr-spgn-beid-gesp-ltg-wlk-010802, 1, en_GB]
Figure 2-134 Fault currents and voltages on double–end fed lines
M : Measuring point
E1, E2 : Source voltage (EMF)
Functions
2.17 Fault locator
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IF1, IF2 : Partial fault currents
IF1 + IF2 : Total fault current
UF1 : Fault voltage at the measuring point
RF : Common fault resistance
ZF1, ZF2 : Fault impedances
ZF1E, ZF2E : Earth fault impedances
ZS1, ZS2 : Source impedances
ZS1E, ZS2E : Earth source impedances
Setting Notes
General
The fault location function is only in service if it was set to Enabled during the configuration of the device
functions (Section 2.1.1.2 Setting Notes, address 138).
If the fault location calculation is to be started by the trip command of the protection, set address 3802 START
= TRIP. In this case a fault location is only output if the device has also issued a trip. The fault location calcula-
tion can however also be started with each fault detection of the device (address 3802 START = Pickup). In
this case the fault location is also calculated if for example a different protection device cleared the fault. For a
fault outside the protected line, the fault location information is not always correct, as the measured values
can be distorted by e.g. intermediate infeeds.
To calculate the distance to fault in kilometers or miles, the device requires the reactance per unit length data
in Ω/km or Ω/mile. For correct indication of the fault location in % of line length, the correct line length has
also to be entered. These setting parameters were already applied with the Power System Data 2 (Section
2.1.4.1 Setting Notes at “General Line Data”).
A prerequisite for the correct indication of the fault location furthermore is that the other parameters that
influence the calculation of the distance to fault have also been set correctly. This concerns the following
addresses
1116 RE/RL(Z1),
1117 XE/XL(Z1)
or
1120 K0 (Z1),
1121 Angle K0(Z1).
If the parallel line compensation is used, set address 3805 Paral.Line Comp to YES (presetting for devices
with parallel line compensation). Further prerequisites are that
•the earth current of the parallel line has been connected to the fourth current input Ι4 with the correct
polarity and
•the current transformer ratio I4/Iph CT (address 221) in the Power System Data 1 has been set
correctly (refer also to Section2.1.2.1 Setting Notes under “Current Transformer Connection”) and
•the parameter for the fourth current input I4 transformer has been set to In paral. line
(address 220) in the Power System Data 1 (Section 2.1.2.1 Setting Notes under “Current Transformer
Connection”) and
•the mutual impedances RM/RL ParalLine and XM/XL ParalLine (addresses 1126 and 1127) have
been set correctly in the general protection data (Power System Data 2, Section 2.1.4.1 Setting Notes).
If load compensation is applied to single-phase faults in double-fed lines of an earthed system, set YES in
address 3806 Load Compensat.. If high fault resistances are expected for single-phase faults, e.g. at over-
head lines without overhead earth wire or unfavourable earthing conditions of the towers, this will improve
the accuracy of the distance calculation.
If the fault location is required to be output as BCD-code, set the maximum time period the data should be
available at the outputs using address 3811 Tmax OUTPUT BCD. If a new fault occurs, the data are termi-
nated immediately even when it occurs before this time has expired. Allocate the corresponding output relays
2.17.2
Functions
2.17 Fault locator
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as stored if a longer time period is desired for the output. Once a fault occurred the data will be latched until
the memory is reset or a new fault is registered.
Settings
Addr. Parameter Setting Options Default Setting Comments
3802 START Pickup
TRIP
Pickup Start fault locator with
3805 Paral.Line Comp NO
YES
YES Mutual coupling parall.line
compensation
3806 Load Compensat. NO
YES
NO Load Compensation
3811 Tmax OUTPUT BCD 0.10 .. 180.00 sec 0.30 sec Maximum output time via BCD
Information List
No. Information Type of
Informa-
tion
Comments
1114 Rpri = VI Flt Locator: primary RESISTANCE
1115 Xpri = VI Flt Locator: primary REACTANCE
1117 Rsec = VI Flt Locator: secondary RESISTANCE
1118 Xsec = VI Flt Locator: secondary REACTANCE
1119 dist = VI Flt Locator: Distance to fault
1120 d[%] = VI Flt Locator: Distance [%] to fault
1122 dist = VI Flt Locator: Distance to fault
1123 FL Loop L1E OUT_Ev Fault Locator Loop L1E
1124 FL Loop L2E OUT_Ev Fault Locator Loop L2E
1125 FL Loop L3E OUT_Ev Fault Locator Loop L3E
1126 FL Loop L1L2 OUT_Ev Fault Locator Loop L1L2
1127 FL Loop L2L3 OUT_Ev Fault Locator Loop L2L3
1128 FL Loop L3L1 OUT_Ev Fault Locator Loop L3L1
1132 Flt.Loc.invalid OUT Fault location invalid
1133 Flt.Loc.ErrorK0 OUT Fault locator setting error K0,angle(K0)
1143 BCD d[1%] OUT BCD Fault location [1%]
1144 BCD d[2%] OUT BCD Fault location [2%]
1145 BCD d[4%] OUT BCD Fault location [4%]
1146 BCD d[8%] OUT BCD Fault location [8%]
1147 BCD d[10%] OUT BCD Fault location [10%]
1148 BCD d[20%] OUT BCD Fault location [20%]
1149 BCD d[40%] OUT BCD Fault location [40%]
1150 BCD d[80%] OUT BCD Fault location [80%]
1151 BCD d[100%] OUT BCD Fault location [100%]
1152 BCD dist. VALID OUT BCD Fault location valid
2.17.3
2.17.4
Functions
2.17 Fault locator
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Circuit breaker failure protection (optional)
The circuit breaker failure protection provides rapid back-up fault clearance in the event that the circuit
breaker fails to respond to a trip command from a protection function of the local circuit breaker.
Functional Description
General
Whenever e.g. a short-circuit protection relay of a feeder issues a trip command to the circuit breaker, this is
repeated to the circuit breaker failure protection (Figure 2-135). A timer T–BF in the circuit breaker failure
protection is started. The timer runs as long as a trip command is present and current continues to flow
through the circuit breaker poles.
[funktionsschema-lvs-ueberwach-wlk-010802, 1, en_GB]
Figure 2-135 Simplified function diagram of circuit breaker failure protection with current flow monitoring
Normally, the circuit breaker will open and interrupt the fault current. The current monitoring stage quickly
resets (typical 10 ms) and stops the timer T–BF.
If the trip command is not carried out (circuit breaker failure case), current continues to flow and the timer
runs to its set limit. The circuit breaker failure protection then issues a command to trip the backup circuit
breakers and interrupt the fault current.
The reset time of the feeder protection is not relevant because the circuit breaker failure protection itself
recognizes the interruption of the current.
For protection functions where the tripping criterion is not dependent on current (e.g. Buchholz protection),
current flow is not a reliable criterion for proper operation of the circuit breaker. In such cases, the circuit
breaker position can be derived from the auxiliary contacts of the circuit breaker. Therefore, instead of moni-
toring the current, the position of the auxiliary contacts is monitored (Figure 2-136). For this purpose, the
outputs from the auxiliary contacts must be fed to binary inputs on the relay (refer also to Section
2.20.1 Function Control).
2.18
2.18.1
Functions
2.18 Circuit breaker failure protection (optional)
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[funktionsschema-lvs-lshiko-wlk-010802, 1, en_GB]
Figure 2-136 Simplified function diagram of circuit breaker failure protection controlled by circuit breaker
auxiliary contact
Current flow monitoring
Each of the phase currents and an additional plausibility current (see below) are filtered by numerical filter
algorithms so that only the fundamental component is used for further evaluation.
Special features recognize the instant of current interruption. In case of sinusoidal currents the current inter-
ruption is detected after approximately a 3/4 cycle. With aperiodic DC current components in the fault current
and/or in the current transformer secondary circuit after interruption (e.g. current transformers with linearized
core), or saturation of the current transformers caused by the DC component in the fault current, it can take
up to 1 1/4 AC cycles before the interruption of the primary current is reliably detected.
The currents are monitored and compared with the set limit value. Besides the three phase currents, two
further current thresholds are provided in order to allow a plausibility check. If configured correspondingly, a
separate threshold value can be used for this plausibility check (see Figure 2-137).
The earth current ΙE (3·Ι0) is preferably used as plausibility current. The earth current from the starpoint of the
current transformer set will be used if it is connected to the device. If this current is not available, the device
will calculate it from the phase currents using this formula:
3·Ι0 = ΙL1 + ΙL2 + ΙL3
Additionally, the value calculated by 7SA522 of three times the negative sequence current 3·Ι2 is used for
plausibility check. This is calculated according to the equation:
3·Ι2 = ΙL1 + a2·ΙL2 + a·ΙL3
mit
a = ej120°.
These plausibility currents do not have any direct influence on the basic functionality of the circuit breaker
failure protection but they allow a plausibility check in that at least two current thresholds must have been
exceeded before any of the circuit breaker failure delay times can be started, thus providing high security
against false operation.
In case of high-resistance earth faults it may occur that the earth current exceeds the sensitively parameter-
ized threshold value 3I0> BF (address 3912), the phase current involved in the short-circuit, however, does
not exceed the threshold value I> BF (address 3902).The plausibility monitoring would prevent the breaker
failure protection from being initiated. In this case the pickup threshold of the phase current monitoring I>
BF can be switched over to the threshold value 3I0> BF. For this purpose, use the binary input 1404
>BFac-
tivate3I0>
. This binary input is linked to an external signal which indicates a high resistance fault, e.g.
earth fault detection, or detection of displacement voltage. With this method, the more sensitively parameter-
ized earth current threshold is also used for the phase current monitoring (Figure 2-137).
Functions
2.18 Circuit breaker failure protection (optional)
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[logik-strmflsueberw-plausibilitaet-110113, 1, en_GB]
Figure 2-137 Current flow monitoring with plausibility currents 3·Ι0 und 3·Ι2
1) only available/visible if 139 is set to enabled w/ 3I0>
Monitoring the circuit breaker auxiliary contacts
It is the central function control of the device that informs the circuit breaker failure protection on the position
of the circuit breaker (see Section 2.20.1 Function Control). The evaluation of the circuit breaker auxiliary
contacts is carried out in the circuit breaker failure protection function only when the current flow monitoring
has not picked up. Once the current flow criterion has picked up during the trip signal from the feeder protec-
tion, the circuit breaker is assumed to be open as soon as the current disappears, even if the associated auxil-
iary contact does not (yet) indicate that the circuit breaker has opened (Figure 2-138). This gives preference to
the more reliable current criterion and avoids overfunctioning due to a defect e.g. in the auxiliary contact
mechanism or circuit. This interlock feature is provided for each individual phase as well as for 3-pole tripping.
It is possible to disable the auxiliary contact criterion. If you set the parameter switch Chk BRK CONTACT
(Figure 2-140 top) to NO the circuit breaker failure protection can only be started when current flow is
detected. The position of the auxiliary contacts is then not evaluated even if the auxiliary contacts are
connected to the device.
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[logik-verriegel-hikos-wlk-010802, 1, en_GB]
Figure 2-138 Interlock of the auxiliary contact criterion - example for phase L1
1) if phase-segregated auxiliary contacts are available
2) if series-connected NC contacts are available
On the other hand, current flow is not a reliable criterion for proper operation of the circuit breaker for faults
which do not cause detectable current flow (e.g. Buchholz protection). Information regarding the position of
the circuit breaker auxiliary contacts is required in these cases to check the correct response of the circuit
breaker. For this purpose, the binary input
>BF Start w/o I
No. 1439 (Figure 2-140 left). This input
initiates the circuit breaker failure protection even if no current flow is detected.
Common phase initiation
Common phase initiation is used, for example, in systems with only 3-pole tripping, for transformer feeders,
or if the busbar protection trips. It is the only available initiation mode when using the 7SA522 version capable
of 3- pole tripping only.
If the circuit breaker failure protection is intended to be initiated by further external protection devices, it is
recommended, for security reasons, to connect two binary inputs to the device. Besides the trip command of
the external protection to the binary input
>BF Start 3pole
No. 1415 it is recommended to connect also
the general device pickup to binary input
>BF release
No. 1432. For Buchholz protection it is recom-
mended that both inputs are connected to the device by two separate wire pairs.
Nevertheless, it is possible to initiate the circuit breaker failure protection in single-channel mode should a
separate release criterion not be available. The binary input
>BF release
(No. 1432) must then not be
assigned to any physical input of the device during configuration.
Figure 2-140 shows the operating principle. When the trip signal appears from any internal or external feeder
protection and at least one current flow criterion according to Figure 2-137 is present, the circuit breaker
failure protection is initiated and the corresponding delay time(s) is (are) started.
If the current criterion is not fulfilled for any of the phases, the position of the circuit breaker auxiliary contact
can be queried as shown in Figure 2-139. If the circuit breaker poles have individual auxiliary contacts, the
series connection of the three normally closed (NC) auxiliary contacts is used. After a 3-pole trip command the
circuit breaker has only operated correctly if no current is flowing via any phase or alternatively all three auxil-
iary contacts indicate the CB is open.
Figure 2-139 illustrates how the internal signal “CB pole ≥L1 closed” is created (see Figure 2-140 left) if at least
one circuit breaker pole is closed.
By means of the binary input 1424
>BF STARTonlyT2
, the tripping delay 3906 T2 can be started. After this
time stage has elapsed, the circuit breaker failure TRIP command 1494
BF T2-TRIP(bus)
is issued.
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[logik-entsteh-signal-ls-hiko-wlk-010802, 1, en_GB]
Figure 2-139 Creation of signal "CB ≥ any pole closed"
If an internal protection function or an external protection device trips without current flow, the circuit
breaker failure protection is initiated by the internal input “Start internal w/o Ι”, if the trip signal comes from
the internal voltage protection or frequency protection, or by the external input
>BF Start w/o I
. In this
case the start signal is maintained until the circuit breaker is reported to be open by the auxiliary contact crite-
rion.
Initiation can be blocked via the binary input
>BLOCK BkrFail
(e.g. during test of the feeder protection
relay).
[logik-svs-phasengem-anwurf-wlk-010802, 1, en_GB]
Figure 2-140 Breaker failure protection with common phase initiation
Phase-segregated initiation
Phase segregated initiation of the circuit breaker failure protection is necessary if the circuit breaker poles are
operated individually, e.g. if 1-pole automatic reclosure is used. This is possible if the device is able to trip 1-
pole.
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If the circuit breaker failure protection is intended to be initiated by further external protection devices, it is
recommended, for security reasons, to connect two binary inputs to the device. Besides the three trip
commands of the external relay to the binary input
>BF Start L1
,
>BF Start L2
and
>BF Start L3
it
is recommended to connect also, for example, the general device pickup to binary input
>BF release
.
Figure 2-141 shows this connection.
Nevertheless, it is possible to initiate the circuit breaker failure protection in single-channel mode should a
separate release criterion not be available. The binary input
>BF release
must then not be assigned to any
physical input of the device during configuration.
If the external protection device does not provide a general fault detection signal, a general trip signal can be
used instead. Alternatively, the parallel connection of a separate set of trip contacts can produce such a
release signal as shown in Figure 2-142.
[svs-phasegetr-anwurf-ext-geraet-wlk-010802, 1, en_GB]
Figure 2-141 Breaker failure protection with phase segregated initiation — example for initiation by an
external protection device with release by a fault detection signal
[svs-phasegetr-anwurf-ext-geraet-frei-ausloese-wlk-010802, 1, en_GB]
Figure 2-142 Schalterversagerschutz mit phasengetrenntem Anwurf — Beispiel für Anwurf von externem
Schutzgerät mit Freigabe durch einen getrennten Satz Auslösekontakte
In principle, the starting condition logic for the delay time(s) is designed similar to that for the common phase
initiation, however, individually for each of the three phases (as shown in Figure 2-143). Thus, current and
initiation conditions are processed for each CB pole. Also during a 1-pole automatic reclosure, the current
interruption is reliably monitored for the tripped CB pole only.
Initiation of an individual phase, e.g. “Start L1”, is only valid if the starting signal (= tripping signal of the
feeder protection) appears for this phase and if the current criterion is met for at least this phase. If it is not
met, the circuit breaker auxiliary contact can be interrogated according to Figure 2-138 – if parameterised
(Chk BRK CONTACT = YES).
The auxiliary contact criterion is also processed for each individual circuit breaker pole. If, however, the circuit
breaker auxiliary contacts are not available for each individual circuit breaker pole, then a 1-pole trip
command is assumed to be executed only if the series connection of the normally open (NO) auxiliary
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contacts is interrupted. This information is provided to the circuit breaker failure protection by the central
function control of the device (refer to Section 2.20.1 Function Control).
The 3-phase starting signal “Start L123” is generated if there are start signals for more than one phase. The
input "BF Start w/o I" (e.g. from Buchholz protection) operates only in 3-phase mode. The function is the same
as with common phase initiation.
The additional release-signal
>BF release
(if assigned to a binary input) affects all external initiation condi-
tions. Initiation can be blocked via the binary input
>BLOCK BkrFail
(e.g. during test of the feeder protec-
tion relay).
[logik-7vk61-anwurfbed-1-pol-ausloese, 1, en_GB]
Figure 2-143 Initiation conditions for single-pole trip commands
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Delay times
When the initiatiation conditions are fulfilled, the associated timers are started. The circuit breaker pole(s)
must open before the associated time has elapsed.
Different delay times are possible for 1-pole and 3-pole initiation. An additional delay time can be used for
twostage circuit breaker failure protection.
With single-stage circuit breaker failure protection, the trip command is relayed to the adjacent circuit breakers
which interrupt the fault current if the local feeder breaker fails (see Figure 2-135 and Figure 2-136). The adja-
cent circuit breakers are those located at the busbar or busbar section to which the feeder under consideration
is connected. The possible initiation conditions for the circuit breaker failure protection are those discussed
above. Depending on the application of the feeder protection, common phase or phase-segregated initiation
conditions may occur. The circuit breaker failure protection always trips 3-pole.
The simplest solution is to start the delay timer T2 (Figure 2-144). The phase-segregated initiation signals are
omitted if the feeder protection always trips 3-pole or if the circuit breaker is not capable of 1-pole tripping.
If different delay times are required after a 1-pole trip or 3-pole trip it is possible to use the timer stages
T1-3pole and T1-1pole according to Figure 2-145.
[logik-1-stufiger-svs-phgem-anwurf-wlk-010802, 1, en_GB]
Figure 2-144 Single-stage breaker failure protection with common phase initiation
[logik-1-stufiger-svs-unterscht-verz-t-wlk-010802, 1, en_GB]
Figure 2-145 Single-stage breaker failure protection with different delay times
With two-stage circuit breaker failure protection the trip command of the feeder protection is usually
repeated, after a first time stage, to the feeder circuit breaker, often via a second trip coil or set of trip coils, if
the circuit breaker has not responded to the original trip command. A second time stage monitors the
response to this repeated trip command and trips the circuit breakers of the relevant busbar section if the fault
has not yet been cleared after this second time.
For the first stage, a different delay T1-1pole can be set for 1-pole trip than for 3-pole trip by the feeder
protection. Additionally, you can select (by setting parameter 1p-RETRIP (T1)) whether this repeated trip
should be 1-pole or 3-pole. In case of a multi-pole tripping of the feeder protection, T1-1pole and T1-3pole
are started simultaneously. By means of T1-3pole, the tripping of the circuit breaker failure protection can
be accelerated in comparison to T1-1pole.
Address 3913 T2StartCriteria is used to set whether the delay time T2 will be started after expiry of T1
(T2StartCriteria = With exp. of T1) or simultaneously with it (T2StartCriteria = Parallel
withT1). The time T2 can also be initiated via a separate binary input 1424
>BF STARTonlyT2
.
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[logik-7vk61-2-stufiger-svs-phgem-anwurf, 1, en_GB]
Figure 2-146 Logic diagram of the two-stage breaker failure protection
Circuit breaker not operational
There may be cases when it is already obvious that the circuit breaker associated with a feeder protection relay
cannot clear a fault, e.g. when the tripping voltage or the tripping energy is not available.
In such a case it is not necessary to wait for the response of the feeder circuit breaker. If provision has been
made for the detection of such a condition (e.g. control voltage monitor or air pressure monitor), the monitor
alarm signal can be fed to the binary input
>CB faulty
of the 7SA522. On occurrence of this alarm and a trip
command by the feeder protection, a separate timer T3-BkrDefective is started (see Figure 2-147), which
is normally set to 0. Thus, the adjacent circuit breakers (bus-bar) are tripped immediately in case the feeder
circuit breaker is not operational.
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[logik-ls-gestoert-wlk-010802, 1, en_GB]
Figure 2-147 Circuit breaker faulty
Transfer trip to the remote end circuit breaker
The device has the facility to provide an additional intertrip signal to the circuit breaker at the remote line end
in the event that the local feeder circuit breaker fails. For this, a suitable protection signal transmission link is
required (e.g. via communication cable, power line carrier transmission, radio transmission, or optical fibre
transmission). With devices using digital transmission via protection interface, the remote commands can be
applied (see also Section 2.5 Remote signals via protection data interface (optional)).
To realise this intertrip, the desired command — usually the trip command which is intended to trip the adja-
cent circuit breakers — is assigned to a binary output of the device. The contact of this output triggers the
transmission device. When using digital signal transmission, the command is connected to a remote command
via the user-defined logic (CFC).
End fault protection
An end fault is defined here as a short–circuit which has occurred at the end of a line or protected object,
between the circuit breaker and the current transformer set.
Figure 2-148 shows the situation. The fault is located — as seen from the current transformer (= measure-
ment location) — on the busbar side, it will thus not be regarded as a feeder fault by the feeder protection
relay. It can only be detected by either a reverse stage of the feeder protection or by the busbar protection.
However, a trip command given to the feeder circuit breaker does not clear the fault since the opposite end
continues to feed the fault. Thus, the fault current does not stop flowing even though the feeder circuit
breaker has properly responded to the trip command.
[endfehler-ls-strwdlr-wlk-010802, 1, en_GB]
Figure 2-148 End fault between circuit breaker and current transformers
The end fault protection has the task to recognize this situation and to transmit a trip signal to the remote
end(s) of the protected object to clear the fault. For this purpose, the output command
BF EndFlt TRIP
is
available to trigger a signal transmission device (e.g. power line carrier, radio wave, or optical fibre) — if appli-
cable, together with other commands that need to be transferred or (when using digital signal transmission)
as command via the protection data interface.
The end fault is recognized when the current continues flowing although the circuit breaker auxiliary contacts
indicate that the circuit breaker is open. An additional criterion is the presence of any circuit breaker failure
protection initiate signal. Figure 2-149 illustrates the functional principle. If the circuit breaker failure protec-
tion is initiated and current flow is detected (current criteria “L*> current criterion” according to Figure 2-137),
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but no circuit breaker pole is closed (auxiliary contact criterion “any pole closed”), then the timer T-EndFault
is started. At the end of this time an intertrip signal is transmitted to the opposite end(s) of the protected
object.
[funktionsschema-endfehlerschutz-wlk-010802, 1, en_GB]
Figure 2-149 Functional scheme of the end fault protection
Pole discrepancy supervision
The pole discrepancy supervision has the task to detect discrepancies in the position of the three circuit
breaker poles. Under steady-state operating conditions, either all three poles of the circuit breaker must be
closed, or all three poles must be open. Discrepancy is permitted only for a short time interval during a 1-pole
automatic reclose cycle.
Figure 2-150 the functional principle. The signals which are processed here are the same as those used for the
circuit breaker failure protection. The pole discrepancy condition is established when at least one pole is
closed (“ ≥ one pole closed”) and at the same time not all three poles are closed (“ ≥ one pole open”).
Additionally, the current criteria (from Figure 2-137) are processed Pole discrepancy can only be detected
when current is not flowing through all three poles, i.e. through only one or two poles. When current is
flowing through all three poles, all three poles must be closed even if the circuit breaker auxiliary contacts
indicate a different status.
Detection of the discrepancy of the CB poles is signaled phase-selective as “Pickup”. The signal identifies the
pole that was open before the trip command of the pole discrepancy supervision occurred.
[logikschema-schalt-gleichlfueberwch-wlk-010802, 1, en_GB]
Figure 2-150 Function diagram of pole discrepancy supervision
Setting Notes
General
The circuit breaker failure protection and its ancillary functions (end fault protection, pole discrepancy supervi-
sion) can only operate if they were set during configuration of the scope of functions (address 139 BREAKER
FAILURE) to Enabled or enabled w/ 3I0>.
Circuit breaker failure protection
The circuit breaker failure protection is switched ON or OFF at address 3901 FCT BreakerFail.
2.18.2
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The current threshold I> BF (address 3902) should be selected such that the protection will operate with the
smallest expected short-circuit current. A setting of 10% below the minimum fault current for which circuit
breaker failure protection must operate is recommended. On the other hand, the value should not be set
lower than necessary.
If the circuit breaker failure protection is configured with zero sequence current threshold (address 139 =
vorh. mit 3I0>), the pickup threshold for the zero sequence current 3I0> BF (address 3912) can be set
independently of I> BF.
Normally, the circuit breaker failure protection evaluates the current flow criterion as well as the position of
the circuit breaker auxiliary contact(s). If the auxiliary contact(s) status is not available in the device, this crite-
rion cannot be processed. In this case, set address 3909 Chk BRK CONTACT to NO.
Two-stage circuit breaker failure protection
With two-stage operation, the trip command is repeated after a time delay T1 to the local feeder circuit
breaker, normally to a different set of trip coils of this circuit breaker. A choice can be made whether this trip
repetition shall be 1-pole or 3-pole if the initial feeder protection trip was 1-pole (provided that 1-pole trip is
possible). This choice is made in address 3903 1p-RETRIP (T1). Set this parameter to YES if the first stage
is to trip 1-pole, otherwise set it to NO.
If the circuit breaker does not respond to this trip repetition, the adjacent circuit breakers are tripped after T2,
i.e. the circuit breakers of the busbar or of the concerned busbar section and, if necessary, also the circuit
breaker at the remote end unless the fault has been cleared.
Separate delay times can be set
•for 1- or 3-pole trip repetition to the local feeder circuit breaker after a 1-pole trip of the feeder protection
T1-1pole at address 3904,
•for 3-pole trip repetition to the local feeder circuit breaker after 3-pole trip of the feeder protection
T1-3pole (address 3905),
•for trip of the adjacent circuit breakers (busbar zone and remote end if applicable) T2 at address 3906.
i
i
NOTE
In case of multi-phase tripping of the feeder protection, T1-1pole and T1-3pole are started in parallel.
T1-3pole therefore allows accelerating the tripping of the breaker failure protection compared to
T1-1pole. Therefore, you should set T1-1pole equal to or longer than T1-3pole.
The delay times are set dependant on the maximum operating time of the feeder circuit breaker and the reset
time of the current detectors of the circuit breaker failure protection, plus a safety margin which allows for any
tolerance of the delay timers. Figure 2-151 illustrates the timing of a typical circuit breaker failure scenario.
The dropout time for sinusoidal currents is ≤ 15 ms. If current transformer saturation is anticipated, the time
should be set to 25 ms.
i
i
NOTE
If the breaker failure protection is to perform a single-pole TRIP repetition, the time set for the AR,
address3408 T-Start MONITOR, has to be longer than the time set for address 3903 1p-RETRIP (T1)
to prevent 3-pole coupling by the AR before T1 expires.
To prevent AR after
BF T2-TRIP(bus)
, the time 3408T-Start MONITOR can be set to expire together
with T2.
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[ls-versag-zeitabl-2stuf-versag-oz-020802, 1, en_GB]
Figure 2-151 Time sequence example for normal clearance of a fault, and with circuit breaker failure, using
two-stage breaker failure protection
Single-stage circuit breaker failure protection
With single-stage operation, the adjacent circuit breakers (i.e. the circuit breakers of the busbar zone and, if
applicable, the circuit breaker at the remote end) are tripped after a delay time T2 (address 3906) should the
fault not have been cleared within this time.
The times T1-1pole (address 3904) and T1-3pole (address 3905) are then set to ∞ since they are not
needed.
You can also use the first stage alone if you wish to use different delay times after 1-pole and 3-pole tripping
of the feeder protection. In this case set T1-1pole (address 3904) and T1-3pole (address 3905) separately,
but address 3903 1p-RETRIP (T1) to NO, to avoid a 1-pole trip command to the busbar. Set T2
(address3906) to ∞ or equal to T1-3pole (address 3905). Be sure that the correct trip commands are
assigned to the desired trip relay(s).
The delay time is determined from the maximum operating time of the feeder circuit breaker, the reset time of
the current detectors of the circuit breaker failure protection, plus a safety margin which allows for any toler-
ance of the delay timers. Figure 2-152 illustrates the timing of a typical circuit breaker failure scenario The
dropout time for sinusoidal currents is ≤ 15 ms. If current transformer saturation is anticipated, the time
should be set to 25 ms.
[ls-versag-zeitabl-1stuf-versag-oz-020802, 1, en_GB]
Figure 2-152 Time sequence example for normal clearance of a fault, and with circuit breaker failure, using
single-stage breaker failure protection
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Circuit breaker not operational
These delays are not necessary if the control circuit of the local circuit breaker is faulted (e.g. control voltage
failure or air pressure failure) since it is apparent that the circuit breaker is not capable of clearing the fault. If
the relay is informed about this disturbance (via the binary input
>CB faulty
, the adjacent circuit breakers
(busbar and remote end if applicable) are tripped after the time T3-BkrDefective (address 3907) which is
usually set to 0.
Address 3908 Trip BkrDefect. determines to which output the trip command is routed in the event that
the circuit breaker is not operational when a feeder protection trip occurs. Select that output which is used to
trip the adjacent circuit breakers (bus-bar trip).
End fault protection
The end fault protection can be switched in address 3921 End Flt. stage separately to ON- or OFF. An end
fault is a short-circuit between the circuit breaker and the current transformer set of the feeder. The end fault
protection presumes that the device is informed about the circuit breaker position via circuit breaker auxiliary
contacts connected to binary inputs.
If, during an end fault, the circuit breaker is tripped by a reverse stage of the feeder protection or by the
busbar protection (the fault is a busbar fault as determined from the location of the current transformers), the
fault current will continue to flow, because the fault is fed from the remote end of the feeder circuit.
The time T-EndFault (address 3922) is started when, during the time of pickup condition of the feeder
protection, the circuit breaker auxiliary contacts indicate open poles and, at the same time, current flow is still
detected (address 3902). The trip command of the end fault protection is intended for the transmission of an
intertrip signal to the remote end circuit breaker.
Thus, the delay time must be set so that it can bridge out short transient apparent end fault conditions which
may occur during switching of the circuit breaker.
Pole discrepancy supervision
In address 3931 PoleDiscrepancy (pole discrepancy protection), the pole discrepancy supervision can be
switched separately ON- or OFF. It is only useful if the circuit breaker poles can be operated individually. It
avoids that only one or two poles of the local circuit breaker are open continuously. It has to be provided that
either the auxiliary contacts of each pole or the series connection of the NO auxiliary contacts and the series
connection of the NC auxiliary contacts are connected to the device's binary inputs. If these conditions are not
fulfilled, switch address 3931 OFF.
The delay time T-PoleDiscrep. (address 3932) indicates how long a circuit breaker pole discrepancy condi-
tion of the feeder circuit breaker, i.e. only one or two poles open, may be present before the pole discrepancy
supervision issues a 3-pole trip command. This time must be clearly longer than the duration of a 1-pole auto-
matic reclose cycle. The time should be less than the permissible duration of an unbalanced load condition
which is caused by the unsymmetrical position of the circuit breaker poles. Standard durations are between 2 s
and 5 s.
Settings
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter C Setting Options Default Setting Comments
3901 FCT BreakerFail ON
OFF
ON Breaker Failure Protection
3902 I> BF 1A 0.05 .. 20.00 A 0.10 A Pick-up threshold I>
5A 0.25 .. 100.00 A 0.50 A
3903 1p-RETRIP (T1) NO
YES
YES 1pole retrip with stage T1
(local trip)
3904 T1-1pole 0.00 .. 30.00 sec; ∞ 0.00 sec T1, Delay after 1pole start
(local trip)
2.18.3
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Addr. Parameter C Setting Options Default Setting Comments
3905 T1-3pole 0.00 .. 30.00 sec; ∞ 0.00 sec T1, Delay after 3pole start
(local trip)
3906 T2 0.00 .. 30.00 sec; ∞ 0.15 sec T2, Delay of 2nd stage
(busbar trip)
3907 T3-BkrDefective 0.00 .. 30.00 sec; ∞ 0.00 sec T3, Delay for start with
defective bkr.
3908 Trip BkrDefect. NO
with T1-trip
with T2-trip
w/ T1/T2-trip
NO Trip output selection with
defective bkr
3909 Chk BRK CONTACT NO
YES
YES Check Breaker contacts
3912 3I0> BF 1A 0.05 .. 20.00 A 0.10 A Pick-up threshold 3I0>
5A 0.25 .. 100.00 A 0.50 A
3913 T2StartCriteria With exp. of T1
Parallel withT1
Parallel withT1 T2 Start Criteria
3921 End Flt. stage ON
OFF
OFF End fault protection
3922 T-EndFault 0.00 .. 30.00 sec; ∞ 2.00 sec Trip delay of end fault
protection
3931 PoleDiscrepancy ON
OFF
OFF Pole Discrepancy supervi-
sion
3932 T-PoleDiscrep. 0.00 .. 30.00 sec; ∞ 2.00 sec Trip delay with pole
discrepancy
Information List
No. Information Type of
Informa-
tion
Comments
1401 >BF on SP >BF: Switch on breaker fail protection
1402 >BF off SP >BF: Switch off breaker fail protection
1403 >BLOCK BkrFail SP >BLOCK Breaker failure
1404 >BFactivate3I0> SP >BF Activate 3I0> threshold
1415 >BF Start 3pole SP >BF: External start 3pole
1424 >BF STARTonlyT2 SP >BF: Start only delay time T2
1432 >BF release SP >BF: External release
1435 >BF Start L1 SP >BF: External start L1
1436 >BF Start L2 SP >BF: External start L2
1437 >BF Start L3 SP >BF: External start L3
1439 >BF Start w/o I SP >BF: External start 3pole (w/o current)
1440 BkrFailON/offBI IntSP Breaker failure prot. ON/OFF via BI
1451 BkrFail OFF OUT Breaker failure is switched OFF
1452 BkrFail BLOCK OUT Breaker failure is BLOCKED
1453 BkrFail ACTIVE OUT Breaker failure is ACTIVE
1461 BF Start OUT Breaker failure protection started
1472 BF T1-TRIP 1pL1 OUT BF Trip T1 (local trip) - only phase L1
1473 BF T1-TRIP 1pL2 OUT BF Trip T1 (local trip) - only phase L2
2.18.4
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No. Information Type of
Informa-
tion
Comments
1474 BF T1-TRIP 1pL3 OUT BF Trip T1 (local trip) - only phase L3
1476 BF T1-TRIP L123 OUT BF Trip T1 (local trip) - 3pole
1493 BF TRIP CBdefec OUT BF Trip in case of defective CB
1494 BF T2-TRIP(bus) OUT BF Trip T2 (busbar trip)
1495 BF EndFlt TRIP OUT BF Trip End fault stage
1496 BF CBdiscrSTART OUT BF Pole discrepancy pickup
1497 BF CBdiscr L1 OUT BF Pole discrepancy pickup L1
1498 BF CBdiscr L2 OUT BF Pole discrepancy pickup L2
1499 BF CBdiscr L3 OUT BF Pole discrepancy pickup L3
1500 BF CBdiscr TRIP OUT BF Pole discrepancy Trip
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2.18 Circuit breaker failure protection (optional)
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Monitoring Functions
The device is equipped with extensive monitoring capabilities - concerning both, hardware and software. In
addition, the measured values are also constantly checked for plausibility, so that the current and voltage
transformer circuits are largely integrated into the monitoring. It is also possible to implement trip circuit
supervision. This supervision is possible using appropriate available binary inputs.
Measurement Supervision
Hardware Monitoring
The device is monitored from the measuring inputs up to the command relays. Monitoring circuits and the
processor check the hardware for malfunctions and inadmissible conditions.
Auxiliary and Reference Voltages
The processor voltage of 5 V is monitored by the hardware, as the processor no longer functions on under-
shooting the minimum value. In that case, the device is not operational. On recovery of the voltage the
processor system is restarted.
If the supply voltage is removed or switched off, the device is taken out of service, and an indication is imme-
diately generated by a normally closed contact. Brief voltage interruptions of up to 50 ms do not disturb the
operational readiness of the device (see Technical Data).
The processor monitors the reference voltage of the ADC (analog-to-digital converter). The protection is
suspended if the voltages deviate outside an allowable range, and persistent deviations are reported.
Buffer battery
The buffer battery, which ensures the operation of the internal clock and the storage of counters and indica-
tions if the auxiliary voltage fails, is periodically checked for charge status. On its undershooting a minimum
admissible voltage, the indication
Fail Battery
(no.177) is issued.
If the device is not supplied with auxiliary voltage for more than 1 or 2 days, the internal clock is switched off
automatically, i.e. the time is not registered any more. The data in the event and fault buffers, however,
remain stored.
Memory Components
The main memory (RAM) is tested when the system starts up. If a fault is detected during this process, the
startup is aborted. Error LED and LED 1 light up and the remaining LEDs start flashing simultaneously. During
operation the memory is checked by means of its checksum.
A checksum of the program memory (EPROM) is cyclically generated and compared with the stored program
checksum.
A checksum for the parameter memory (FLASH-EPROM) is cyclically generated and compared with the
checksum which is computed after each change of the stored parameters.
If a malfunction occurs, the processor system is restarted.
Offset of the Analogue-to-Digital Converter
The offset of the ADC is measured cyclically for each channel and corrected. When the offset reaches an inad-
missibly high value, the indication
Error Offset
(No. 191) is displayed. The protection functions remain
active.
Sampling frequency
The sampling frequency and the synchronism of the analog-digital converters is continuously monitored. If
any deviations cannot be removed by remedied synchronization, then the processor system is restarted.
2.19
2.19.1
2.19.1.1
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Measured Value Acquisition - Currents
Up to four input currents are measured by the device. If the three phase currents and the earth current from
the current transformer starpoint or a separated earth current transformer of the line to be protected are
connected to the device, their digitized sum must be zero. Faults in the current circuit are recognized if
ΙF = |ΙL1 + ΙL2 + ΙL3 + kΙ·ΙE| > ΣI THRESHOLD + ΣI FACTOR·Σ | Ι |
Factor kΙ (address 221 I4/Iph CT) takes into account a possible different ratio of a separate ΙE transformer
(e.g. cable core balance current transformer). ΣI THRESHOLD and ΣI FACTOR. are setting parameters.
The ΣI FACTOR Σ | Ι | part takes into account permissible current-proportional transformation errors of the
transformer, which can occur in the case of high short-circuit currents.Figure 2-153). Σ | Ι | is the sum of all
currents:
Σ | Ι | = |ΙL1| + |ΙL2| + |ΙL3| + |kΙ·ΙE|
This fault is signaled as
Failure Σ I
(no. 162).
i
i
NOTE
Current sum monitoring can operate properly only when the residual current of the protected line is fed to
the fourth current input (Ι4) of the relay.
[stromsummenueberwachung-020313-kn, 1, en_GB]
Figure 2-153 Current sum monitoring
Measured Value Acquisition Voltages
Four measuring inputs are available in the voltage path: three for phase-to-earth voltages and one input for
the displacement voltage (e-n voltage of open delta winding) or a busbar voltage. If the displacement voltage
is connected to the device, the sum of the three digitized phase voltages must equal three times the zero
sequence voltage. Errors in the voltage transformer circuits are detected when
UF = |UL1 + UL2 + UL3 + kU·UEN| > 25 V.
The factor kU allows for a difference of the transformation ratio between the displacement voltage input and
the phase voltage inputs (address 211 Uph / Udelta).
This fault is signaled as
Fail Σ U Ph-E
(no. 165).
i
i
NOTE
Voltage sum monitoring is only effective if an external displacement voltage is connected to the displace-
ment voltage measuring input.
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Software Monitoring
Watchdog
For continuous monitoring of the program sequences, a time monitor is provided in the hardware (watchdog
for hardware) that expires upon failure of the processor or an internal program, and causes a reset of the
processor system with complete restart.
An additional software watchdog ensures that malfunctions during the processing of programs are discov-
ered. This also initiates a restart of the processor system.
If the fault is not eliminated by the restart, a second restart attempt is initiated. If the fault is still present after
three restart attempts within 30 s, the protection system will take itself out of service, and the red LED
“ERROR” lights up. The device ready relay drops out and alarms the device malfunction with its normally closed
contact(“Life-Contact”).
Monitoring External Transformer Circuits
Interruptions or short circuits in the secondary circuits of the current and voltage transformers, as well as
faults in the connections (important for commissioning!), are detected and reported by the device. To this
end, the measured values are cyclically checked in the background as long as no fault detection is present.
Current Symmetry
During normal system operation the currents are assumed to be largely symmetrical. The symmetry is moni-
tored in the device by magnitude comparison. The smallest phase current is compared to the largest phase
current. Asymmetry is recognized if:
|Ιmin| / |Ιmax| < BAL. FACTOR I as long as Ιmax > BALANCE I LIMIT
Ιmax is the highest, Ιmin the lowest of the three phase currents. The symmetry factor BAL. FACTOR I
(address 2905) represents the allowable asymmetry of the phase currents while the limit value BALANCE I
LIMIT (address 2904) is the lower limit of the operating range of this monitoring (see Figure 2-154). The
dropout ratio is about 97 %.
After a settable time (5 s -100 s), this malfunction is signaled as
Fail I balance
(No. 163).
[stromsymmetrieueberwachung-020313-kn, 1, en_GB]
Figure 2-154 Current symmetry monitoring
Broken Conductor
A broken wire of the protected line or in the current transformer secondary circuit can be detected, if the
minimum current PoleOpenCurrent flows via the feeder. If the minimum phase current is below this limit
while the other phase currents are above this limit, an interruption of this conductor may be assumed. If
2.19.1.2
2.19.1.3
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current asymmetry is also detected (see margin heading “Current Symmetry”), the device issues the message
Fail Conductor
(No. 195).
Voltage Symmetry
During normal system operation the voltages are assumed to be largely symmetrical. The symmetry is moni-
tored in the device by magnitude comparison. The smallest phase voltage is compared to the largest. Asym-
metry is recognized if:
|Umin| / |Umax| < BAL. FACTOR U as long as |Umax| > BALANCE U-LIMIT
Thereby Umax is the largest of the three phase-to-phase voltages and Umin the smallest. The symmetry factor
BAL. FACTOR U (address 2903) represents the allowable asymmetry of the voltages while the limit value
BALANCE U-LIMIT (address 2902) is the lower limit of the operating range of this monitoring (see
Figure 2-155). The dropout ratio is about 97 %.
After a settable time, this malfunction is signaled as
Fail U balance
(no.167).
[spannungssymmetrieueberwachung-020313-kn, 1, en_GB]
Figure 2-155 Voltage symmetry monitoring
Voltage Phase Sequence
Verification of the faulted phases, phase preference, direction measurement and polarization with quadrature
voltages usually require clockwise rotation of the measured values. The phase rotation of the measuring
voltages is checked by control of the phase sequence of the voltages
UL1 before UL2 before UL3
. This check takes place if each measured voltage has a minimum magnitude of
|UL1|, |UL2|, |UL3| > 40 V/√3
. In case of negative phase rotation, the indication
Fail Ph. Seq.
(No. 171) is displayed.
If the system has a negative phase rotation, this must have been set during the configuration of the power
system data (Section 2.1.2.1 Setting Notes, address235). In such event, the phase rotation monitoring applies
to the corresponding opposite phase sequence.
Fast Asymmetrical Measuring Voltage Failure "Fuse Failure Monitor"
In the event of a measured voltage failure due to a short circuit fault or a broken conductor in the voltage
transformer secondary circuit certain measuring loops may mistakenly see a voltage of zero. Simultaneously
existing load currents may then cause a spurious pickup.
If fuses are used instead of a voltage transformer miniature circuit breaker (VT mcb) with connected auxiliary
contacts, then the “Fuse-Failure-Monitor” can detect problems in the voltage transformer secondary circuit. Of
course, the VT miniature circuit breaker and the “Fuse-Failure-Monitor” can be used at the same time.
Figure 2-156 and Figure 2-157 show the logic diagram of the “Fuse-Failure-Monitors”.
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[lo-ffm-mcl-01-20101014, 1, en_GB]
Figure 2-156 Fuse failure monitoring Part 1: Detection of asymmetrical measuring voltage failure
The asymmetrical measured voltage failure is characterised by its voltage asymmetry with simultaneous
current symmetry. If there is substantial voltage asymmetry of the measured values, without asymmetry of
the currents being registered at the same time, this indicates the presence of an asymmetrical failure in the
voltage transformer secondary circuit.
The asymmetry of the voltage is detected by the fact that either the zero sequence voltage or the negative
sequence voltage exceed a settable value FFM U>(min) (address 2911). The current is assumed to be suffi-
ciently symmetrical if both the zero sequence as well as the negative sequence current are below the settable
threshold FFM I< (max) (address 2912).
In non-earthed systems (address 207 SystemStarpoint), the zero-sequence system quantities are no reli-
able criterion since a considerable zero sequence voltage occurs also in case of a simple earth fault where a
significant zero sequence current does not necessarily flow. Therefore, the zero sequence voltage is not evalu-
ated in these systems but only the negative sequence voltage and the ratio between negative sequence and
positive sequence voltage.
The immediate effect of the “Fuse-Failure-Monitors” is signaled by means of the indication
VT FuseFail
(No.
170). To detect an asymmetrical measuring voltage failure, at least one phase current must exceed the value
FFM I< (max) (address 2912).
In case that zero sequence or negative sequence current arise within 10 s after detecting an asymmetrical
measuring voltage failure, a short-circuit in the network is assumed and the signal
VT FuseFail
is immedi-
ately reset. If the zero-sequence voltage or the negative-sequence voltage exceed the presettable value FFM
U>(min) (address 2911) for more than 10 s, the signal
VT FuseFail>10s
(No. 169) will be generated. In
this status, a reset of the signal
VT FuseFail
will no longer be effected by means of an increase of the zero-
sequence current or the negative-sequence current, but only through the fact that the voltages in the zerose-
quence system and in the negative-sequence system fall below the threshold value. The signal
VT FuseFail
can also be generated independently from the quantity of the phase currents.
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During a single-pole automatic reclose dead time, the “Fuse-Failure-Monitor” does not detect an asymmetrical
measuring voltage failure. Due to the de-energization in one phase, an operational asymmetry is caused on
the primary side which cannot be distinguished from a measuring voltage failure in the secondary circuit (not
represented in the logic diagram).
[lo_7sa6-ffm-mcl-02, 1, en_GB]
Figure 2-157 Fuse failure monitoring Part 2: Detection of three-phase measuring voltage failure
A 3-phase failure of the secondary measured voltages can be distinguished from an actual system fault by
the fact that the currents have no significant change in the event of a failure in the secondary measured
voltage. For this reason, the current values are routed to a buffer so that the difference between present and
stored current values can be analysed to recognise the magnitude of the current differential (current differen-
tial criterion), see Figure 2-157.
A three-pole measuring voltage failure is detected if:
•All 3 phase-to-earth voltages are smaller than the threshold FFM U<max (3ph) (address 2913).
•The current differential in all 3 phases is smaller than the threshold FFM Idelta (3p) (address 2914).
•In minimum 1 phase current amplitudes is larger than the minimum current Iph> (Adresse 1202) ffor
impedance measurement of the distance protection.
A three-pole measuring voltage failure is also detected without the mentioned criteria if the signal
VT Fuse-
Fail
(No. 170) previously has been generated by an asymmetrical measuring voltage failure. The measuring
voltage failure is still detected in this state if the three phase-to-earth voltages subsequently fall below the
threshold value FFM U<max (3ph) (address 2913 ).
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The effect of the signals
VT FuseFail
(No. 170) and
VT FuseFail>10s
(No. 169) on the protection func-
tions is described in the following section “Effect of the measuring voltage failure”.
Additional Measured Voltage Failure Monitoring
If no measuring voltage is available after power-on of the circuit breaker (e.g. because the voltage trans-
formers are not connected), the absence of the voltage can be detected and reported by an additional moni-
toring function. Where circuit breaker auxiliary contacts are used, they should be used for monitoring as well.
Figure 2-158 shows the logic diagram of the measured voltage failure monitoring. A failure of the measured
voltage is detected if the following conditions are met at the same time:
•All 3 phase-to-earth voltages are less than FFM U<max (3ph)
•At least 1 phase current is larger than PoleOpenCurrent or at least 1 breaker pole is closed (can be
set), • No protection function has picked up,
•es liegt keine Anregung einer Schutzfunktion vor
•This condition persists for a settable time T V-Supervision (default setting: 3 s).
The time T V-Supervision is required to prevent that a voltage failure is detected before the protection
picks up.
If this monitoring function picks up, the indication
Fail U absent
(No. 168) will be issued. The effect of
this monitoring indication will be described in the following section “Effect of the Measuring Voltage Failure”.
[logikdia-zusaetzl-messspgausfall-wlk-010802, 1, en_GB]
Figure 2-158 Logic diagram of the additional measured voltage failure monitoring
Fail U absent
Effect of the Measuring Voltage Failure
In the event of a measuring voltage failure due to a short-circuit or broken conductor in the voltage trans-
former secondary circuit, some or all measuring loops may mistakenly see a voltage of zero. In case that load
currents exist simultaneously, incorrect pickup could occur. If such a voltage failure is detected, the protection
functions that operate on the basis of undervoltage are blocked.
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The O/C emergency operation is possible during the voltage failure, provided that the O/C protection is para-
meterized accordingly (refer to Section 2.11 Overcurrent protection (optional) ).
The following figure shows the effect on the protection functions in case that a measuring voltage is detected
by the “Fuse-Failure-Monitor”“
VT FuseFail
(No. 170),
VT FuseFail>10s
(No. 169), the additional
measuring voltage failure monitoring
Fail U absent
(No. 168) and the binary input of the VT miniature
circuit breaker
>FAIL:Feeder VT
(No. 361).
[lo-ffm-mcl-20101014, 1, en_GB]
Figure 2-159 Effect of the measuring voltage failure
Monitoring the Phase Angle of the Positive Sequence Power
This monitoring function allows determining the direction of power flow. You can monitor the phase angle of
the complex power, and generate an indication when the power phasor is inside a settable segment.
One example of this application is the indication of capacitive reactive power. The monitoring indication can
then be used to control the overvoltage protection function. For this purpose, two angles must be set, as
shown in Figure 2-160 . In this example, φA = 200° und φB = 340° have been set.
If the measured phase angle φ(S1) of the positive sequence power is innerhalb the area of the P-Q plane
delimited by the angles φA and φB, the indication
φ(PQ Pos. Seq.)
(No. 130) is output. The angles φA and
φB can be freely set in the range between 0° and 359°. The area starts at φA and extends in a mathematically
positive sense as far as the angle φB. A hysteresis of 2° is provided to prevent erroneous indications which
might emerge at the threshold limits.
2.19.1.4
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[blindleistung-ind-kap-wlk040602, 1, en_GB]
Figure 2-160 Characteristic of the Positive Sequence System Phase Angle Monitoring
The monitoring function can also be used for the display of negative active power. In this case the areas must
be defined as shown in Figure 2-161 .
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[wirkleistung-ind-kap--wlk040602, 1, en_GB]
Figure 2-161 Phase Angle Monitoring for Negative Active Power
The two angles must be at least 3° apart; if they are not, monitoring is blocked, and the indication
φ Set
wrong
(No. 132 is output.
The following conditions must be fulfilled for measurement to be enabled:
•The positive sequence current Ι1is higher than the value set in parameter 2943 I1>.
•The positive sequence voltage U1 is higher than the value set in parameter 2944 U1>.
•The angles set in address 2941 φA and 2942 φB must be at least 3° apart. Incorrect parameter settings
cause the indication 132
φ Set wrong
to be output.
•The “Fuse-Failure-Monitor” and the measured voltage failure monitoring must not have responded, and
binary input indication 361
>FAIL:Feeder VT
must not be present.
If monitoring is not active, this fact is signaled by the indication
φ(PQ Pos) block
(No. 131).
Figure 2-162 shows the logic of the positive sequence system phase angle monitoring.
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[logikphasenwinkelueberwachung-wlk-040514, 1, en_GB]
Figure 2-162 Logic of the Positive Sequence System Phase Angle Monitoring
Malfunction Reaction
Depending on the kind of fault detected, an alarm is given, the processor is restarted or the device is taken out
of operation. After three unsuccessful restart attempts, the device is taken out of service. The device ready
relay drops out and indicates the device failure with its NC contact (“life contact”). The red LED “ERROR” on the
device front lights up, provided that there is an internal auxiliary voltage, and the green LED “RUN” goes off. If
the internal auxiliary voltage supply fails, all LEDs are dark. Table 2-19 shows a summary of the monitoring
functions and the malfunction responses of the device.
Table 2-9 Summary of malfunction responses of the device
Monitoring Possible Causes Malfunction Response Indication (No.) Output
Auxiliary Supply
Voltage Loss
External (aux. voltage)
internal (converter)
Device out of operation or
alarm
All LEDs dark
Error 5V
(144)
DOK2) drops
Measured Value Acquis-
ition
Internal (converter or refer-
ence voltage)
Protection out of opera-
tion, alarm
LED “ERROR”
Error A/D-conv.
(181)
DOK2) drops
Buffer battery Internal (battery) Indication
Fail Battery
(177)
as allocated
Hardware Watchdog Internal (processor failure) Device not in operation LED “ERROR” DOK2) drops
Software-Watchdog Internal (program
sequence)
Restart attempt 1) LED “ERROR” DOK2) drops
RAM Internal (RAM) Restart attempt 1), Restart
abort
Device not in operation
LED flashes DOK2) drops
ROM Internal (EPROM) Restart attempt 1) LED “ERROR” DOK2) drops
Settings memory Internal (Flash-EPROM or
RAM)
Restart attempt 1) LED “ERROR” life contact2)
drops
Scanning frequency Internal ((clock generator) Restart attempt 1) LED “ERROR” DOK2) drops
2.19.1.5
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Monitoring Possible Causes Malfunction Response Indication (No.) Output
1 A/5 A setting 1/5 A jumper wrong Messages:
Protection out of opera-
tion
Error1A/5Awrong
(192)
Error A/D-
conv.
(181)
LED “ERROR”
DOK2) drops
Adjustment values Internal (EEPROM or RAM) Indication:
Use of
default values
Alarm adjustm.
(193)
as allocated
ADC offse Internal (ADC) Indication
Error Offset
(191)
as allocated
Earth current trans-
former sensitive/insen-
sitive
I/O module does not corre-
spond to the order number
(MLFB) of the device.
Indications:
Protection out of opera-
tion
Error neutralCT
(194),
Error A/D-
conv.
(181)
LED “ERROR”
DOK2) drops
Modules Module does not comply
with ordering number
(MLFB).
Indications:
Protection out of opera-
tion
“Error Board BG1...7”
(183 ... 189)
and if applicable
Error A/D-conv.
.
(181)
DOK2) drops
Current sum Internal (measured value
acquisition)
Indication
Failure Σ I
(162) as allocated
Current symmetry External (power system or
current transformer)
Indication
Fail I balance
(163)
as allocated
Broken Conductor External (power system or
current transformer)
Indication
Fail Conductor
(195)
as allocated
Voltage sum Internal (measured value
acquisition)
Indication
Fail Σ U Ph-E
(165)
as allocated
Voltage symmetry External (power system or
voltage transformer)
Indication
Fail U balance
(167)
as allocated
Voltage phase
sequence
External (power system or
connection)
Indication
Fail Ph. Seq.
(171)
as allocated
Voltage failure, 3-
phase“Fuse-Failure-
Monitor”
External (power system or
connection)
Indication
Distance protection is
blocked,
Undervoltage protection is
blocked,
Weak-infeed tripping is
blocked,
Frequency protection is
blocked, and
Direction determination of
the earth fault protection
is blocked
VT FuseFail>10s
(169),
VT FuseFail
(170)
as allocated
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Monitoring Possible Causes Malfunction Response Indication (No.) Output
Voltage failure, 1-/2-
phase“Fuse-Failure-
Monitor”
External (voltage trans-
formers)
Indication
Distance protection is
blocked,
Undervoltage protection is
blocked,
Weak-infeed tripping is
blocked,
Frequency protection is
blocked, and
Direction determination of
the earth fault protection
is blocked
VT FuseFail>10s
(169),
VT FuseFail
(170)
as allocated
Voltage failure, 3-phase External (power system or
connection)
Indication
Distance protection is
blocked,
Undervoltage protection is
blocked,
Weak-infeed tripping is
blocked,
Frequency protection is
blocked, and
Direction determination of
the earth fault protection
is blocked
Fail U absent
(168)
as allocated
Trip Circuit Monitoring External (trip circuit or
control voltage)
Indication
FAIL: Trip cir.
(6865)
as allocated
1) after three unsuccessful restarts, the device is taken out of service.
2) DOK = “Devive OK” = NC contact of the operational readiness relay = life contact
Setting Notes
General
The sensitivity of the measured value monitoring can be changed. Experiential values set ex works are
adequate in most cases. If particularly high operational asymmetries of the currents and/or voltages are
expected, or if one or more monitoring functions pick up sporadically during normal operation, the sensitivity
settings should be made less sensitive..
At address 2901 MEASURE. SUPERV measurement supervision can be switched ON or OFF.
Symmetry monitoring
Address2902 BALANCE U-LIMIT determines the limit voltage (phase-to-phase), above which the voltage
symmetry monitoring is effective. Address 2903 BAL. FACTOR U is the associated balance factor, i.e. the
gradient of the balance characteristic. The indication
Fail U balance
(No 167) can be delayed under
address 2908 T BAL. U LIMIT. These settings can only be changed via DIGSI at Display Additional
Settings.
Address2904 BALANCE I LIMIT determines the limit current above which the current symmetry monitoring
is effective. Address 2905 BAL. FACTOR I is the associated balance factor, i.e. the gradient of the balance
characteristic. The indication
Fail I balance
(No 163) can be delayed under address 2909 T BAL. I
LIMIT. These settings can only be changed via DIGSI at Display Additional Settings.
Sum Monitoring
Address 2906 ΣI THRESHOLD determines the limit current above which the current sum monitoring is acti-
vated (absolute portion, only relative to ΙN). The relative portion (relative to the maximum phase current) for
2.19.1.6
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activating the current sum monitoring is set at 2907 ΣI FACTOR. These settings can only be changed via
DIGSI at Display Additional Settings.
i
i
NOTE
Current sum monitoring can operate properly only when the residual current of the protected line is fed to
the fourth current input (Ι4) of the relay.
Asymmetrical measuring voltage failure "Fuse Failure Monitor"
The settings for the “fuse failure monitor” for non-symmetrical measuring voltage failure must be selected
such that on the one hand it is reliably activated if a phase voltage fails (address 2911 FFM U>(min)), but
does not pick up on earth faults in an earthed network on the other hand. Accordingly, address 2912 FFM I<
(max) (max) must be set sufficiently sensitive (below the smallest fault current during earth faults). These
settings can only be changed via DIGSI at Display Additional Settings.
In address 2910 FUSE FAIL MON. the “Fuse-Failure-Monitor”, e.g. during asymmetrical testing, can be
switched OFF.
Three-phase measuring voltage failure „Fuse-Failure-Monitor“
In address 2913 FFM U<max (3ph) the minimum voltage threshold is set. If the measured voltage drops
below this threshold and a simultaneous current jump which exceeds the limits according to address 2914
FFM Idelta (3p) is not detected while all three phase currents are greater than the minimum current
required for the impedance measurement by the distance protection according to address 1202 Minimum
Iph>, a threephase measured voltage failure is recognized. These settings can only be changed via DIGSI at
Display Additional Settings.
In address 2910 FUSE FAIL MON., the „Fuse Failure Monitor“, e.g. during asymmetrical testing, can be
switched OFF.
Measured voltage failure monitoring
The measured voltage failure monitoring can be switched under address 2915 V-Supervision w/
CURR.SUP, w/ I> & CBaux or OFF. Address 2916 T V-Supervision is used to set the waiting time of the
voltage failure supervision. This setting can only be changed in DIGSI at Display Additional Settings.
Circuit breaker for voltage transformers
If a circuit breaker for voltage transformers (VT mcb) is installed in the secondary circuit of the voltage trans-
formers, the status is sent, via binary input, to the device informing it about the position of the VT mcb. If a
shortcircuit in the secondary side initiates the tripping of the VT mcb, the distance protection function has to
be blocked immediately, since otherwise it would be spuriously tripped due to the lacking measured voltage
during a load current. The blocking must be faster than the first stage of the distance protection.This requires
an extremely short reaction time for VT mcb (≤ 4 ms at 50 Hz, ≤ 3 ms at 60 Hz nominal frequency). If this
cannot be ensured, the reaction time is to be set under address 2921 T mcb.
Monitoring the phase angle of the positive sequence power
The parameters 2943 I1> and 2944 U1> are used to specify the minimum positive sequence system quanti-
ties required for measurement of the positive sequence power. The angles set in address 2941 φA and 2942
φB must be at least 3° apart. Incorrect parameter settings cause the indication 132
φ Set wrong
to be
output.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
2.19.1.7
Functions
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Addr. Parameter C Setting Options Default Setting Comments
2901 MEASURE. SUPERV ON
OFF
ON Measurement Supervision
2902A BALANCE U-LIMIT 10 .. 100 V 50 V Voltage Threshold for
Balance Monitoring
2903A BAL. FACTOR U 0.58 .. 0.95 0.75 Balance Factor for Voltage
Monitor
2904A BALANCE I LIMIT 1A 0.10 .. 1.00 A 0.50 A Current Balance Monitor
5A 0.50 .. 5.00 A 2.50 A
2905A BAL. FACTOR I 0.10 .. 0.95 0.50 Balance Factor for Current
Monitor
2906A ΣI THRESHOLD 1A 0.05 .. 2.00 A 0.10 A Summated Current Moni-
toring Threshold
5A 0.25 .. 10.00 A 0.50 A
2907A ΣI FACTOR 0.00 .. 0.95 0.10 Summated Current Moni-
toring Factor
2908A T BAL. U LIMIT 5 .. 100 sec 5 sec T Balance Factor for
Voltage Monitor
2909A T BAL. I LIMIT 5 .. 100 sec 5 sec T Current Balance Monitor
2910 FUSE FAIL MON. ON
OFF
ON Fuse Failure Monitor
2911A FFM U>(min) 10 .. 100 V 30 V Minimum Voltage
Threshold U>
2912A FFM I< (max) 1A 0.05 .. 1.00 A 0.10 A Maximum Current
Threshold I<
5A 0.25 .. 5.00 A 0.50 A
2913A FFM U<max (3ph) 2 .. 100 V 15 V Maximum Voltage
Threshold U< (3phase)
2914A FFM Idelta (3p) 1A 0.05 .. 1.00 A 0.10 A Delta Current Threshold
(3phase)
5A 0.25 .. 5.00 A 0.50 A
2915 V-Supervision w/ CURR.SUP
w/ I> & CBaux
OFF
w/ CURR.SUP Voltage Failure Supervision
2916A T V-Supervision 0.00 .. 30.00 sec 3.00 sec Delay Voltage Failure
Supervision
2921 T mcb 0 .. 30 ms 0 ms VT mcb operating time
2941 φA 0 .. 359 ° 200 ° Limit setting PhiA
2942 φB 0 .. 359 ° 340 ° Limit setting PhiB
2943 I1> 1A 0.05 .. 2.00 A 0.05 A Minimum value I1>
5A 0.25 .. 10.00 A 0.25 A
2944 U1> 2 .. 70 V 20 V Minimum value U1>
Information List
No. Information Type of
Informa-
tion
Comments
130 φ(PQ Pos. Seq.) OUT Load angle Phi(PQ Positive sequence)
131 φ(PQ Pos) block OUT Load angle Phi(PQ) blocked
132 φ Set wrong OUT Setting error: |PhiA - PhiB| < 3°
161 Fail I Superv. OUT Failure: General Current Supervision
162 Failure Σ I OUT Failure: Current Summation
163 Fail I balance OUT Failure: Current Balance
2.19.1.8
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No. Information Type of
Informa-
tion
Comments
164 Fail U Superv. OUT Failure: General Voltage Supervision
165 Fail Σ U Ph-E OUT Failure: Voltage summation Phase-Earth
167 Fail U balance OUT Failure: Voltage Balance
168 Fail U absent OUT Failure: Voltage absent
169 VT FuseFail>10s OUT VT Fuse Failure (alarm >10s)
170 VT FuseFail OUT VT Fuse Failure (alarm instantaneous)
171 Fail Ph. Seq. OUT Failure: Phase Sequence
195 Fail Conductor OUT Failure: Broken Conductor
196 Fuse Fail M.OFF OUT Fuse Fail Monitor is switched OFF
197 MeasSup OFF OUT Measurement Supervision is switched OFF
Trip circuit supervision
Functional Description
Trip Circuit Supervision
The 7SA522 incorporates an integrated trip circuit supervision function. Depending on the number of avail-
able binary inputs (not connected to a common potential), supervision with one or two binary inputs can be
selected. If the routing of the required binary inputs does not comply with the selected supervision mode, an
alarm is issued (“TripC ProgFAIL”) with identification of the non-compliant circuit. When using two binary
inputs, malfunctions in the trip circuit can be detected under all circuit breaker conditions. When only one
binary input is used, malfunctions in the circuit breaker itself cannot be detected. If single-pole tripping is
possible, a separate trip circuit supervision can be implemented for each circuit breaker pole provided the
required binary inputs are available.
Supervision with Two Binary Inputs
When using two binary inputs, these are connected according to Figure 2-163 parallel to the associated trip
contact on one side, and parallel to the circuit breaker auxiliary contacts on the other.
A precondition for the use of the trip circuit supervision is that the control voltage for the circuit breaker is
higher than the total of the minimum voltages drops at the two binary inputs (UCtrl > 2·UBImin). Since at least 19
V are needed for each binary input, the supervision function can only be used with a system control voltage of
over 38 V.
2.19.2
2.19.2.1
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[prinzip-ausloesekrueb-2-be-wlk-010802, 1, en_GB]
Figure 2-163 Principle of the trip circuit supervision with two binary inputs
TR Trip relay contact
CB Circuit breaker
TC Circuit breaker trip coil
Aux1 Circuit breaker auxiliary contact (NO contact)
Aux2 Circuit breaker auxiliary contact (NC contact)
U-CTR Control voltage (trip voltage)
U-BI1 Input voltage of 1st binary input
U-BI2 Input voltage of 2nd binary input
Supervision with two binary inputs not only detects interruptions in the trip circuit and loss of control voltage,
it also supervises the response of the circuit breaker using the position of the circuit breaker auxiliary contacts.
Depending on the conditions of the trip contact and the circuit breaker, the binary inputs are activated (logical
condition “H” in the following table), or short-circuited (logical condition “L”).
A state in which both binary inputs are not activated (“L”) is only possible in intact trip circuits for a short tran-
sition period (trip relay contact closed but circuit breaker not yet open).
A continuous state of this condition is only possible when the trip circuit has been interrupted, a short-circuit
exists in the trip circuit, a loss of battery voltage occurs, or malfunctions occur with the circuit breaker mecha-
nism. Therefore, it is used as supervision criterion.
Table 2-10 Condition table for binary inputs, depending on RTC and CB position
No
.
Trip Contact Circuit Breaker Aux 1 Aux 2 BI 1 BI 2 Dynamic State Static State
1 open ON closed open H L Normal operation with circuit
breaker closed
2 open OFF open closed H H Normal operation with circuit
breaker open
3 closed ON closed open L L Transition or
malfunction
Malfunction
4 closed OFF open closed L H TR has tripped successfully
The conditions of the two binary inputs are checked periodically. A query takes place about every 500 ms. If
three consecutive conditional checks detect an abnormality, a fault indication is output (see Figure 2-164).
The repeated measurements determine the delay of the alarm message and avoid that an alarm is output
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during short transition periods. After clearance of the failure in the trip circuit, the failure alarm automatically
resets with the same time delay.
[logikdiagramm-auskruebrwchg-2-be-wlk-310702, 1, en_GB]
Figure 2-164 Logic diagram of the trip circuit supervision with two binary inputs
Supervision with One Binary Input
According to Figure 2-165, the binary input is connected in parallel to the respective command relay contact
of the protection device. The circuit breaker auxiliary contact is bridged with a high-resistance bypass resistor
R.
The control voltage for the circuit breaker should be at least twice as high as the minimum voltage drop at the
binary input (UCtrl > 2·UBImin). Since at least 19 V are needed for the binary input, the monitor can be used with
a system control voltage of over 38 V.
A calculation example for the bypass resistor R is shown in the configuration notes in Section “Mounting and
Connections”, margin heading “Trip Circuit Supervision”.
[prinzip-ausloesekrueb-1-be-wlk-010802, 1, en_GB]
Figure 2-165 Principle of the trip circuit supervision with one binary input
TR Trip relay contact
CB Circuit breaker
TC Circuit breaker trip coil
Aux1 Circuit breaker auxiliary contact (NO contact)
Aux2 Circuit breaker auxiliary contact (NC contact)
U-CTR Control voltage for trip circuit
U-BI Input voltage of binary input
R Bypass resistor
UR Voltage across the bypass resistor
During normal operation, the binary input is activated (logical condition “H”) when the trip contact is open and
the trip circuit is intact, because the supervision circuit is closed either by the circuit breaker auxiliary contact
(if the circuit breaker is closed) or through the bypass resistor R. Only as long as the trip contact is closed, the
binary input is short-circuited and thereby deactivated (logical condition “L”).
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If the binary input is permanently deactivated during operation, an interruption in the trip circuit or a failure of
the (trip) control voltage can be assumed.
The trip circuit supervision does not operate during system faults. A momentary closed tripping contact does
not lead to a fault indication. If, however, other trip relay contacts from different devices are connected in
parallel in the trip circuit, the fault indication must be delayed by Alarm Delay (see also Figure 2-166). After
clearance of the failure in the trip circuit, the fault message automatically resets with the same time delay.
[logikdiagramm-auskruebrwchg-1-be-wlk-310702, 1, en_GB]
Figure 2-166 Logic diagram for trip circuit supervision with one binary input
Setting Notes
General
The number of circuits to be supervised was set during the configuration in address 140 Trip Cir. Sup.
(Section 2.1.1.2 Setting Notes). If the trip circuit supervision is not used at all, the setting Disabled must be
applied there.
The trip circuit supervision can be switched in address 4001 FCT TripSuperv. ON- or OFF. The number of
binary inputs that shall be used in each of the supervised circuits is set in address 4002 No. of BI. If the
routing of the required binary inputs does not comply with the selected monitoring mode, an alarm is issued
(
TripC ProgFAIL...
with identification of the non-compliant circuit).
Supervision with one binary input
The alarm for supervision with two binary inputs is always delayed by approx. 1s to 2s, whereas the delay time
of the alarm for supervision with one binary input can be set in address 4003 Alarm Delay. If only the
device 7SA522 is connected to the trip circuits 1 s to 2 s are sufficient, as the trip circuit supervision does not
operate during a system fault. If, however, trip contacts from other devices are connected in parallel in the trip
circuit, the alarm must be delayed such that the longest trip command duration can be reliably bridged.
Settings
Addr. Parameter Setting Options Default Setting Comments
4001 FCT TripSuperv. ON
OFF
OFF TRIP Circuit Supervision is
4002 No. of BI 1 .. 2 2 Number of Binary Inputs per trip
circuit
4003 Alarm Delay 1 .. 30 sec 2 sec Delay Time for alarm
Information List
No. Information Type of
Informa-
tion
Comments
6854 >TripC1 TripRel SP >Trip circuit superv. 1: Trip Relay
6855 >TripC1 Bkr.Rel SP >Trip circuit superv. 1: Breaker Relay
6856 >TripC2 TripRel SP >Trip circuit superv. 2: Trip Relay
6857 >TripC2 Bkr.Rel SP >Trip circuit superv. 2: Breaker Relay
6858 >TripC3 TripRel SP >Trip circuit superv. 3: Trip Relay
6859 >TripC3 Bkr.Rel SP >Trip circuit superv. 3: Breaker Relay
6861 TripC OFF OUT Trip circuit supervision OFF
2.19.2.2
2.19.2.3
2.19.2.4
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No. Information Type of
Informa-
tion
Comments
6865 FAIL: Trip cir. OUT Failure Trip Circuit
6866 TripC1 ProgFAIL OUT TripC1 blocked: Binary input is not set
6867 TripC2 ProgFAIL OUT TripC2 blocked: Binary input is not set
6868 TripC3 ProgFAIL OUT TripC3 blocked: Binary input is not set
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Function Control and Circuit Breaker Test
Function Control
The function control is the control centre of the device. It coordinates the sequence of the protection and
ancillary functions, processes their decisions and the information coming from the power system.
Applications
•Line energization recognition,
•Processing of the circuit breaker position,
•Open Pole Detector,
•Fault detection logic,
•Tripping logic.
Line Energization Recognition
During energization of the protected object, several measures may be required or desirable. Following a
manual closure onto a short-circuit, immediate trip of the circuit breaker is usually desired. In the distance
protection, for example, this is implemented by activation of the overreaching zone Z1B and the switch onto
fault function for a short period following manual closure. In addition, at least one stage of each short-circuit
protection function can be selected to trip without delay following line-energizion as described in the corre-
sponding sections. See also Section 2.1.4.1 Setting Notes at margin heading “Circuit breaker status”.
The manual closing command must be indicated to the device via a binary input. In order to be independent
of the duration that the switch is closed, the command is set to a defined length in the device (adjustable with
the address 1150 SI Time Man.Cl). This setting can only be changed using DIGSI at Additional Settings.
Figure 2-167 shows the logic diagram.
[logikdiagramm-hand-ein-wlk-220802, 1, en_GB]
Figure 2-167 Logic diagram of the manual closing procedure
2.20
2.20.1
2.20.1.1
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Reclosure via the integrated control functions - on-site control, control via DIGSI, control via serial interface -
can have the same effect as manual closure, see parameter 1152 Section 2.1.4.1 Setting Notes at margin
heading „Circuit Breaker Status“.
If the device has an integrated automatic reclosure, the integrated manual closure logic of the 7SA522 auto-
matically distinguishes between an external control command via the binary input and an automatic reclosure
by the internal automatic reclosure so that the binary input
>Manual Close
can be connected directly to the
control circuit of the close coil of the circuit breaker (Figure 2-168). Each closing operation that is not initiated
by the internal automatic reclosure function is interpreted as a manual closure, even it has been initiated by a
control command from the device.
[hand-ein-mit-we-wlk-010802, 1, en_GB]
Figure 2-168 Manual closure with internal automatic reclosure
CB Circuit breaker
TC Circuit breaker close coil
CBaux Circuit breaker auxiliary contact
If, however, external close commands which should not activate the manual close function are possible (e.g.
external reclosure device), the binary input
>Manual Close
must be triggered by a separate contact of the
control switch (Figure 2-169).
If in that latter case a manual close command can also be given by means of an internal control command
from the device, such a command must be combined with the manual CLOSE function via parameter 1152
Man.Clos. Imp. (Figure 2-167).
[hand-ein-mit-ext-we-wlk-010802, 1, en_GB]
Figure 2-169 Manual closure with external automatic reclosure
CB Circuit breaker
TC Circuit breaker close coil
CBaux Circuit breaker auxiliary contact
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Besides the manual CLOSE detection, the device records any energization of the line via the integrated line
energization detection. This function processes a change-of-state of the measured quantities as well as the
position of the breaker auxiliary contacts. The current status of the circuit breaker is detected, as described in
the following Section at “Detection of the Circuit Breaker Position”. The criteria for the line energization detec-
tion change according to the local conditions of the measuring points and the setting of the parameter
address 1134 Line Closure (see Section 2.1.4 Power System Data 2 at margin heading “Circuit Breaker
Status”).
The phase currents and the phase-to-earth voltages are available as measuring quantities. A flowing current
excludes that the circuit breaker is open (exception: a fault between current transformer and circuit breaker).
If the circuit breaker is closed, it may, however, still occur that no current is flowing. The voltages can only be
used as a criterion for the de-energised line if the voltage transformers are installed on the feeder side. There-
fore, the device only evaluates those measuring quantities that provide information on the status of the line
according to address 1134.
But a change-of-state, such as a voltage jump from zero to a considerable value (address 1131 PoleOpen-
Voltage) or the occurrence of a considerable current (address 1130 PoleOpenCurrent), can be a reliable
indicator for line energization as such changes can neither occur during normal operation nor in case of a
fault. These settings can only be changed via DIGSI at Additional Settings.
i
i
NOTE
When the Line Closure detection (addresse 1134) is set to: with I or Man.Close, there is a risk that, in
the event of very small load current - less than I-pole open, the line closure may incorrectly assert if a fault
now occurs. In networks with resonant or isolated neutral a wrong operation is also possible with the
setting I OR U or ManCl when a earth fault is present because the line closure detection is done on a
phase selective basis. The setting CB OR I or M/C is therefore recommended for networks with isolated
or resonant grounded neutral.
The position of the auxiliary contacts of the circuit breakers directly indicate the position of the circuit breaker.
If the circuit breaker is controlled single-pole, energization takes place if at least one contact changes from
open to closed.
i
i
NOTE
For the line energization detection with circuit breaker auxiliary contacts, either the phase-selective binary
inputs or the input
>CB 3p Open
(No. 379) must be used. If the binary input
>CB 3p Open
(No. 380) is
not activated, the status circuit breaker 3-pole closed is not established. This status suppresses the line
energization detection.
The detected energization is signalled through the message
Line closure
(No. 590). The parameter 1132
SI Time all Cl. is used to set the signal to a defined length. These settings can only be changed via DIGSI
at Display Additional Settings. Figure 2-170 shows the logic diagram.
In order to avoid that an energization is detected mistakenly, the state “line open”, which precedes any energi-
zation, must apply for a minimum time (settable with the address 1133 T FRG. ZUSCHALT). The default
setting for this enable delay is 250 ms. This setting can only be changed using DIGSI at Additional Settings.
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[logik-zuschalterk-wlk-220802, 1, en_GB]
Figure 2-170 Generation of the energization signal
The line energization detection enables the distance protection, earth fault protection, time-overcurrent
protection and high-current switch onto fault protection to trip without delay after energization of their line
was detected.
Depending on the configuration of the distance protection, an undelayed trip command can be generated
after energization for each pickup or for pickup in zone Z1B. The stages of the earth fault protection and of the
time overcurrent protection generate an undelayed TRIP command if this was provided for in the configura-
tion. The switch onto fault protection is released phase-selectively and three-pole in case of manual closure
after energization detection. In order to generate a trip command as quickly as possible after an energization,
the fast switch onto fault protection is released selectively for each phase already when the line is open.
Detection of the Circuit Breaker Position
For Protection Purposes
Information regarding the circuit breaker position is required by various protection and supplementary func-
tions to ensure their optimal functionality. This is, for example, of assistance for
•The echo function in conjunction with the distance protection with teleprotection (refer to Section
2.6 Teleprotection for distance protection),
•The echo function in conjunction with directional earth fault comparison scheme (refer to Section
2.8 Teleprotection for earth fault overcurrent protection (optional)),
•Weak infeed tripping (refer to Section 2.9.2 Classical Tripping),
•The high-current instantaneous tripping (refer to Section 2.12 Instantaneous high-current switch-on-to-
fault protection (SOTF)),
•The circuit breaker failure protection (refer to Section 2.18 Circuit breaker failure protection (optional)),
•Verification of the dropout condition for the trip command (see Section “Terminating the Trip Signal”).
The device is equipped with a circuit breaker position logic (Figure 2-171) which offers different options
depending on the type of auxiliary contacts provided by the circuit breaker and on how they are connected to
the device.
In most cases it is sufficient to report the status of the circuit breaker with its auxiliary contacts to the device
via binary input. This always applies if the circuit breaker is only switched 3-pole. Then the NO auxiliary
2.20.1.2
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contact of the circuit breaker is connected to a binary input which must be configured to the input function
>CB 3p Closed
(No. 379). The other inputs are then not used and the logic is restricted in principle to
simply forwarding the input information.
If the circuit breaker poles can be switched individually, and only a parallel connection of the NO individual
pole auxiliary contacts is available, the relevant binary input (BI) is allocated to the function
>CB 3p Open
(no. 380). The remaining inputs are not used in this case.
If the circuit breaker poles can be switched individually and if the individual auxiliary contacts are available, an
individual binary input should be used for each auxiliary contact if this is possible and if the device can and is
to trip 1-pole. With this configuration, the device can process the maximum amount of information. Three
binary inputs are used for this purpose:
•
>CB Aux. L1
(No. 351) for the auxiliary contact of pole L1,
•
>CB Aux. L2
(No. 352) for the auxiliary contact of pole L2,
•
>CB Aux. L3
(No. 353) for the auxiliary contact of pole L3,
The inputs No. 379 and No. 380 are not used in this case.
If the circuit breaker can be switched individually, two binary inputs are sufficient if both the parallel as well as
series connection of the auxiliary contacts of the three poles are available. In this case, the parallel connection
of the auxiliary contacts is routed to the input function
>CB 3p Closed
(No.379) and the series connection
is routed to the input function „
>CB 3p Open
(No. 380).
Please note that Figure 2-171 shows the complete logic for all connection alternatives. For each particular
application, only a portion of the inputs is used as described above.
The eight output signals of the circuit breaker position logic can be processed by the individual protection and
supplementary functions. The output signals are blocked if the signals transmitted from the circuit breaker are
not plausible: for example, the circuit breaker cannot be open and closed at the same time. Furthermore, no
current can flow over an open breaker contact.
The evaluation of the measuring quantities is according to the local conditions of the measuring points (see
Section 2.1.4.1 Setting Notes at margin heading “Circuit Breaker Status”).
The phase currents are available as measuring quantities. A flowing current excludes that the circuit breaker is
open (exception: A fault between current transformer and circuit breaker). If the circuit breaker is closed, it
may, however, still occur that no current is flowing. The decisive setting for the evaluation of the measuring
quantities is PoleOpenCurrent (address 1130) for the presence of the currents.
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[logik-ls-stellung-wlk-020802, 1, en_GB]
Figure 2-171 Circuit breaker position logic
For automatic reclosure and circuit breaker test
Separate binary inputs comprising information on the position of the circuit breaker are available for the auto-
matic reclosure and the circuit breaker test. This is important for
•The plausibility check before automatic reclosure (refer to Section 2.13 Automatic reclosure function
(optional)),
•the trip circuit check with the help of the TRIP–CLOSE–test cycle (refer to Section 2.20.2 Circuit breaker
trip test).
When using 11/2 or 2 circuit breakers in each feeder, the automatic reclosure function and the circuit breaker
test refer to one circuit breaker. The feedback information of this circuit breaker can be connected separately
to the device.
For this, separate binary inputs are available, which should be treated the same and configured additionally if
necessary. These have a similar significance as the inputs described above for protection applications and are
marked with “CB1 ...” to distinguish them, i.e.:
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•
>CB1 3p Closed
(No. 410) for the series connection of the NO auxiliary contacts of the CB,
•
>CB1 3p Open
(No. 411) for the series connection of the NC auxiliary contacts of the CB,
•
>CB1 Pole L1
(No. 366) for the auxiliary contact of pole L1,
•
>CB1 Pole L2
(No. 367) for the auxiliary contact of pole L2,
•
>CB1 Pole L3
(No. 368) for the auxiliary contact of pole L3,
Open Pole Detektor
Single-pole dead times can be detected and reported via the Open Pole Detector. The corresponding protec-
tion and monitoring functions can respond. The following figure shows the logic structure of an Open Pole
Detector.
2.20.1.3
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[logik-open-pole-detek-wlk-120902, 1, en_GB]
Figure 2-172 Open pole detector logic
1-pole dead time
During a 1-pole dead time, the load current flowing in the two healthy phases forces a current flow via earth
which may cause undesired pickup. The raising zero- sequence voltage can also produce undesired responses
of the functions.
The indications
1pole open L1
(No. 591),
1pole open L2
(No. 592) and
1pole open L3
(No. 593) are
additionally generated if the “Open Pole Detector” detects that current and voltage are absent in one phase –
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while current flow is detected in both other phases. In this case, one of the indications will only be maintained
while the condition is met. This enables a single-pole automatic reclosure to be detected on an unloaded line.
Specially for applications with busbar side voltage transformers the indication
1pole open Lx
is additionally
transmitted if the phase-selective CB auxiliary contacts clearly show a single-pole open circuit breaker, and the
current of the affected phase falls below the parameter 1130 PoleOpenCurrent.
Depending on the setting of parameter 1136 OpenPoleDetect.the Open Pole Detector evaluates all avail-
able measured values including the auxiliary contacts (default setting w/ measurement) or it processes only
the information from the auxiliary contacts including the phase current values (setting Current AND CB). To
disable the Open Pole Detector, set parameter 1136 to OFF.
Pickup Logic for the Entire Device
Phase Segregated Fault Detection
The fault detection logic combines the fault detection (pickup) signals of all protection functions. In the case
of those protection functions that allow for phase segregated pickup, the pickup is output in a phase segre-
gated manner. If a protection function detects an earth fault, this is also output as a common device alarm.
Thus, the alarms
Relay PICKUP L1
,
Relay PICKUP L2
,
Relay PICKUP L3
and
Relay PICKUP E
are
available.
The above annunciations can be allocated to LEDs or output relays. For the local display of fault event
messages and for the transmission of event messages to a personal computer or a centralized control system,
several protection functions provide the possibility to display the faulted phase information in a single
message, e.g.
Dis.Pickup L12E
for the distance protection fault detection in L1-L2-E; only one such
message appears. It represents the complete definition of the fault detection.
General Pickup
The pickup signals are combined with OR and lead to a general pickup of the device. It is signalled with
Relay
PICKUP
. If no function of the device is picked up any longer,
Relay PICKUP
disappears (indication “OFF”).
General device pickup is a precondition for a series of internal and external functions that occur subsequently.
The following are among the internal functions controlled by general device pickup:
•Opening of a trip log: from general device pickup to general device dropout, all fault indications are
entered in the trip log.
•Initialization of fault record: the storage and maintenance of fault values can also be made dependent on
the occurrence of a trip command.
•Generation of spontaneous indications: Certain fault indications can be displayed as spontaneous indica-
tions (see margin heading “Spontaneous Indications”). In addition, this indication can be made
dependent on the general device trip.
•Start action time of automatic reclosure (if available and used).
External functions may be controlled by this indication via an output contact. Examples are:
•Automatic reclose devices,
•Channel boost in conjunction with signal transmission by PLC.
•Further additional devices or similar.
Spontaneous Displays
Spontaneous indications are fault indications which appear in the display automatically following a general
fault detection or trip command of the device. For the 7SA522, these indications include:
“Relay PICKUP”: Protection function that picked up;
PU Time
:Operating time from the general pickup to the dropout of the device, in ms;
TRIP Time
:the operating time from general pickup to the first trip command of the device, in ms;
dist =
:Distance to fault in kilometers or miles derived by the distance to fault locator function (if
possible).
2.20.1.4
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Tripping Logic of the Entire Device
Three-pole tripping
In general, the device trips three-pole in the event of a fault. Depending on the version ordered (see Section
A Ordering Information and AccessoriesOrdering Information, “Ordering Information”), single-pole tripping is
also possible. If, in general, single-pole tripping is not possible or desired, the output function
Relay TRIP
is
used for the trip command output to the circuit breaker. In these cases, the following sections regarding
single-pole tripping are not of interest.
Single-pole tripping
Single-pole tripping only makes sense on overhead lines on which automatic reclosure is to be carried out and
where the circuit breakers at both ends of the line are capable of single-pole tripping. Single-pole tripping of
the faulted phase with subsequent reclosure is then possible for single phase faults; three-pole tripping is
generally performed in case of two-phase or three-phase faults with and without earth.
Device prerequisites for phase segregated tripping are:
•Phase segregated tripping is provided by the device (according to the ordering code);
•The tripping function is suitable for pole-segregated tripping (for example, not for frequency protection,
overvoltage protection or overload protection),
•The binary input
>1p Trip Perm
is configured and activated or the internal automatic reclosure func-
tion is ready for reclosure after single-pole tripping.
In all other cases tripping is always three-pole. The binary input
>1p Trip Perm
is the logic inversion of a
three-pole coupling and activated by an external auto-reclosure device as long as this is ready for a single-pole
auto-reclosure cycle.
With the 7SA522, it is also possible to trip three-pole when only one phase is subjected to the trip conditions,
but more than one phase indicates a fault detection. With distance protection this is the case when two faults
at different locations occur simultaneously but only one of them is within the range of the fast tripping zone
(Z1 or Z1B). This is selected with the setting parameter 3pole coupling (address 1155), which can be set
to with PICKUP (every multiple-phase fault detection causes three-pole trip) or with TRIP (in the event of
multiplephase fault in the tripping area, the tripping is always three-pole)..
The tripping logic combines the trip signals from all protection functions. The trip commands of those func-
tions that allow single-pole tripping are phase segregated. The corresponding indications are named
Relay
TRIP L1
,
Relay TRIP L2
und
Relay TRIP L3
.
These indications can be allocated to LEDs or output relays. In the event of three-pole tripping all three indica-
tions are displayed. These alarms are also intended for the trip command output to the circuit breaker.
If single-pole tripping is possible, the protection functions generate a group signal for the local display of fault
indications and for the transmission of the indications to a PC or a central control system, e.g.
Dis.Trip
1pL1
,
Dis.Trip 1pL2
,
Dis.Trip 1pL3
for single-pole tripping by the distance protection and
Dis.Trip
3p
for three-pole tripping; only one of these messages is displayed at a time.
Single-pole tripping for two-phase faults
Single-pole tripping for two-phase faults is a special feature. If a phase-to-phase fault without earth occurs in
an earthed system, this fault can be cleared by single-pole trip and automatic reclosure in one of the faulted
phases as the short-circuit path is interrupted in this manner. The phase selected for tripping must be the
same at both line ends (and should be the same for the entire system).
The setting parameter Trip2phFlt (address 1156) allows to select whether this tripping is to be 1pole
leading Ø, i.e. single-pole tripping in the leading phase or 1pole lagging Ø, i.e. single-pole tripping in
the lagging phase. Standard setting is 3pole tripping in the event of two-phase faults (default setting).
2.20.1.5
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Table 2-11 Single-pole and three-pole trip depending on fault type
Type of Fault
(from Protection Func-
tion)
Parameter
Trip2phFlt
Output signals for trip
TRIP 1p. L1 TRIP 1p. L2 TRIP 1p.pol L3 Relay TRIP
3ph.
L1 (any) X
L2 (any) X
L3 (any) X
L1 E (any) X
L2 E (any) X
L3 E (any) X
L1 L2 3pole X
L1 L2 1pole
leading Ø
X
L1 L2 1pole
lagging Ø
X
L2 L3 3pole X
L2 L3 1pole
leading Ø
X
L2 L3 1pole
lagging Ø
X
L1 L3 3pole X
L1 L3 1pole
leading Ø
X
L1 L3 1pole
lagging Ø
X
L1 L2 E (any) X
L2 L3 E (any) X
L1 L3 E (any) X
L1 L2 L3 (any) X
L1 L2 L3 E (any) X
E (any) X
General Trip
All trip signals for the functions are connected by OR and generate the message
Relay TRIP
. This can be
allocated to LED or output relay.
Terminating the Trip Signal
Once a trip command is initiated, it is phase segregatedly latched (in the event of three-pole tripping for each
of the three poles) (refer to Figure 2-173). At the same time, the minimum trip command duration TMin
TRIP CMD (address 240) is started. This ensures that the trip command is output to the circuit breaker for a
sufficiently long time even if the tripping protection function resets very rapidly. The trip commands can only
be reset after all tripping protection functions have dropped out and after the minimum trip command dura-
tion has elapsed.
A further condition for the reset of the trip command is that the circuit breaker has opened, in the event of
singlepole tripping the relevant circuit breaker pole. In the function control of the device, this is checked by
means of the circuit breaker position feedback (Section “Detection of the Circuit Breaker Position”) and the
flow of current. In address 1130 PoleOpenCurrent, the residual current threshold which may definitely not
be exceeded when the circuit breaker pole is open, is set. Address 1135 Reset Trip CMD determines under
which conditions a trip command is reset. If CurrentOpenPole is set, the trip command is reset as soon as
the current disappears. It is important that the value set in address 1130 PoleOpenCurrent (see above) is
undershot. If Current AND CB is set, the circuit breaker auxiliary contact must send a message that the
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circuit breaker is open. It is a prerequisite for this setting that the position of the auxiliary contact is allocated
via a binary input. If this additional condition is not required for resetting the trip command (e.g. if test sockets
are used for protection testing), it can be switched off with the setting Pickup Reset.
[logik-speich-absteuer-ausloese-wlk-020802, 1, en_GB]
Figure 2-173 Storage and termination of the trip command
Reclosure Interlocking
When a protection function has tripped the circuit breaker, it is often desired to prevent reclosing until the
tripping cause has been found. 7SA522 enables this via the integrated reclosure interlocking.
The interlocking state (“LOCKOUT”) will be realized by an RS flipflop which is protected against auxiliary
voltage failure (Figure 2-174). The RS flipflop is set via binary input
>Lockout SET
(No. 385). With the
output alarm
LOCKOUT
(No. 530), if interconnected correspondingly, a reclosure of the circuit breaker (e.g. for
automatic reclosure, manual close signal, synchronization, closing via control) can be blocked. Only once the
cause for the protection operation is known, should the interlocking be reset by a manual reset via binary
input
>Lockout RESET
(No. 386).
[logik-we-verriegelung-wlk-020802, 1, en_GB]
Figure 2-174 Reclosure Interlocking
Conditions which cause reclosure interlocking and control commands which have to be interlocked can be set
individually. The two inputs and the output can be wired via the correspondingly allocated binary inputs and
outputs or be linked via user-defined logic functions (CFC).
If, for example, each trip by the protection function has to cause a closing lock-out, then combine the tripping
command
Relay TRIP
(No. 511) with the locking input
>Lockout SET
. If automatic reclosure is used, only
the final trip of the protection function should activate reclosing lock-out. Remember that the indication
Definitive TRIP
(No. 536) only continues 500 ms. Then c
Definitive TRIP
(No. 536) with the inter-
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locking input
>Lockout SET
, so that the interlocking is not activated if an automatic reclosure is still
expected.
You can configure the output indication
LOCKOUT
(No 530) in the simplest case without other links to the
same output that operated the trip of the circuit breaker. Then the tripping command is maintained until the
interlock is reset via the reset input. This requires the close coil at the circuit breaker to be blocked as usual for
as long as a tripping command is maintained.
The output indication
LOCKOUT
can also be applied to interlock certain closing commands (externally or via
CFC), e.g. by combining the output alarm with the binary input
>Blk Man. Close
(No. 357) or by
connecting the inverted alarm with the bay interlocking of the feeder.
The reset input
>Lockout RESET
(No. 386) resets the interlocking state. This input is initiated by an external
device which is protected against unauthorized or unintentional operation. The interlocking state can also be
controlled by internal sources using CFC, e.g. a function key, operation of the device or using DIGSI on a PC.
For each case please ensure that the corresponding logic operations, security measures, etc. are taken into
account when routing the binary inputs and outputs and may have to be considered when creating the user-
defined logic functions. See also the SIPROTEC 4 System Description.
Breaker Tripping Alarm Suppression
On feeders without automatic reclosure, every trip command by a protection function is final. But when using
automatic reclosure, it is desired that the operation detector of the circuit breaker (fleeting contact at the
breaker) should only generate an alarm if the trip of the breaker is final (Figure 2-175).
To accomplish this, the signal from the circuit breaker can be routed via an output contact of the 7SA522
(output alarm
CB Alarm Supp
, No. 563) that is configured accordingly. In the idle state and when the
device is turned off, this contact is closed. This requires that a normally closed contact is allocated. Which
contact is to be allocated depends on the device version. See also the general views in the Appendix.
Prior to a trip command with the internal automatic reclosure in the ready state, the contact opens so that the
tripping of the circuit breaker is not passed on. This is only the case if the device is equipped with internal
automatic reclosure and if the latter was taken into consideration when configuring the protection functions
(address 133).
Also when closing the breaker via the binary input
>Manual Close
(No. 356) or via the integrated automatic
reclosure the contact is interrupted so that the breaker alarm is inhibited.
Further optional closing commands which are not sent via the device are not taken into consideration. Closing
commands for control can be linked to the alarm suppression via the user-defined logic functions (CFC).
[schalterfall-meldeunterdrueck-wlk-020802, 1, en_GB]
Figure 2-175 Breaker tripping alarm suppression
If the device issues a final trip command, the contact remains closed. This is the case, during the reclaim time
of the automatic reclosure cycle, when the automatic reclosure is blocked or switched off or, due to other
reasons is not ready for automatic reclosure (e.g. tripping only occurred after the action time expired).
Figure 2-176 shows time diagrams for manual trip and close as well as for short-circuit tripping with a single,
failed automatic reclosure cycle.
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[schalterfall-meldeunterdrueck-ablauf-wlk-020802, 1, en_GB]
Figure 2-176 Breaker tripping alarm suppression — sequence examples
Circuit breaker trip test
The 7SA522 distance protection relay allows for convenient testing of the trip circuits and the circuit breakers.
Functional Description
The test programs shown in Table 2-12 are available. The single-pole tests are of course only possible if the
device you are using is capable of single-pole tripping.
The output alarms mentioned must be allocated to the relevant command relays that are used for controlling
the circuit breaker coils.
The test is started using the operator panel on the front of the device or using the PC with DIGSI. The proce-
dure is described in detail in the SIPROTEC 4 System Description. Figure 2-177 shows the progression over
time of an open-close test cycle. The set times are those stated in Section 2.1.2.1 Setting Notes for “Trip
Command Duration” and “Circuit Breaker Test”.
Where the circuit breaker auxiliary contacts indicate the status of the circuit breaker or of its poles to the
device via binary inputs, the test cycle can only be initiated if the circuit breaker is closed.
The information regarding the position of the circuit breakers is not automatically derived from the position
logic according to the above section. For the circuit breaker test function (auto recloser) there are separate
binary inputs for the switching status feedback of the circuit breaker position. These must be taken into
consideration when allocating the binary inputs as mentioned in the previous section.
The alarms of the device show the respective state of the test sequence.
2.20.2
2.20.2.1
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Table 2-12 Circuit breaker test programs
Serial
No.
Test Programs Circuit
Breaker
Output Indications (No.)
1 1-pole TRIP/CLOSE-cycle phase L1
CB 1
CB1-TESTtrip L1 (7325)
2 1-pole TRIP/CLOSE-cycle phase L2 CB1-TESTtrip L2 (7326)
3 1-pole TRIP/CLOSE-cycle phase L3 CB1-TESTtrip L3 (7327)
4 3-pole TRIP/CLOSE-cycle CB1-TESTtrip 123 (7328)
Associated close command CB1-TEST CLOSE (7329)
[ein-aus-pruefzyklus-wlk-170902, 1, en_GB]
Figure 2-177 TRIP-CLOSE test cycle
Setting Notes
The timer setting values are according to Subsection 2.1.2.1 Setting Notes for “command duration” and “circuit
breaker test”.
Information List
No. Information Type of
Informa-
tion
Comments
- CB1tst L1 - CB1-TEST trip/close - Only L1
- CB1tst L2 - CB1-TEST trip/close - Only L2
- CB1tst L3 - CB1-TEST trip/close - Only L3
- CB1tst 123 - CB1-TEST trip/close Phases L123
7325 CB1-TESTtrip L1 OUT CB1-TEST TRIP command - Only L1
7326 CB1-TESTtrip L2 OUT CB1-TEST TRIP command - Only L2
7327 CB1-TESTtrip L3 OUT CB1-TEST TRIP command - Only L3
7328 CB1-TESTtrip123 OUT CB1-TEST TRIP command L123
7329 CB1-TEST close OUT CB1-TEST CLOSE command
7345 CB-TEST running OUT CB-TEST is in progress
7346 CB-TSTstop FLT. OUT_Ev CB-TEST canceled due to Power Sys. Fault
7347 CB-TSTstop OPEN OUT_Ev CB-TEST canceled due to CB already OPEN
7348 CB-TSTstop NOTr OUT_Ev CB-TEST canceled due to CB was NOT READY
7349 CB-TSTstop CLOS OUT_Ev CB-TEST canceled due to CB stayed CLOSED
7350 CB-TST .OK. OUT_Ev CB-TEST was successful
Device
The device requires some general information. This may be, for example, the type of indication to be issued in
the event a power system fault occurs.
2.20.2.2
2.20.2.3
2.20.3
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Trip-Dependent Indications
Spontaneous Fault Messeges
After a fault, the essential fault data spontaneously appear on the device display. Under address 610
FltDisp.LED/LCD you can select whether the spontaneous fault indications are updated in every case of
fault (Target on PU) or only in faults with tripping (Target on TRIP).
For devices with graphic display, you can specify in address 615 Spont. FltDisp. whether a spontaneous
fault message appears automatically on the display (YES) or not (NO). For devices with text display such indi-
cations will appear anyway after a power system fault.
[logik-spondanmeld-display-081024, 1, en_GB]
Figure 2-178 Generation of spontaneous fault indications on the display
Reset of Stored LED / Relays
Pickup of a new protection function generally deletes all stored LED/relays so that only the information of the
latest fault is displayed at a time. The deletion of the stored LED and relays can be inhibited for a settable time
under address 625 T MIN LED HOLD. Any information occurring during this time are then combined with a
logical OR function.
Under address 610 FltDisp.LED/LCD also the information of the latest fault stored on LED and relays can
be deleted with the setting (Target on TRIP) unless this fault has lead to a trip command of the device.
i
i
NOTE
Setting the address 610 FltDisp.LED/LCD to (Target on TRIP) only makes sense if address 625 T
MIN LED HOLD is set to 0.
[logik-ruecksetz-gesp-led-081024, 1, en_GB]
Figure 2-179 Creation of the reset command for saved LED/relays
2.20.3.1
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2.20 Function Control and Circuit Breaker Test
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Switching Statistics
The number of trips initiated by the device 7SA522 are counted. If the device is capable of single-pole tripping,
a separate counter for each circuit breaker pole is provided.
Furthermore, for each trip command the interrupted current for each pole is measured, output in the trip log
and accumulated in a memory. The maximum interrupted current is also stored.
If the device is equipped with the integrated automatic reclosing function, the automatic close commands are
also counted, separately for reclosure after single-pole tripping, after three-pole tripping and separately for the
first and further reclosure cycles.
The counter and memory content are secured against loss of auxiliary voltage. They can be set to zero or to
any other initial value. For more details, please refer to the SIPROTEC 4 System Description.
Setting Notes
Fault Annunciations
Pickup of a new protection function generally turns off any previously set displays, so that only the latest fault
is displayed at any one time. It can be selected whether the stored LED displays and the spontaneous indica-
tions on the display appear upon renewed pickup, or only after a renewed trip signal is issued. In order to
enter the desired type of display, select the submenu General Device Settings in the SETTINGS menu. At
address 610 FltDisp.LED/LCD the two alternatives Target on PU and Target on TRIP (“No trip - no
flag”) are offered.
After startup of the device featuring a 4-line display, default measured values are displayed. Use the arrow
keys on the device front to select different measured value views to be used as the so-called default display.
The start page of the default display, which will open after each startup of the device, can be selected via
parameter 640 Start image DD. The available representation types for the measured value are listed in the
Appendix.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
610 FltDisp.LED/LCD Target on PU
Target on TRIP
Target on PU Fault Display on LED / LCD
625A T MIN LED HOLD 0 .. 60 min; ∞ 0 min Minimum hold time of latched
LEDs
640 Start image DD image 1
image 2
image 3
image 4
image 5
image 1 Start image Default Display
Information List
No. Information Type of
Informa-
tion
Comments
- Test mode IntSP Test mode
- DataStop IntSP Stop data transmission
- Reset LED IntSP Reset LED
- SynchClock IntSP_Ev Clock Synchronization
- >Light on SP >Back Light on
- HWTestMod IntSP Hardware Test Mode
- Error FMS1 OUT Error FMS FO 1
2.20.3.2
2.20.3.3
2.20.3.4
2.20.3.5
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No. Information Type of
Informa-
tion
Comments
- Error FMS2 OUT Error FMS FO 2
- Distur.CFC OUT Disturbance CFC
- Brk OPENED IntSP Breaker OPENED
- FdrEARTHED IntSP Feeder EARTHED
1 Not configured SP No Function configured
2 Non Existent SP Function Not Available
3 >Time Synch SP >Synchronize Internal Real Time Clock
5 >Reset LED SP >Reset LED
11 >Annunc. 1 SP >User defined annunciation 1
12 >Annunc. 2 SP >User defined annunciation 2
13 >Annunc. 3 SP >User defined annunciation 3
14 >Annunc. 4 SP >User defined annunciation 4
15 >Test mode SP >Test mode
16 >DataStop SP >Stop data transmission
51 Device OK OUT Device is Operational and Protecting
52 ProtActive IntSP At Least 1 Protection Funct. is Active
55 Reset Device OUT Reset Device
56 Initial Start OUT Initial Start of Device
67 Resume OUT Resume
68 Clock SyncError OUT Clock Synchronization Error
69 DayLightSavTime OUT Daylight Saving Time
70 Settings Calc. OUT Setting calculation is running
71 Settings Check OUT Settings Check
72 Level-2 change OUT Level-2 change
73 Local change OUT Local setting change
110 Event Lost OUT_Ev Event lost
113 Flag Lost OUT Flag Lost
125 Chatter ON OUT Chatter ON
126 ProtON/OFF IntSP Protection ON/OFF (via system port)
127 AR ON/OFF IntSP Auto Reclose ON/OFF (via system port)
128 TelepONoff IntSP Teleprot. ON/OFF (via system port)
140 Error Sum Alarm OUT Error with a summary alarm
144 Error 5V OUT Error 5V
160 Alarm Sum Event OUT Alarm Summary Event
177 Fail Battery OUT Failure: Battery empty
181 Error A/D-conv. OUT Error: A/D converter
183 Error Board 1 OUT Error Board 1
184 Error Board 2 OUT Error Board 2
185 Error Board 3 OUT Error Board 3
186 Error Board 4 OUT Error Board 4
187 Error Board 5 OUT Error Board 5
188 Error Board 6 OUT Error Board 6
189 Error Board 7 OUT Error Board 7
190 Error Board 0 OUT Error Board 0
191 Error Offset OUT Error: Offset
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No. Information Type of
Informa-
tion
Comments
192 Error1A/5Awrong OUT Error:1A/5Ajumper different from setting
193 Alarm adjustm. OUT Alarm: Analog input adjustment invalid
194 Error neutralCT OUT Error: Neutral CT different from MLFB
320 Warn Mem. Data OUT Warn: Limit of Memory Data exceeded
321 Warn Mem. Para. OUT Warn: Limit of Memory Parameter exceeded
322 Warn Mem. Oper. OUT Warn: Limit of Memory Operation exceeded
323 Warn Mem. New OUT Warn: Limit of Memory New exceeded
4051 Telep. ON IntSP Teleprotection is switched ON
Ethernet EN100-Module
Functional Description
An Ethernet Ethernet EN100-Module allows for the integration of the 7SA522 into 100 Mbit Ethernet
communication networks used by process control and automation systems according to the IEC 61850 proto-
cols. This standard enables integrated inter-relay communication without using gateways or protocol
converters. This allows open and interoperable use of SIPROTEC 4 devices even in heterogeneous environ-
ments. In addition to the process control integration of the device, this interface can also be used for commu-
nication with DIGSI and for interrelay communication via GOOSE messaging.
Setting Notes
Interface selection
No settings are required for operation of the Ethernet system interface module (IEC 61850 Ethernet EN100-
Modul). If the device is equipped with such a module (see MLFB), the module is automatically configured to
the interface available for it.
Information List
No. Information Type of
Informa-
tion
Comments
009.0100 Failure Modul IntSP Failure EN100 Modul
009.0101 Fail Ch1 IntSP Failure EN100 Link Channel 1 (Ch1)
009.0102 Fail Ch2 IntSP Failure EN100 Link Channel 2 (Ch2)
2.20.4
2.20.4.1
2.20.4.2
2.20.4.3
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Auxiliary Functions
The additional functions of the 7SA522 distance protection relay include:
•Commissioning tool,
•Processing of messages,
•Processing of operational measured values,
•Storage of fault record data.
Commissioning Aids
Functional Description
The device is provided with a comprehensive commissioning and monitoring tool that checks the entire
distance protection system: The WEB-Monitor. The documentation for this tool is available on CD-ROM with
DIGSI, and on the Internet at www.siprotec.com.
To ensure proper communication between the device and the PC browser, several prerequisites must be met.
The transmission speed must be the same and an IP address has to be assigned so that the browser can iden-
tify the device.
Thanks to the WEB Monitor, the user is able to operate the device from a PC. On the PC screen, the front panel
of the device with its operator keyboard is emulated. The actual operation of the device can be simulated
using the mouse pointer. This feature can be disabled.
If the device is equipped with an EN100 module, operation by DIGSI or the WEB Monitor is possible via
Ethernet. This is done by simply setting the IP configuration of the device accordingly. Parallel operation of
DIGSI and WEB Monitor via different interfaces is possible.
WEB-Monitor
The WEB Monitor provides quick and easy access to the most important data in the device. Using a personal
computer with a web browser, the WEB Monitor offers a detailed illustration of the most important measured
values and of the distance protection data required for directional checks.
The measured values list can be selected from the navigation toolbar separately for the local device and (in
devices with protection data interface) the remote device. In each case a list with the desired information is
displayed (see Figure 2-180 and Figure 2-181).
2.21
2.21.1
2.21.1.1
Functions
2.21 Auxiliary Functions
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[webmon-primaer-mess-wlk-040427, 1, en_GB]
Figure 2-180 Local measured values in the Web-Monitor — examples for measured values
[webmon-primaer-mess-fern-wlk-040427, 1, en_GB]
Figure 2-181 Measured values of the remote device — Example
The currents, voltages and their phase angles derived from the primary, secondary and remote measured
values are graphically displayed as phasor diagrams. Figure 2-182 shows this view for one device, and
Figure 2-183 for two devices. In addition to phasor diagrams of the measured values, the numerical values as
well as frequency and device addresses are indicated. For details please refer to the documentation provided
for the WEB-Monitor.
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2.21 Auxiliary Functions
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[webmon-messwertprim-zeig-wlk-040429, 1, en_GB]
Figure 2-182 Phasor diagram of the primary measured values — Example
[webmon-messwertfern-zeig-wlk-040429, 1, en_GB]
Figure 2-183 Phasor diagram of the remote measured values — Example
The following types of indications can be retrieved and displayed with the WEB-Monitor
•Event Log (operational indications),
•Trip Log (fault indications),
•Spontaneous indications
You can print these lists with the“Print event buffer” button.
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2.21 Auxiliary Functions
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The illustration below shows how the displayed measured values are allocated to the devices of the distance
protection system. The active power direction of each device is shown by an arrow. The active power is calcu-
lated on the basis of voltages and currents that exceed the values set for PoleOpenVoltage (address 1131)
or PoleOpenCurrent (address 1130). The direction of the arrow, and its colour, show you whether the
active power flows into the line or whether the current transformer is misconnected. This allows to check the
correct connection of the current transformers at each line end. If there are several ends, you can check the
theoretically determined directions. This directional check is used to verify that the protection operates in the
correct direction. It is not related with parameter 1107 P,Q sign.
[webmon-richtung-drei-ger-wlk-040429, 1, en_GB]
Figure 2-184 Directional check for three devices — Example
Setting Notes
The parameters of the WEB-Monitor can be set separately for the front operator interface and the service inter-
face. The relevant IP address of the interface is the one that is used for communication with the PC and the
WEB-Monitor.
Make sure that the 12-digit IP address valid for the browser is set correctly via DIGSI in the format
***.***.***.***.
Processing of Messages
After the occurrence of a system fault, data regarding the response of the protection relay and the measured
quantities should be saved for future analysis. For this reason message processing is done in three ways:
Functional Description
Indicators and Binary Outputs (Output Relays)
Important events and states are displayed by LEDs on the front cover. The device also contains output relays
for remote signaling. Most indications and displays can be configured differently from the delivery default
settings (for information on the delivery default setting see Appendix). The SIPROTEC 4 System Description
gives a detailed description of the configuration procedure.
The output relays and the LEDs may be operated in a latched or unlatched mode (each may be individually
set).
The latched conditions are protected against loss of the auxiliary voltage. They are reset
2.21.1.2
2.21.2
2.21.2.1
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•On site by pressing the LED key on the relay,
•Remotely using a binary input configured for that purpose,
•via one of the serial interfaces,
•Automatically at the beginning of a new pickup.
Status messages should not be latched. Also, they cannot be reset until the criterion to be reported is
remedied. This applies to, e.g., indications from monitoring functions, or the like.
A green LED displays operational readiness of the relay (“RUN”); it cannot be reset. It extinguishes if the self-
check feature of the microprocessor detects an abnormal occurrence, or if the auxiliary voltage fails.
When auxiliary voltage is present but the relay has an internal malfunction, the red LED (“ERROR”) lights up
and the processor blocks the relay.
DIGSI enables you to selectively control each output relay and LED of the device and, in doing so, check the
correct connection to the system. In a dialog box, you can, for instance, cause each output relay to pick up,
and thus test the wiring between the 7SA522 and the system without having to create the indications masked
to it.
Information on the Integrated Display (LCD) or to a Personal Computer
Events and conditions can be read out on the display on the front panel of the relay. Using the front operator
interface or the rear service interface, for instance, a personal computer can be connected, to which the infor-
mation can be sent.
In the quiescent state, i.e. as long as no system fault is present, the LCD can display selectable operational
information (overview of the operational measured values) (default display). In the event of a system fault,
information regarding the fault, the so-called spontaneous displays, are displayed instead. After the fault indi-
cations have been acknowledged, the quiescent data are shown again. Acknowledgement is accomplished by
pressing the LED buttons on the front panel (see above).
Figure 2-185 shows the default display in a 4-line display as preset.
Various default displays can be selected via the arrow keys. Parameter 640 can be set to change the default
setting for the default display page shown in idle state. Two examples of possible default display selections are
given below.
[beispiel-grundb-4-zeil-disp-wlk-210802, 1, en_GB]
Figure 2-185 Operational measured values in the default display
Default display 3 shows the measured power values and the measured values UL1-L2 and ΙL2 dargestellt.
[grundb-3-4-zeil-displ-wlk-230802, 1, en_GB]
Figure 2-186 Operational measured values in the default display
Moreover, the device has several event buffers for operational indications, fault indications, switching statis-
tics, etc., which are protected against loss of auxiliary supply by means of a backup battery. These indications
can be displayed on the LCD at any time by selection using the keypad or transferred to a personal computer
via the serial service or operator interface. Reading out indications during operation is described in detail in
the SIPROTEC 4 System Description.
After a system fault, for example, important information about the progression of the fault can be retrieved,
such as the pickup of a protection stage or the initiation of a trip signal. The system clock accurately provides
the absolute time when the fault first occurred. The fault progression is output with a relative time referred to
Functions
2.21 Auxiliary Functions
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the instant of pickup so that the time until tripping and until reset of the trip command can be recognized. The
resolution of the time information is 1 ms.
With a PC and the DIGSI protection data processing software, it is also possible to retrieve and display the
events with the convenience of visualisation on a monitor and a menu-guided dialog. The data can either be
printed out or stored elsewhere for later evaluation.
The protection device stores the messages of the last eight system faults; in the event of a ninth fault, the
oldest is erased.
A system fault starts with the detection of the fault by the fault detection of any protection function and ends
with the reset of the fault detection of the last protection function or after the expiry of the auto-reclose
reclaim time, so that several unsuccessful reclose cycles are also stored cohesively. Accordingly a system fault
may contain several individual fault events (from fault detection up to reset of fault detection).
Information to a Control Centre
If the device has a serial system interface, stored information may additionally be transferred via this interface
to a central control and storage device. Transmission is possible via different transmission protocols.
You may test whether the indications are transmitted correctly with DIGSI.
Also the information transmitted to the control centre can be influenced during operation or tests. The IEC
60870-5-103 protocol allows to identify all indications and measured values transferred to the central control
system with an added indication “test mode” while the device is being tested on site (test mode). This identifi-
cation prevents the indications from being incorrectly interpreted as resulting from an actual power system
disturbance or event. Alternatively, you may disable the transmission of indications to the system interface
during tests “Transmission Block”).
To influence information at the system interface during test mode (“test mode” and “transmission block”), a
CFC logic is required. Default settings already include this logic (see Appendix).
The SIPROTEC 4 System Description describes in detail how to activate and deactivate test mode and blocked
data transmission.
Classification of Indications
Indications are classified as follows:
•Operational indications: messages generated while the device is in operation: They include information
about the status of device functions, measurement data, system data, and similar information.
•Fault indications: messages from the last eight system faults that were processed by the device.
•Indications on Statistics: they include counters for the switching actions of the circuit breakers initiated
by the device, maybe reclose commands as well as values of interrupted currents and accumulated fault
currents.
A complete list of all indications and output functions generated by the device with the associated information
number (No.) can be found in the Appendix. This list also indicates where each indication can be sent. If
certain functions are not avaiable in a device version with reduced function scope or if they are configured as
in the function scope, then the associated indications will not appear.
Operational Indications
Operational indications contain information generated by the device during operation about operational
conditions.
Up to 200 operational indications are recorded in chronological order in the device. Newly generated indica-
tions are added to those already present. If the maximum capacity of the memory has been exceeded, the
oldest indication will be overwritten.
Operational indications arrive automatically and can be read out from the device display or a personal
computer at any time. Faults in the power system are indicated with “Network Fault” and the present fault
number. The fault indications contain detailed information on the response during system faults.
Fault Indications
Following a system fault it is possible to retrieve important information regarding its progress, such as pickup
and trip. The system clock accurately provides the absolute time when the fault first occurred. The fault
Functions
2.21 Auxiliary Functions
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progression is output with a relative time referred to the instant of pickup so that the time until tripping and
until reset of the trip command can be recognized. The resolution of the time information is 1 ms.
A system fault starts with the recognition of a fault by the fault detection, i.e. first pickup of any protection
function, and ends with the reset of the fault detection, i.e. dropout of the last protection function. Where a
fault causes several protection functions to pick up, the fault is considered to include all that occurred
between pickup of the first protection function and dropout of the last protection function.
Spontaneous Indications
After a fault, the device displays automatically and without any operator action on its LCD display the most
important fault data from the general device pickup in the sequence shown in Figure 2-187.
[anzeig-spontan-meld-displ-wlk-210802, 1, en_GB]
Figure 2-187 Display of spontaneous messages in the display — Example
Fault Location Options
In addition to the displays located on the device front and in DIGSI, there are additional display options avail-
able in particular for the fault location. They depend on the device version, configuration and allocation:
•If the device features the BCD output for the fault location, the transmitted figures mean the following:
0 to 195: the calculated fault location in % of the line length (if greater than 100%, the error lies outside
the protected line in a forward direction);
197: negative fault location (fault in reverse direction);
199: Überlauf.
Retrievable Indications
The indications of the last eight system faults can be retrieved and read out. A total of 600 indications can be
stored. The oldest indications are erased for the newest fault indications when the buffer is full.
Spontaneous Indications
Spontaneous indications contain information that new indications have arrived. Each new incoming indication
appears immediately, i.e. the user does not have to wait for an update or initiate one. This can be a useful help
during operation, testing and commissioning.
Spontaneous indications can be read out via DIGSI. For more information see the SIPROTEC 4 System Descrip-
tion.
General Interrogation
The present condition of the SIPROTEC 4 device can be retrieved via DIGSI by viewing the contents of the
General Interrogation. It shows all indications that are subject to general interrogation with their current
value.
Statistics
Counting includes the number of trips initiated by 7SA522, the accumulated breaking currents resulting from
trips initiated by protection functions, the number of close commands initiated by the auto-reclosure function.
2.21.3
Functions
2.21 Auxiliary Functions
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Functional Description
Counters and Memories
The counters and memories of the statistics are saved by the device. Therefore, the information will not get
lost in case the auxiliary voltage supply fails. The counters, however, can be reset to zero or to any value
within the setting range.
Switching statistics can be viewed on the LCD of the device, or on a PC running DIGSI and connected to the
operating or service interface.
A password is not required to read switching statistics; however, a password is required to change or delete
the statistics. For more information see the SIPROTEC 4 System Description.
Number of trips
The number of trips initiated by the device 7SA522 is counted. If the device is capable of single-pole tripping,
a separate counter for each circuit breaker pole is provided.
Number of automatic reclosing commands
If the device is equipped with the integrated automatic reclosure, the automatic close commands are also
counted, separately for reclosure after 1-pole tripping, after 3-pole tripping as well as separately for the first
reclosure cycle and other reclosure cycles.
Interrupted currents
Furthermore, for each trip command the interrupted current for each pole is acquired, output in the trip log
and accumulated in a memory. The maximum interrupted current is stored as well. The indicated measured
values are indicated in primary values.
Transmission statistics
In 7SA522 the protection communication is registered in statistics. The delay times of the information
between the devices via interfaces (run and return) are measured steadily. The values are kept stored in the
Statistics folder. The availability of the transmission media is also reported. The availability is indicated in % /
min and % / h. This enables an evaluation of the transmission quality.
Setting Notes
Reading/Setting/Resetting
The SIPROTEC 4 System Description describes how to read out the statistical counters via the device front
panel or DIGSI. Setting or resetting of these statistical counters takes place under the menu item INDICA-
TIONS -> STATISTICS by overwriting the counter values displayed.
Information List
No. Information Type of
Informa-
tion
Comments
1000 # TRIPs= VI Number of breaker TRIP commands
1001 TripNo L1= VI Number of breaker TRIP commands L1
1002 TripNo L2= VI Number of breaker TRIP commands L2
1003 TripNo L3= VI Number of breaker TRIP commands L3
1027 Σ IL1 = VI Accumulation of interrupted current L1
1028 Σ IL2 = VI Accumulation of interrupted current L2
1029 Σ IL3 = VI Accumulation of interrupted current L3
1030 Max IL1 = VI Max. fault current Phase L1
1031 Max IL2 = VI Max. fault current Phase L2
2.21.3.1
2.21.3.2
2.21.3.3
Functions
2.21 Auxiliary Functions
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No. Information Type of
Informa-
tion
Comments
1032 Max IL3 = VI Max. fault current Phase L3
2895 AR #Close1./1p= VI No. of 1st AR-cycle CLOSE commands,1pole
2896 AR #Close1./3p= VI No. of 1st AR-cycle CLOSE commands,3pole
2897 AR #Close2./1p= VI No. of higher AR-cycle CLOSE commands,1p
2898 AR #Close2./3p= VI No. of higher AR-cycle CLOSE commands,3p
7751 PI1 TD MV Prot.Interface 1:Transmission delay
7752 PI2 TD MV Prot.Interface 2:Transmission delay
7753 PI1A/m MV Prot.Interface 1: Availability per min.
7754 PI1A/h MV Prot.Interface 1: Availability per hour
7755 PI2A/m MV Prot.Interface 2: Availability per min.
7756 PI2A/h MV Prot.Interface 2: Availability per hour
Measurement
Functional Description
A series of measured values and the values derived from them are available for on-site retrieval or for data
transfer.
A precondition for the correct display of primary and percentage values is the complete and correct entry of
the nominal values of the instrument transformers and the power system as well as the transformation ratio
of the current and voltage transformers in the earth paths.
Display of measured values
Depending on ordering code, connection of the device and configured protection functions, only some of the
operational measured values listed in Table 2-13 may be available. Of the current values ΙEE, ΙY and ΙP only the
one which is connected to current measuring input Ι4 can apply. Phase-to-earth voltages can only be meas-
ured if the phase-to-earth voltage inputs are connected. The displacement voltage 3U0 is e-n-voltage multi-
plied by √3 — if Uen is connected — or calculated from the phase-to-earth voltages 3U0 = |UL1 + UL2 + UL3|. All
three voltage inputs must be phase-earth connected for this.
The zero sequence voltage U0 indicates the voltage between the centre of the voltage triangle and earth.
If the device features synchronism and voltage check and if, when configuring the functions (address 135),
these functions were set as Enabled and the parameter U4 transformer transformer (address 210) to
Usy2 transf. transf., you can read out the characteristic values (voltages, frequencies, differences).
The power and operating values upon delivery are set such that power in line direction is positive. Active
components in line direction and inductive reactive components in line direction are also positive. The same
applies for the power factor cosφ.
It is occasionally desired to define the power drawn from the line (e.g. as seen from the consumer) positively.
Using parameter 1107 P,Q sign the signs for these components can be inverted.
The computation of the operational measured values is also executed during an existent system fault in inter-
vals of approx. 0.5 s
Table 2-13 Operational measured values of the local device
Measured Values primary secondary % referred to
ΙL1, ΙL2, ΙL3 Phase currents A A Rated operational current 1)
ΙEE Sensitive earth current A mA Rated operational current 3)1)
2.21.4
2.21.4.1
Functions
2.21 Auxiliary Functions
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Measured Values primary secondary % referred to
3Ι0 - calculated Earth current A A Rated operational current 1)
3Ι0 - measured Earth current A A Rated operational current 3)1)
Ι1, Ι2Positive and negative sequence compo-
nent of currents
A A Rated operational current 1)
ΙY, ΙPTransformer Starpoint Current or Earth
Current of the Parallel Line
A A Rated operational current 3)1)
UL1-E, UL2-E, UL3-E Phase-to-earth voltages kV V Rated operational voltage / √3 2)
UL1-L2, UL2-L3, UL3-L1 Phase-to-phase voltages kV V Rated operational voltage 2)
3U0Displacement Voltage kV V Rated operational voltage / √32)
U0Zero-sequence voltage kV V Rated operational voltage / √32)
U1, U2Positive and negative sequence compo-
nent of voltages
kV V Rated operational voltage / √32)
UX, Uen Voltage at measuring input U4- V -
Usy2 Voltage at measuring input U4kV V Rated operational voltage or
Rated operational voltage /
√32)4)5)
U1kompoundiert Positive sequence component of
voltages at the remote end (if
compounding is active in voltage
protection)
kV V Betriebsnennspannung / √32)
RL1-E, RL2-E,
RL3-E, RL1-L2,
RL1-L2, RL3-L1
Operational resistance of all loops Ω Ω -
XL1-E, XL2-E,
XL3-E,XL1-L2,
XL2-L3, XL3-L1
Operational reactance of all loops Ω Ω -
S, P, Q Apparent, active and reactive power MVA,
MW,
MVAR
-√3·UN·ΙN operational rated quan-
tities 1)2)
f Frequency Hz Hz Rated system frequency
cos φ Power factor (abs) (abs) -
Usy1, Usy2, Udiff Measured voltage values
(for synchronism check)
kV - -
fsy1, fsy2, fdiff Measured voltage values
(for synchronism check)
(für Synchronkontrolle)
Hz - -
φdiff Betrag der Phasenwinkeldifferenz
zwischen den Messstellen Usy1 und Usy2
(für Synchronkontrolle)
°- -
1) according to address 1104
2) according to address 1103
3) considering factor 221 I4/Iph CT
4) according to address 212 Usy2 connection
5) considering factor 215 Usy1/Usy2 ratio
Functions
2.21 Auxiliary Functions
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Remote measured values
During communication, the data of the other ends of the protected object can also be read out. For each of
the devices, the currents and voltages involved as well as phase shifts between the local and remote measured
quantities can be displayed. This is especially helpful for checking the correct and coherent phase allocation
and polarity at the different line ends. Furthermore, the device addresses of the other devices are transmitted
so that all important data of all ends are available in a substation. All possible data are listed in Table 2-14
aufgelistet.
Table 2-14 Operational measured values transmitted from the other ends and compared to the local
values
Data Primary value
Device ADR Device address of the remote device (absolut)
ΙL1, ΙL2, ΙL3 remote Phase currents of the remote device A
ΙL1, ΙL2, ΙL3 local Phase currents of the local device A
φ(ΙL1), φ(ΙL2), φ(ΙL3) remote Phase angle of the phase currents of the remote device referred to the
local voltage UL1-E
°
φ(ΙL1), φ(ΙL2), φ(ΙL3) local Phase angle of the phase currents of the local device referred to the
local voltage UL1-E
°
UL1, UL2, UL3 remote Voltages of the remote device kV
UL1, UL2, UL3 local Voltages of the local device kV
φ(UL1), φ(UL2) φ(UL3)
remote
Phase angle of the phase voltages of the remote device referred to the
local voltage UL1-E
°
φ(UL1), φ(UL2) φ(UL3) local Phase angle of the phase voltages of the local device referred to the
local voltageUL1-E
°
Information List
No. Information Type of
Informa-
tion
Comments
601 IL1 = MV I L1
602 IL2 = MV I L2
603 IL3 = MV I L3
610 3I0 = MV 3I0 (zero sequence)
611 3I0sen= MV 3I0sen (sensitive zero sequence)
612 IY = MV IY (star point of transformer)
613 3I0par= MV 3I0par (parallel line neutral)
619 I1 = MV I1 (positive sequence)
620 I2 = MV I2 (negative sequence)
621 UL1E= MV U L1-E
622 UL2E= MV U L2-E
623 UL3E= MV U L3-E
624 UL12= MV U L12
625 UL23= MV U L23
626 UL31= MV U L31
627 Uen = MV Uen
631 3U0 = MV 3U0 (zero sequence)
632 Usy2= MV Measured value Usy2
633 Ux = MV Ux (separate VT)
2.21.4.2
Functions
2.21 Auxiliary Functions
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No. Information Type of
Informa-
tion
Comments
634 U1 = MV U1 (positive sequence)
635 U2 = MV U2 (negative sequence)
636 Udiff = MV Measured value U-diff (Usy1- Usy2)
637 Usy1= MV Measured value Usy1
638 Usy2= MV Measured value Usy2
641 P = MV P (active power)
642 Q = MV Q (reactive power)
643 PF = MV Power Factor
644 Freq= MV Frequency
645 S = MV S (apparent power)
646 F-sy2 = MV Frequency fsy2
647 F-diff= MV Frequency difference
648 φ-diff= MV Angle difference
649 F-sy1 = MV Frequency fsy1
679 U1co= MV U1co (positive sequence, compounding)
684 U0 = MV U0 (zero sequence)
966 R L1E= MV R L1E
967 R L2E= MV R L2E
970 R L3E= MV R L3E
971 R L12= MV R L12
972 R L23= MV R L23
973 R L31= MV R L31
974 X L1E= MV X L1E
975 X L2E= MV X L2E
976 X L3E= MV X L3E
977 X L12= MV X L12
978 X L23= MV X L23
979 X L31= MV X L31
Oscillographic Fault Records
Functional Description
The 7SA522 is equipped with a fault recording function. The instantaneous values of the measured quantities
iL1, iL2, iL3, iE or iEE, ip, iy and uL1, uL2, uL3, uen or usync or ux or 3·u0
(voltages depending on the connection) are sampled at intervals of 1 ms (for 50 Hz) and stored in a circulating
buffer (20 samples per cycle). For a fault, the data are stored for an adjustable period of time, but no more
than 5 seconds per fault. A total of 8 faults can be saved spanning a total time of 15 s maximum. The fault
record memory is automatically updated with every new fault, so that no acknowledgment is required. The
storage of fault values can be started by pickup of a protection function, as well as via binary input and via the
serial interface.
The data can be retrieved via the serial interfaces by means of a personal computer and evaluated with the
operating software DIGSI and the graphic analysis software SIGRA 4. The latter graphically represents the data
recorded during the system fault and calculates additional information such as the impedance or r.m.s. values
from the measured values. A selection may be made as to whether the currents and voltages are represented
as primary or secondary values. Binary signal traces (marks) of particular events, e.g. “fault detection”, “trip-
ping” are also represented.
2.21.5
2.21.5.1
Functions
2.21 Auxiliary Functions
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If the device has a serial system interface, the fault recording data can be passed on to a central device via this
interface. Data are evaluated by appropriate programs in the central device. Currents and voltages are referred
to their maximum values, scaled to their rated values and prepared for graphic presentation. Binary signal
traces (marks) of particular events e.g. “fault detection”, “tripping” are also represented.
In the event of transfer to a central device, the request for data transfer can be executed automatically and
can be selected to take place after each fault detection by the protection, or only after a trip.
Setting Notes
General
Other settings pertaining to fault recording (waveform capture) are found in the submenu Oscillographic
Fault Records submenu of the Settings menu. Waveform capture makes a distinction between the trigger
instant for an oscillographic record and the criterion to save the record (address402 WAVEFORMTRIGGER).
This parameter can only be altered in DIGSI at Display Additional Settings. Normally the trigger instant is the
device pickup, i.e. the pickup of an arbitrary protection function is assigned the time. The criterion for saving
may be both the device pickup(Save w. Pickup) or the device trip Save w. TRIP). A trip command
issued by the device can also be used as trigger instant (Start w. TRIP), in this case it is also the saving
criterion.
An oscillographic fault record includes data recorded prior to the time of trigger, and data after the dropout of
the recording criterion. Usually this is also the extent of a fault recording (address 403 WAVEFORM DATA =
Fault event). If automatic reclosure is implemented, the entire system disturbance — possibly with several
reclose attempts — up to the ultimate fault clearance can be stored (address 403 WAVEFORM DATA =
Pow.Sys.Flt.). This facilitates the representation of the entire system fault history, but also consumes
storage capacity during the auto reclosure dead time(s). This parameter can only be altered in DIGSI at Display
Additional Settings.
The actual storage time encompasses the pre-fault time PRE. TRIG. TIME (address 411) ahead of the refer-
ence instant, the normal recording time and the post-fault time POST REC. TIME (address 412) after the
storage criterion has reset. The maximum recording duration to each fault MAX. LENGTH is set at address
410.
The fault recording can also be triggered via a binary input, via the keypad on the front of the device or with a
PC via the operation or service interface. The storage is then dynamically triggered. The length of the fault
recording is set in address 415 BinIn CAPT.TIME (maximum length however is MAX. LENGTH, address
410). Pre-fault and post-fault times will be included. If the binary input time is set for ∞ , then the length of
the record equals the time that the binary input is activated (static), or the MAX. LENGTH setting in address
410, whichever is shorter.
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr. Parameter Setting Options Default Setting Comments
402A WAVEFORMTRIGGER Save w. Pickup
Save w. TRIP
Start w. TRIP
Save w. Pickup Waveform Capture
403A WAVEFORM DATA Fault event
Pow.Sys.Flt.
Fault event Scope of Waveform Data
410 MAX. LENGTH 0.30 .. 5.00 sec 2.00 sec Max. length of a Waveform
Capture Record
411 PRE. TRIG. TIME 0.05 .. 0.50 sec 0.25 sec Captured Waveform Prior to
Trigger
412 POST REC. TIME 0.05 .. 0.50 sec 0.10 sec Captured Waveform after Event
415 BinIn CAPT.TIME 0.10 .. 5.00 sec; ∞ 0.50 sec Capture Time via Binary Input
2.21.5.2
2.21.5.3
Functions
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Information List
No. Information Type of
Informa-
tion
Comments
- FltRecSta IntSP Fault Recording Start
4 >Trig.Wave.Cap. SP >Trigger Waveform Capture
30053 Fault rec. run. OUT Fault recording is running
Demand Measurement Setup
Long-term average values are calculated by 7SA522 and can be read out with the point of time (date and
time) of the last update.
Long-Term Average Values
The long-term average values of the three phase currents ΙLx, the positive sequence component Ι1 of the three
phase currents, and the real power P, reactive power Q, and apparent power S are calculated within a set
period of time and indicated in primary values.
For the long-term average values mentioned above, the length of the time window for averaging and the
frequency with which it is updated can be set. The corresponding min/max values can be reset via binary
inputs, via the integrated control panel or using the DIGSI software.
Setting Notes
Mean values
The time interval for measured value averaging is set at address 2801 DMD Interval. The first number
specifies the averaging time window in minutes while the second number gives the frequency of updates
within the time window. 15 Min., 3 Subs, for example, means that time averaging occurs for all meas-
ured values that arrive within 15 minutes. The output is updated every 15/3 = 5 minutes.
At address 2802 DMD Sync.Time you can determine whether the averaging time, selected under address
2801, begins on the hour (On The Hour) or is to be synchronized with another point in time (15 After
Hour, 30 After Hour or 45 After Hour).
If the settings for averaging are changed, then the measured values stored in the buffer are deleted, and new
results for the average calculation are only available after the set time period has passed.
Settings
Addr. Parameter Setting Options Default Setting Comments
2801 DMD Interval 15 Min., 1 Sub
15 Min., 3 Subs
15 Min.,15 Subs
30 Min., 1 Sub
60 Min., 1 Sub
60 Min., 1 Sub Demand Calculation Intervals
2802 DMD Sync.Time On The Hour
15 After Hour
30 After Hour
45 After Hour
On The Hour Demand Synchronization Time
2.21.5.4
2.21.6
2.21.6.1
2.21.6.2
2.21.6.3
Functions
2.21 Auxiliary Functions
352 SIPROTEC 4, 7SA522, Manual
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Information List
No. Information Type of
Informa-
tion
Comments
833 I1dmd = MV I1 (positive sequence) Demand
834 Pdmd = MV Active Power Demand
835 Qdmd = MV Reactive Power Demand
836 Sdmd = MV Apparent Power Demand
963 IL1dmd= MV I L1 demand
964 IL2dmd= MV I L2 demand
965 IL3dmd= MV I L3 demand
1052 Pdmd Forw= MV Active Power Demand Forward
1053 Pdmd Rev = MV Active Power Demand Reverse
1054 Qdmd Forw= MV Reactive Power Demand Forward
1055 Qdmd Rev = MV Reactive Power Demand Reverse
Min/Max Measurement Setup
Minimum and maximum values are calculated by the 7SA522 and can be read out with the point of time (date
and time) of the last update.
Reset
The minimum and maximum values can be reset, using binary inputs or by using the integrated control panel
or the DIGSI software. Additionally, the reset can be carried out cyclically, beginning with a preset point of
time.
Setting Notes
The tracking of minimum and maximum values can be reset automatically at a pre-defined point in time. To
select this feature, address 2811 MinMax cycRESET is set to YES (default setting).
The point in time when reset is to take place (the minute of the day in which reset will take place) is set at
address 2812 MiMa RESET TIME. The reset cycle in days is entered at address 2813 MiMa RESETCYCLE,
and the beginning date of the cyclical process, from the time of the setting procedure (in days), is entered at
address 2814 MinMaxRES.START.
Settings
Addr. Parameter Setting Options Default Setting Comments
2811 MinMax cycRESET NO
YES
YES Automatic Cyclic Reset Function
2812 MiMa RESET TIME 0 .. 1439 min 0 min MinMax Reset Timer
2813 MiMa RESETCYCLE 1 .. 365 Days 7 Days MinMax Reset Cycle Period
2814 MinMaxRES.START 1 .. 365 Days 1 Days MinMax Start Reset Cycle in
Information List
No. Information Type of
Informa-
tion
Comments
- ResMinMax IntSP_Ev Reset Minimum and Maximum counter
2.21.6.4
2.21.7
2.21.7.1
2.21.7.2
2.21.7.3
2.21.7.4
Functions
2.21 Auxiliary Functions
SIPROTEC 4, 7SA522, Manual 353
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No. Information Type of
Informa-
tion
Comments
395 >I MinMax Reset SP >I MIN/MAX Buffer Reset
396 >I1 MiMaReset SP >I1 MIN/MAX Buffer Reset
397 >U MiMaReset SP >U MIN/MAX Buffer Reset
398 >UphphMiMaRes SP >Uphph MIN/MAX Buffer Reset
399 >U1 MiMa Reset SP >U1 MIN/MAX Buffer Reset
400 >P MiMa Reset SP >P MIN/MAX Buffer Reset
401 >S MiMa Reset SP >S MIN/MAX Buffer Reset
402 >Q MiMa Reset SP >Q MIN/MAX Buffer Reset
403 >Idmd MiMaReset SP >Idmd MIN/MAX Buffer Reset
404 >Pdmd MiMaReset SP >Pdmd MIN/MAX Buffer Reset
405 >Qdmd MiMaReset SP >Qdmd MIN/MAX Buffer Reset
406 >Sdmd MiMaReset SP >Sdmd MIN/MAX Buffer Reset
407 >Frq MiMa Reset SP >Frq. MIN/MAX Buffer Reset
408 >PF MiMaReset SP >Power Factor MIN/MAX Buffer Reset
837 IL1d Min MVT I L1 Demand Minimum
838 IL1d Max MVT I L1 Demand Maximum
839 IL2d Min MVT I L2 Demand Minimum
840 IL2d Max MVT I L2 Demand Maximum
841 IL3d Min MVT I L3 Demand Minimum
842 IL3d Max MVT I L3 Demand Maximum
843 I1dmdMin MVT I1 (positive sequence) Demand Minimum
844 I1dmdMax MVT I1 (positive sequence) Demand Maximum
845 PdMin= MVT Active Power Demand Minimum
846 PdMax= MVT Active Power Demand Maximum
847 QdMin= MVT Reactive Power Demand Minimum
848 QdMax= MVT Reactive Power Demand Maximum
849 SdMin= MVT Apparent Power Demand Minimum
850 SdMax= MVT Apparent Power Demand Maximum
851 IL1Min= MVT I L1 Minimum
852 IL1Max= MVT I L1 Maximum
853 IL2Min= MVT I L2 Mimimum
854 IL2Max= MVT I L2 Maximum
855 IL3Min= MVT I L3 Minimum
856 IL3Max= MVT I L3 Maximum
857 I1 Min= MVT Positive Sequence Minimum
858 I1 Max= MVT Positive Sequence Maximum
859 UL1EMin= MVT U L1E Minimum
860 UL1EMax= MVT U L1E Maximum
861 UL2EMin= MVT U L2E Minimum
862 UL2EMax= MVT U L2E Maximum
863 UL3EMin= MVT U L3E Minimum
864 UL3EMax= MVT U L3E Maximum
865 UL12Min= MVT U L12 Minimum
867 UL12Max= MVT U L12 Maximum
868 UL23Min= MVT U L23 Minimum
Functions
2.21 Auxiliary Functions
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No. Information Type of
Informa-
tion
Comments
869 UL23Max= MVT U L23 Maximum
870 UL31Min= MVT U L31 Minimum
871 UL31Max= MVT U L31 Maximum
874 U1 Min = MVT U1 (positive sequence) Voltage Minimum
875 U1 Max = MVT U1 (positive sequence) Voltage Maximum
880 SMin= MVT Apparent Power Minimum
881 SMax= MVT Apparent Power Maximum
882 fMin= MVT Frequency Minimum
883 fMax= MVT Frequency Maximum
1040 Pmin Forw= MVT Active Power Minimum Forward
1041 Pmax Forw= MVT Active Power Maximum Forward
1042 Pmin Rev = MVT Active Power Minimum Reverse
1043 Pmax Rev = MVT Active Power Maximum Reverse
1044 Qmin Forw= MVT Reactive Power Minimum Forward
1045 Qmax Forw= MVT Reactive Power Maximum Forward
1046 Qmin Rev = MVT Reactive Power Minimum Reverse
1047 Qmax Rev = MVT Reactive Power Maximum Reverse
1048 PFminForw= MVT Power Factor Minimum Forward
1049 PFmaxForw= MVT Power Factor Maximum Forward
1050 PFmin Rev= MVT Power Factor Minimum Reverse
1051 PFmax Rev= MVT Power Factor Maximum Reverse
10102 3U0min = MVT Min. Zero Sequence Voltage 3U0
10103 3U0max = MVT Max. Zero Sequence Voltage 3U0
Set Points (Measured Values)
SIPROTEC 4 devices allow thresholds (set points) to be set for some measured and metered values. If one of
these set points is reached or is exceeded positively or negatively during operation, the device generates an
alarm which is displayed as an operational indication. This can be configured to LEDs and/or binary outputs,
transferred via the interfaces and interconnected in DIGSI CFC. In addition you can use DIGSI CFC to configure
set points for further measured and metered values and configure these via the DIGSI device matrix.
In contrast to the actual protection functions the limit value monitoring function operates in the background;
therefore it may not pick up if measured values are changed spontaneously in the event of a fault and if
protection functions are picked up. Furthermore, since an indication is only issued when the set point limit is
repeatedly exceeded, the limit value monitoring functions do not react as fast as protection functions trip
signals.
Limit value monitoring
Set points can be set for the following measured and metered values:
•ΙL1dmd>: Exceeding a preset maximum average value in Phase L1.
•ΙL2dmd>: Exceeding a preset maximum average value in Phase L2.
•ΙL3dmd>: Exceeding a preset maximum average value in Phase L3.
•Ι1dmd>: Exceeding a preset maximum average value of the positive sequence system currents.
•|Pdmd|>: Exceeding a preset maximum average active power.
•|Qdmd|>: Exceeding a preset maximum average reactive power.
2.21.8
2.21.8.1
Functions
2.21 Auxiliary Functions
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•Sdmd>: Exceeding a preset maximum average value of the apparent power.
•|cosφ|< falling below a preset power factor.
Setting Notes
Set Points for Measured Values
The settings are entered under MEASUREMENT in the sub-menu SET POINTS (MV) (MV) by overwriting the
existing values.
Information List
No. Information Type of
Informa-
tion
Comments
- IL1dmd> LV Upper setting limit for IL1dmd
- IL2dmd> LV Upper setting limit for IL2dmd
- IL3dmd> LV Upper setting limit for IL3dmd
- I1dmd> LV Upper setting limit for I1dmd
- |Pdmd|> LV Upper setting limit for Pdmd
- |Qdmd|> LV Upper setting limit for Qdmd
- Sdmd> LV Upper setting limit for Sdmd
- PF< LV Lower setting limit for Power Factor
273 SP. IL1 dmd> OUT Set Point Phase L1 dmd>
274 SP. IL2 dmd> OUT Set Point Phase L2 dmd>
275 SP. IL3 dmd> OUT Set Point Phase L3 dmd>
276 SP. I1dmd> OUT Set Point positive sequence I1dmd>
277 SP. |Pdmd|> OUT Set Point |Pdmd|>
278 SP. |Qdmd|> OUT Set Point |Qdmd|>
279 SP. |Sdmd|> OUT Set Point |Sdmd|>
285 cosφ alarm OUT Power factor alarm
Energy
Metered values for active and reactive power are determined in the background by the processor system. They
can be called up at the front of the device, read out via the operating interface using a PC with DIGSI, or trans-
ferred to a central master station via the system interface.
Energy Metering
7SA522 integrates the calculated power as a function of time and then provides the results under the meas-
ured values. The components as listed in Table 2-15 can be read out. The signs of the operating values depend
on the setting at address 1107 P,Q sign (see Section 2.21.4 Measurement under margin heading“Display of
Measured Values”).
Please take into consideration that 7SA522 is, above all, a protection device. The accuracy of the metered
values depends on the instrument transformers (normally protection core) and the device tolerances. The
metering is therefore not suited for tariff purposes.
The counters can be reset to zero or any initial value (see also SIPROTEC 4 System Description).
Table 2-15 Operational metered values
Measured values Primary
Wp+ Active power, output kWh, MWh, GWh
2.21.8.2
2.21.8.3
2.21.9
2.21.9.1
Functions
2.21 Auxiliary Functions
356 SIPROTEC 4, 7SA522, Manual
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Measured values Primary
Wp– Active power, input kWh, MWh, GWh
Wq+ Reactive power, output kVARh, MVARh, GVARh
Wq– Reactive power, input kVARh, MVARh, GVARh
Setting Notes
Retrieving Parameters
The SIPROTEC System Description describes in detail how to read out the statistical counters via the device
front panel or DIGSI. The values are added up in direction of the protected object Provided the direction was
configured as “forward” (address 201).
Information List
No. Information Type of
Informa-
tion
Comments
- Meter res IntSP_Ev Reset meter
888 Wp(puls) PMV Pulsed Energy Wp (active)
889 Wq(puls) PMV Pulsed Energy Wq (reactive)
924 Wp+= MVMV Wp Forward
925 Wq+= MVMV Wq Forward
928 Wp-= MVMV Wp Reverse
929 Wq-= MVMV Wq Reverse
2.21.9.2
2.21.9.3
Functions
2.21 Auxiliary Functions
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Command Processing
The SIPROTEC 4 7SA522 includes a command processing for initiating switching operations in the system.
Control can originate from four command sources:
•Local operation using the keypad on the local user interface of the device,
•Operation using DIGSI,
•Remote operation using a substation automation and control system (e.g. SICAM),
•Automatic functions (e.g. using binary inputs, CFC).
The number of switchgear devices that can be controlled is basically limited by the number of available and
required binary inputs and outputs. For the output of control commands it has to be ensured that all the
required binary inputs and outputs are configured and provided with the correct properties.
If specific interlocking conditions are needed for the execution of commands, the user can program the device
with bay interlocking by means of the user-defined logic functions (CFC). The interlocking conditions of the
system can be injected via the system interface and must be allocated accordingly.
The procedure for switching resources is described in the SIPROTEC 4 System Description under Control of
Switchgear.
Control Authorization
Type of Commands
Commands to the Process
These commands are directly output to the switchgear to change their process state:
•Commands for the operation of circuit breakers (asynchronous; or synchronized through integration of
the synchronism check and closing control function) as well as commands for the control of isolators and
earth switches.
•Step commands, e.g. for raising and lowering transformer taps,
•Setpoint commands with configurable time settings, e.g. to control arc-suppression coils.
Device-internal Commands
These commands do not directly operate binary outputs. They serve for initiating internal functions, communi-
cating the detection of status changes to the device or for acknowledging them.
•Manual override commands for “manual update”of information on process-dependent objects such as
annunciations and switching states, e.g. if the communication with the process is interrupted. Manually
overridden objects are marked as such in the information status and can be displayed accordingly.
•Tagging commands (for “setting”) the information value of internal objects, such as switching authority
(remote/local), parameter changeovers, blocking of transmission and deletion/presetting of metered
values.
•Acknowledgment and resetting commands for setting and resetting internal buffers or data stocks.
•Information status commands to set/delete the additional “Information Status” item of a process object,
such as
– Acquisition blocking,
– Output blocking.
Sequence in the Command Path
Safety mechanisms in the command sequence ensure that a switch command can only be released after a
thorough check of preset criteria has been successfully concluded. Additionally, user-defined interlocking
2.22
2.22.1
2.22.1.1
2.22.1.2
Functions
2.22 Command Processing
358 SIPROTEC 4, 7SA522, Manual
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conditions can be configured separately for each device. The actual execution of the command is also moni-
tored after its release. The entire sequence of a command is described briefly in the following list:
Checking a Command Execution
Please observe the following:
•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 deactivated interlocking
status.
•User configurable interlocking checks:
– Switching authority;
– Device position check (set vs. actual comparison);
– Zone controlled / bay interlocking (logic using CFC);
– System interlocking (centrally via SICAM);
– Double operation (interlocking against parallel switching operation);
– Protection blocking (blocking of switching operations by protection functions);
– Checking the synchronism before a close command.
•Fixed commands:
– Internal process time (software watch dog which checks the time for processing the control action
between initiation of the control and final close of the relay contact);
– Configuration in process (if setting modification is in process, commands are rejected or delayed);
– Equipment present as output;
– 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 is rejected);
– Component hardware malfunction;
– Command in progress (only one command can be processed at a time for each circuit breaker or
switch);
– 1–of–n check (for multiple allocations such as common contact relays or multiple protection
commands configured to the same contact it is checked if a command procedure was already initi-
ated for the output relays concerned or if a protection command is present. Superimposed
commands in the same switching direction are tolerated).
Command Execution Monitoring
The following is monitored:
•Interruption of a command because of a cancel command,
•Running time monitor (feedback monitoring time).
Interlocking
Interlocking can be executed by the user-defined logic (CFC). Switchgear interlocking checks in a SICAM/
SIPROTEC 4 system are normally divided in the following groups:
•System interlocking checked by a central control system (for interbay interlocking),
•Zone controlled/bay interlocking checked in the bay device (for the feeder).
•Cross-bay interlocking via GOOSE messages directly between bay controllers and protection relays (with
rollout of IEC 61850; inter-relay communication by GOOSE messaging is performed via the EN100
module)
2.22.1.3
Functions
2.22 Command Processing
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System interlocking is based on the process image in the central device. Zone controlled/bay interlocking relies
on the object database (feedback information) of the bay unit (here the SIPROTEC 4 relay) as was determined
during configuration (see SIPROTEC 4 System Description).
The extent of the interlocking checks is determined by the configuration and interlocking logic of the relay.
For more information on GOOSE messaging, please refer to the SIPROTEC 4 System Description.
Switching objects that require system interlocking in a central control system are marked by a specific param-
eter inside the bay unit (via configuration matrix).
For all commands, operation with interlocking (normal mode) or without interlocking (test mode) can be
selected:
•For local commands by reprogramming the settings with password check,
•For automatic commands, via command processing by CFC and Deactivated Interlocking Recognition,
•For local/remote commands, using an additional interlocking disable command via PROFIBUS.
Interlocked/non-interlocked Switching
The configurable command checks in the SIPROTEC 4 devices are also called “standard interlocking”. These
checks can be activated via DIGSI (interlocked switching/tagging) or deactivated (non-interlocked).
De-interlocked or non-interlocked switching means that the configured interlock conditions are not tested.
Interlocked switching means that all configured interlocking conditions are checked within the command
processing. If a condition could not be fulfilled, the command will be rejected by an indication with a minus
added to it, e.g. “CO–”, followed by an operation response information. The command is rejected if a
synchronism check is carried out before closing and the conditions for synchronism are not fulfilled.
Table 2-16 shows some types of commands and indications. The indications marked with *) are displayed only
in the event logs on the device display; for DIGSI they appear in spontaneous indications.
Table 2-16 Command types and corresponding indications
Type of Command Control Cause Indication
Control issued Switching CO CO+/–
Manual tagging (positive/negative) Manual tagging MT MT+/–
Information state command, Input blocking Input blocking ST ST+/– *)
Information state command, Output blocking Output blocking ST ST+/– *)
Cancel command Cancel CA CA+/–
The plus sign in the indication is a confirmation of the command execution: The command output has a posi-
tive result, as expected. A minus sign means a negative, i.e. an unexpected result. The command was rejected.
Figure 2-188 shows an example for successful switching of the circuit breaker in the Event Log (command and
feedback).
The check of interlocking can be programmed separately for all switching devices and tags that were set with
a tagging command. Other internal commands such as overriding or abort are not tested, i.e. are executed
independently of the interlockings.
[leistungsschalterbetriebsmeldung-020315-wlk, 1, en_GB]
Figure 2-188 Example of an operational indication for switching circuit breaker (Q0)
Standard Interlocking
The standard interlocking includes the checks for each switchgear which were set during the configuration of
inputs and outputs, see SIPROTEC 4 System Description.
An overview for processing the interlocking conditions in the relay is shown in Figure 2-189.
Functions
2.22 Command Processing
360 SIPROTEC 4, 7SA522, Manual
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[standardveriegelungen-wlk-020802, 1, en_GB]
Figure 2-189 Standard interlockings
1) Source of Command REMOTE includes LOCAL.
(NAH Command using substation controller
FERN Command via telecontrol station to power system management and from power system manage-
ment to the device)
The display shows the configured interlocking reasons. They are marked by letters as explained in Table 2-17 .
Table 2-17 Interlocking Commands
Interlocking Commands Command (abbrevia-
tion)
Display
Control Authority SV S
System Interlocking AV A
Bay Interlocking BI F
SET = ACTUAL (switch direction check) SΙ Ι
Protection Blockage SB B
Figure 2-190 shows all interlocking conditions (which usually appear in the display of the device) for three
switchgear items with the relevant abbreviations explained in Table . Table 2-17 explained abbreviations. All
parameterized interlocking conditions are indicated.
Functions
2.22 Command Processing
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[verriegelungsbed-020315-wlk, 1, en_GB]
Figure 2-190 Example of configured interlocking conditions
Control Logic via CFC
For bay interlocking, a release logic can be created using CFC. Via specific release conditions the information
“released” or “bay interlocked” are available, e.g. object “Release CD Close” and “Release CD Open” with the
information values: ON/OFF).
Information List
No. Information Type of
Informa-
tion
Comments
- ModeREMOTE IntSP Controlmode REMOTE
- Cntrl Auth IntSP Control Authority
- ModeLOCAL IntSP Controlmode LOCAL
Control Device
Information List
No. Information Type of
Informa-
tion
Comments
- Breaker CF_D12 Breaker
- Breaker DP Breaker
- Disc.Swit. CF_D2 Disconnect Switch
- Disc.Swit. DP Disconnect Switch
- EarthSwit CF_D2 Earth Switch
- EarthSwit DP Earth Switch
- Brk Open IntSP Interlocking: Breaker Open
- Brk Close IntSP Interlocking: Breaker Close
- Disc.Open IntSP Interlocking: Disconnect switch Open
- Disc.Close IntSP Interlocking: Disconnect switch Close
- E Sw Open IntSP Interlocking: Earth switch Open
- E Sw Cl. IntSP Interlocking: Earth switch Close
- Q2 Op/Cl CF_D2 Q2 Open/Close
- Q2 Op/Cl DP Q2 Open/Close
- Q9 Op/Cl CF_D2 Q9 Open/Close
- Q9 Op/Cl DP Q9 Open/Close
- Fan ON/OFF CF_D2 Fan ON/OFF
- Fan ON/OFF DP Fan ON/OFF
- UnlockDT IntSP Unlock data transmission via BI
31000 Q0 OpCnt= VI Q0 operationcounter=
31001 Q1 OpCnt= VI Q1 operationcounter=
31002 Q2 OpCnt= VI Q2 operationcounter=
2.22.1.4
2.22.2
2.22.2.1
Functions
2.22 Command Processing
362 SIPROTEC 4, 7SA522, Manual
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No. Information Type of
Informa-
tion
Comments
31008 Q8 OpCnt= VI Q8 operationcounter=
31009 Q9 OpCnt= VI Q9 operationcounter=
Process Data
During the processing of commands, independently of the further allocation and processing of indications,
command and process feedbacks are sent to the indication processing. These indications contain information
on the cause. With the corresponding allocation (configuration) these indications are entered in the event log,
thus serving as a report.
A listing of possible operational indications and their meaning, as well as the command types needed for trip-
ping and closing the switchgear or for raising and lowering transformer taps and detailed information are
described in the SIPROTEC 4 System Description.
Functional Description
Acknowledgement of Commands to the Device Front
All indications with the source of command LOCAL are transformed into a corresponding response and shown
in the display of the device.
Acknowledgement of commands to local/remote/DIGSI
The acknowledgement of indications which relate to commands with the origin “Command Issued = Local/
Remote/DIGSI” are sent back to the initiating point independent of the routing (configuration on the serial
digital interface).
The acknowledgement of commands is therefore not executed by a response indication as it is done with the
local command but by ordinary command and feedback information recording.
Feedback monitoring
Command processing time monitors all commands with feedback. Parallel to the command, a monitoring time
period (command runtime monitoring) is started which checks whether the switchgear has achieved the
desired final state within this period. The monitoring time is stopped as soon as the feedback information
arrives. If no feedback information arrives, a response
Time Limit Expired
appears and the process is
terminated.
Commands and their feedbacks are also recorded as operational indications. Normally the execution of a
command is terminated as soon as the feedback information (FB+) of the relevant switchgear arrives or, in
case of commands without process feedback information, the command output resets.
In the feedback, the plus sign means that a command has been positively completed. The command was as
expected, in other words positive. The "minus" is a negative confirmation and means that the command was
not executed as expected.
Command output/switching relays
The command types needed for tripping and closing of the switchgear or for raising and lowering transformer
taps have been defined during the configuration, see also SIPROTEC 4 System Description.
Information List
No. Information Type of
Informa-
tion
Comments
- >Door open SP >Cabinet door open
- >CB wait SP >CB waiting for Spring charged
2.22.3
2.22.3.1
2.22.3.2
Functions
2.22 Command Processing
SIPROTEC 4, 7SA522, Manual 363
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No. Information Type of
Informa-
tion
Comments
- >Err Mot U SP >Error Motor Voltage
- >ErrCntrlU SP >Error Control Voltage
- >SF6-Loss SP >SF6-Loss
- >Err Meter SP >Error Meter
- >Tx Temp. SP >Transformer Temperature
- >Tx Danger SP >Transformer Danger
Protocol
Information List
No. Information Type of
Informa-
tion
Comments
- SysIntErr. IntSP Error Systeminterface
2.22.4
2.22.4.1
Functions
2.22 Command Processing
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Mounting and Commissioning
This chapter is primarily intended for experienced commissioning engineers. The commissioning engineer
must be familiar with the commissioning of protection and control systems, with the management of power
systems and with the relevant safety rules and guidelines. Under certain circumstances adaptations of the
hardware to the particular power system data may be necessary. The primary tests require the protected
object (line, transformer etc.) to carry load.
3.1 Mounting and Connections 366
3.2 Checking Connections 395
3.3 Commissioning 400
3.4 Final Preparation of the Device 427
3
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Mounting and Connections
General
!
WARNING
Warning of improper transport, storage, installation, and application of the device.
Non-observance can result in death, personal injury or substantial property damage.
²Trouble free and safe use of this device depends on proper transport, storage, installation, and appli-
cation of the device according to the warnings in this instruction manual.
²Of particular importance are the general installation and safety regulations for work in a high-voltage
environment (for example, VDE, IEC, EN, DIN, or other national and international regulations). These
regulations must be observed.
Configuration Information
Prerequisites
For installation and connections the following conditions must be met:
The rated device data has been tested as recommended in the SIPROTEC 4 System Description and their
compliance with the Power System Data is verified.
Connection Variants
General Diagrams are shown in Appendix B Terminal Assignments. Connection examples for current trans-
former and voltage transformer circuits are provided in Appendix C Connection Examples. It must be checked
that the setting of the P.System Data 1, Section 2.1.2.1 Setting Notes, was made in accordance to the
device connections.
Currents
Appendix C Connection Examples shows current transformer connection examples in dependence on network
conditions.
For normal connection, address 220 I4 transformer = In prot. line must be set and furthermore,
address 221 I4/Iph CT = 1.000.
When using separate earth current transformers, address 220 I4 transformer = In prot. line must be
set. The setting value of the address 221 I4/Iph CT may deviate from 1. For information on the calculation,
please refer to section 2.1.2.1 Setting Notes.
Furthermore, examples for the connection of the earth current of a parallel line (for parallel line compensa-
tion) are shown. Address 220 I4 transformer must be set In paral. line here. The setting value
address 221 I4/Iph CT may deviate from 1. For information on the calculation hints, please refer to Section
2.1.2.1 Setting Notes under “Connection of the Currents”.
The other figures show examples for the connection of the earth current of a source transformer. The address
220 I4 transformer must be set IY starpoint here. Hints regarding the factor 221 I4/Iph CT can
also be found in Section 2.1.2.1 Setting Notes.
Voltages
Connection examples for current and voltage transformer circuits are provided in Appendix C Connection
Examples.
For the normal connection the 4th voltage measuring input is not used; correspondingly the address must be
set to 210 U4 transformer = Not connected.
3.1
3.1.1
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3.1 Mounting and Connections
366 SIPROTEC 4, 7SA522, Manual
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For an additional connection of an e-n-winding of a set of voltage transformers, the address 210 U4 trans-
former = Udelta transf. must be set. The setting value of the address Uph / Udelta depends on the
transformation ratio of the e–n-winding. For additional hints, please refer to Section 2.1.2.1 Setting Notes
under “Transformation Ratio”.
In further connection examples also the e–n winding of a set of voltage transformers is connected, in this
case, however of a central set of transformers at a busbar. For more information refer to the previous para-
graph.
Further figures show examples for the additional connection of a different voltage, in this case the busbar
voltage (e.g. for voltage protection or synchronism check). For the voltage protection the address 210 U4
transformer = Ux transformer has to be set, U4 transformer = Usy2 transf. for the synchronism
check. The address 215 Usy1/Usy2 ratio is only then not equal to 1 when feeder transformer and busbar
transformer have a different transformation ratio. .
If there is a power transformer between the set of busbar voltage transformers and the set of feeder voltage
transformers, the phase displacement of the voltage caused by the power transformer must be compensated
for the synchronism check if used. In this case also check the addresses 212 Usy2 connection, 214 φ
Usy2-Usy1 and 215 Usy1/Usy2 ratio. You will find detailed notes and an example in Section
2.1.2.1 Setting Notes under “Voltage connection”.
Binary Inputs and Outputs
The connections to the power plant depend on the possible allocation of the binary inputs and outputs, i.e.
how they are assigned to the power equipment. The preset allocation can be found in the tables in Section
D Default Settings and Protocol-dependent Functions of the Appendix. Check also whether the labelling corre-
sponds to the allocated indication functions.
Changing Setting Group
If binary inputs are used to change setting groups, please observe the following:
•To enable the control of 4 possible setting groups 2 binary inputs have to be available. One binary input
must be set for
>Set Group Bit0
, the other input for
>Set Group Bit1
.
•To control two setting groups, one binary input set for
>Set Group Bit0
is sufficient since the binary
input
>Set Group Bit1
“, which is not assigned, is considered to be not controlled.
•The status of the signals controlling the binary inputs to activate a particular setting group must remain
constant as long as that particular group is to remain active.
The following Table shows the relationship between binary inputs and the setting groups A to D. Principal
connection diagrams for the two binary inputs are illustrated in the following figure. The Figure illustrates an
example in which both Set Group Bits 0 and 1 are configured to be controlled (actuated) when the associated
binary input is energized (high).
Table 3-1 Changing setting groups with binary inputs
Binary Input Active settings group
>Set Group Bit 0 >Set Group Bit 1
Not energized Not energized GroupA
Energized Not energized Group B
Not energized Energized Group C
Energized Energized Group D
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[einstellgruppenumschalt-7sa-ueber-binaere-240702-kn, 1, en_GB]
Figure 3-1 Connection diagram (example) for setting group switching with binary inputs
Trip Circuit Supervision
Please note that two binary inputs or one binary input and one bypass resistor R must be connected in series.
The pick-up threshold of the binary inputs must therefore be substantially below half the rated control DC
voltage.
If two binary inputs are used for the trip circuit supervision, these binary inputs must be isolated, i.o.w. not be
communed with each other or with another binary input.
If one binary input is used, a bypass resistor R must be inserted (see following figure). The resistor R is
connected in series with the second circuit breaker auxiliary contact (Aux2) to allow the detection of a trip
circuit failure even when circuit breaker auxiliary contact (Aux1) is open and the command relay has dropped
out. The value of this resistor must be such that in the circuit breaker open condition (Aux1 is open and Aux2
is closed) the circuit breaker trip coil (TC) is no longer picked up and binary input (BI1) is still picked up if the
command relay contact is open.
[prinzip-ausloesekrueb-1-be-wlk-010802, 1, en_GB]
Figure 3-2 Principle of the trip circuit supervision with one binary input
TR Trip relay contact
CB Circuit breaker
TC Circuit breaker trip coil
Aux1 Circuit breaker auxiliary contact (NO contact)
Aux2 Circuit breaker auxiliary contact (NC contact)
U-CTR Control voltage for trip circuit
U-BI Input voltage of binary input
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R Bypass resistor
UR Voltage across the bypass resistor
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 R should be selected:
[formel-mittelwert-r-260602-kn, 1, en_GB]
In order that the minimum voltage for controlling the binary input is ensured, Rmax is derived as::
[formel-rmax-260602-kn, 1, en_GB]
To keep the circuit breaker trip coil not energized in the above case,Rmin is derived as:
[formel-rmin-260602-kn, 1, en_GB]
ΙBI (HIGH) Constant current with activated BI ( = 1.8 mA)
UBI min Minimum control voltage for BI
19 V for delivery setting for nominal voltages of 24 V/48 V/60 V;
88 V for delivery setting for nominal voltages of 110 V/125 V/220 V/250 V;
176 Vfor delivery setting for nominal voltages of 220 V/250 V
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
If the calculation results that Rmax < Rmin then the calculation must be repeated, with the next lowest switching
threshold UBE min and this threshold must be implemented in the relay using plug-in jumpers (see Section
“Hardware Modifications”).
For the power consumption of the resistance the following applies:
[formel-leistungvon-r-260602-kn, 1, en_GB]
Example:
ΙBI (HIGH) 1.8 mA (vom SIPROTEC 4 7SA522)
UBE min 19 V for delivery setting for nominal voltages 24 V/48 V/60 V
(from the device 7SA522);
88 V for delivery setting for nominal voltages 110 V/125 V/220 V/250 V
(from the device 7SA522);
176 V for delivery setting for nominal voltages 220 V/250 V
(from the devicet 7SA522)
UST 110 V (system / trip circuit)
RCBTC 500 Ω (system / trip circuit)
ULSS (LOW) 2 V (system / trip circuit)
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[beispiel-rmax-150502-kn, 1, en_GB]
[beispiel-rmin-150502-kn, 1, en_GB]
[beispiel-rmittelwert-150502-kn, 1, en_GB]
The closest standard value of 39 kΩ is selected; the power is:
[beispiel-leistungvonr-150502-kn, 1, en_GB]
Hardware Modifications
General
A subsequent adaptation of hardware to the power system conditions can be necessary for example with
regard to the control voltage for binary inputs or termination of bus-capable interfaces. Follow the procedure
described in this section, whenever hardware modifications are carried out.
Auxiliary Voltage
There are different power supply voltage ranges for the auxiliary voltage (refer to the Ordering Information in
Appendix A Ordering Information and AccessoriesOrdering Information). The power supplies of the variants
for 60/110/125 VDC and 110/125/220 VDC, 115 VAC are largely interchangeable by modifying the position of
the jumpers. The assignment of these jumpers to the nominal voltage ranges and the spatial layout on the PCB
are described further below at „Input/Output Board C-I/O-1 and C-I/O-10“. When the relays are delivered, these
jumpers are set according to the name-plate sticker. Generally, they need not be altered.
Life Status contact
The life contact of the device is a changeover contact from which either the NC contact or the NO contact can
be connected to the device terminals via a plug-in jumper (X40). The assignment of the jumper to the contact
type and the spatial arrangement of the jumper are described in the following section under the margin
heading „Input/Output Board(s) C-I/O-1 and C-I/O-10“.
Nominal Currents
The input transformers of the devices are set to a nominal current of 1 A or 5 A with jumpers. The position of
jumpers is determined according to the name-plate sticker. The assignment of the jumpers to the nominal
current and the spatial layout of the jumpers are described in the following section under the margin heading
„Board C-I/O-2“. All jumpers must be set for one nominal current, i.e. one jumper (X61 to X64) for each input
transformer and additionally the common jumper X60.
i
i
NOTE
If nominal current ratings are changed exceptionally, then the new ratings must be registered in addresses
206 CT SECONDARY in the power system data (see Section 2.1.2.1 Setting Notes).
3.1.2
3.1.2.1
Mounting and Commissioning
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Control Voltage for Binary Inputs
When the device is delivered from the factory, the binary inputs are set to operate with a voltage that corre-
sponds to the rated DC voltage of the power supply. If the rated values differ from the power system control
voltage, it may be necessary to change the switching threshold of the binary inputs.
A jumper position is changed to adjust the pickup voltage of a binary input. The assignment of the jumpers to
the binary inputs and their physical arrangement are described below at margin headings “Input/Output
Board(s) C-I/O-1 and C-I/O-10” and “Input/Output Board(s) C-I/O-7”.
i
i
NOTE
If binary inputs are used for trip circuit supervision, note that two binary inputs (or a binary input and an
equivalent resistor) are connected in series. The switching threshold must lie clearly below one half of the
nominal control voltage.
Type of Contact for Output Relays
Some input/output boards can contain relays whose contacts can be set to have normally closed or normally
open contacts. To do so, you have to move a jumper. The following sections under “Switching Elements on
Printed Circuit Boards”describe for which relays on which boards this is the case.
Exchanging Interfaces
The serial interfaces can only be replaced in devices designed for panel flush and cubicle mounting and for
surface-mounted devices with a detached operator panel. The following section under margin heading
“Replacing Interface Modules” describes which interfaces can be exchanged, and how this is done.
Terminating of Bus-capable Interfaces
If the device is equipped with a serial RS485 interface or PROFIBUS, they must be terminated with resistors at
the last device on the bus to ensure reliable data transmission. On the interface board, termination resistors
are provided that can be connected via jumpers. The spatial arrangement of the jumpers on the PCB on the
interface modules is described at margin headings “RS485 Interface” and “Profibus Interface”. Both jumpers
must always be plugged in identically.
The termination resistors are disabled on delivery.
Spare Parts
Spare parts can include the backup battery that maintains the data in the battery-buffered RAM when the
voltage supply fails, and the miniature fuse of the internal power supply. Their spatial arrangement is shown
in the figure of the processor module. The ratings of the fuse are printed on the board next to the fuse. When
replacing the fuse, please observe the guidelines given in the SIPROTEC 4 System Description in the chapter
“Maintenance” and “Corrective Maintenance”.
Disassembly
Work on the Printed Circuit Boards
i
i
NOTE
It is assumed for the following steps that the device is not operative.
3.1.2.2
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!
CAUTION
Caution when changing jumper settings that affect nominal values of the device:
As a consequence, the ordering number (MLFB) and the ratings on the name plate no longer match
the actual device properties.
²Where such changes are necessary in exceptional cases, they MUST be marked clearly and visibly on
the device. Self-adhesive stickers are available that can be used as supplementary name plate.
To perform work on the printed circuit boards, such as checking or moving switching elements or exchanging
modules, proceed as follows:
•Prepare your workplace: provide a suitable pad for electrostatically sensitive devices (ESD). Also the
following tools are required:
– screwdriver with a 5 to 6 mm wide tip,
– a crosstip screwdriver for Pz size 1,
– a 5 mm socket wrench.
•Unfasten the screw-posts of the D-subminiature connectors on the back panel at location “A”. This step is
not necessary if the device is designed for surface mounting.
•If the device features interfaces next to the interfaces at location “A”, the screws located diagonally to the
interfaces must be removed. This is not necessary if the device is designed for surface mounting.
•Remove the covers on the front panel and loosen the screws which can then be accessed.
•Remove the front cover and place it carefully to the side. For device versions with a detached operator
panel, the front cover can be lifted off directly after the screws have been released.
Work on the Plug Connectors
!
CAUTION
Mind electrostatic discharges:
Non-observance can result in minor personal injury or property damage.
²When handling plug connectors, electrostatic discharges may emerge. These must be avoided by
previously touching an earthed metal surface
²Do not plug or unplug interface connectors under voltage!
The order of the boards for housing size 1/2 is shown in Figure 3-3 and that for housing size 1/1 in Figure 3-4.
•Disconnect the plug connector of the ribbon cable between the front cover and the processor board C-
CPU- 1 (No. 1 in Figure 3-3) at the front cover side. Press the top latch of the plug connector up and the
bottom latch down so that the plug connector of the ribbon cable is pressed out.
•Disconnect the ribbon cables between the processor board C-CPU-1 (No. 1 in Figure 3-4) and the input/
output board I/O (according to order variant No. 2 to No. 5 in Figure 3-4).
•Remove the boards and put them on the earth mat to protect them from ESD damage. In the case of the
device variant for panel surface mounting, please be aware of the fact that a certain amount of force is
required in order to remove the C-CPU-1 board due to the existing plug connector.
•Check the jumpers according to Figures Figure 3-5 to Figure 3-8, Figure 3-12 to Figure 3-14 and the
following information. Change or remove the jumpers if necessary.
Mounting and Commissioning
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372 SIPROTEC 4, 7SA522, Manual
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[frontansicht-geh-einhalb-o-frontkappe7sa522-251102-wlk, 1, en_GB]
Figure 3-3 Front view with housing size 1/2 after removal of the front cover (simplified and scaled down)
Mounting and Commissioning
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SIPROTEC 4, 7SA522, Manual 373
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[frontansicht-geh-einein-o-frontkappe7sa522-251102-wlk, 1, en_GB]
Figure 3-4 Front view with housing size 1/1 after removal of the front cover (simplified and scaled down)
Switching Elements on Printed Circuit Boards
Input/Output Board(s) C-I/O-1 and C-I/O-10
The layout of the PCB for the input/output board C-I/O-1 is shown in Figure 3-5, that of the input/output board
C-I/O-10 up to release 7SA522 .../EE in Figure 3-6 and that of input/output board C-I/O-10 for release
7SA522 .../FF and higher in Figure 3-7.
The power supply is situated
•On the input/output board C-I/O-1 (No. 2 in Figure 3-3, slot 19) for housing size 1/2,
•On the input/output board C-I/O-1 (No. 2 in Figure 3-4, slot 33 links) for housing size 1/1.
The preset nominal voltage of the integrated power supply is checked according to Table 3-2, the quiescent
state of the life contact is checked according to Table 3-3.
3.1.2.3
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Table 3-2 Jumper settings of the nominal voltage of the integrated Power Supply of the input/output
board C-I/O-1.
Jumper Nominal Voltage
DC 60/110/125 V DC 110/125/220/250 V AC 115 V DC 24/48 V
X51 1-2 2-3 Jumpers X51 to
X52 1-2 and 3-4
2-3 X53 are not
used
X52 1-2 and 3-4 2-3
X53 1-2 2-3
interchangeable cannot be
changed
Fuse T2H250V T4H250V
Table 3-3 Jumper position of the quiescent state of the Life contact on the C-I/O-1 input/output board
Jumper Open in quiescent state
(NO)
Closed in quiescent state
(NC)
Factory Setting
X40 1-2 2-3 2-3
Depending on the device version the contacts of some binary outputs can be changed from normally open to
normally closed (see Appendix, under section B Terminal Assignments).
•In versions 7SA522*-*D/H/M ((housing size 1/1 with 32 binary outputs) this is valid for the binary outputs
BO16 and BO24 (Figure 3-4, slot 19 left and right);
•In versions 7SA522*-*C/G/L ((housing size 1/1 with 24 binary outputs) this is valid for the binary output
BO16 (Figure 3-4, slot 19 right);
•In versions 7SA522*-*P/R/T ((housing size 1/1 with 32 binary outputs and command acceleration) this is
valid for the binary output BO24 (Figure 3-4, slot 19 left);
•In version 7SA522*-*U ((housing size 1/1 with 44 binary outputs and command acceleration) this is valid
for the binary output BO16 (Figure 3-4, slot 19 right).
The following table shows the jumper settings for the contact mode.
Table 3-4 Jumper settings for contact mode of the binary outputs BO16 and BO24 on the input/output
board C–I/O-1
Device
7SA522*-*
Module for Module Open in quies-
cent state (NO)
Closed in quiescent state
(NC)
Factory Setting
D/H/M Slot 19 left side BO 16 X40 1-2 2-3 1-2
Slot 19 right side BO 24 X40 1-2 2-3 1-2
C/G/L/U Slot 19 right side BO 16 X40 1-2 2-3 1-2
P/R/T Slot 19 left side BO 24 X40 1-2 2-3 1-2
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SIPROTEC 4, 7SA522, Manual 375
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[ein-ausgabebgr-c-io-1-160502-wlk, 1, en_GB]
Figure 3-5 Input/output board C-I/O-1 with representation of the jumper settings required for checking
configuration settings
Mounting and Commissioning
3.1 Mounting and Connections
376 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[ein-ausgabebgr-c-io-10-240702-kn, 1, en_GB]
Figure 3-6 Input/output board C-I/O-10 up to release 7SA522 .../EE with representation of the jumper
settings required for checking configuration settings
Check of the control voltages of the binary inputs:
BI1 to BI8 (with housing size 1/2) according to Table 3-5,
BI1 to BI24 (with housing size 1/1 depending on the version) according to Table 3-6.
Table 3-5 Jumper settings of the Control Voltages of the binary inputs BI1 to BI8 on the input/output
board C-I/O-1 with housing size 1/2
Binary Inputs slot
19
Jumper 19 V Threshold1) 88 V Threshold5) 176 V Threshold9)
BI1 X21/X22 L M H
BI2 X23/X24 L M H
BI3 X25/X26 L M H
BI4 X27/X28 L M H
BI5 X29/X30 L M H
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Binary Inputs slot
19
Jumper 19 V Threshold1) 88 V Threshold5) 176 V Threshold9)
BI6 X31/X32 L M H
BI7 X33/X34 L M H
BI8 X35/X36 L M H
1) Factory settings for devices with power supply voltages of DC 24 to 125 V
2) Factory settings for devices with power supply voltages of DC 110 to 250 V and AC 115 V
3) Factory settings for devices with power supply voltages of DC 220 to 250 V and AC 115 V
Table 3-6 Jumper settings of the Control Voltages of the binary inputs BI1 to BI24 on the input/output
board C-I/O-1 or C-I/O-10 with housing size 1/1
Binäreingänge Jumper 19 V
Threshold1)
88 V
Threshold5)
176 V
Threshold9)
Slot 33 left
side
Slot 19 right
side
Slot 19 left
side
BI1 BI9 BI17 X21/X22 L M H
BI2 BI10 BI18 X23/X24 L M H
BI3 BI11 BI19 X25/X26 L M H
BI4 BI12 BI20 X27/X28 L M H
BI5 BI13 BI21 X29/X30 L M H
BI6 BI14 BI22 X31/X32 L M H
BI7 BI15 BI23 X33/X34 L M H
BI8 BI16 BI24 X35/X36 L M H
1) Factory settings for devices with power supply voltages of DC 24 to 125 V
2) Factory settings for devices with power supply voltages of DC 110 to 250 V and AC 115 V
3) Factory settings for devices with power supply voltages of DC 220 to 250 V and AC 115 V
Table 3-7 Jumper settings of the PCB Address of the input/output board C-I/O-1 or C-I/O-10 with housing
size 1/1
Jumper Insert location
Slot 19 left side Slot 19 right side
X71 H L
X72 L L
X73 H H
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Input/Output Board C-I/O-10 Release 7SA522 .../FF
[ein-ausgabebgr-c-io-10-080904-oz, 1, en_GB]
Figure 3-7 Input/output board C-I/O-10 release 7SA522 .../FF or higher, with representation of jumper
settings required for checking configuration settings
Table 3-8 Jumper settings of the Control Voltages of the binary inputs BI1 to BI24 on the input/output
board C-I/O-10 for release 7SA522 .../FF and higher with housing size 1/1
Binary Inputs Jumper 19 V
Threshold1)
88 V
Threshold5)
176 V
Threshold9)
Slot 33 left
side
Slot 19 right
side
Slot 19 left
side
BI1 BI9 BI17 X21 L M H
BI2 BI10 BI18 X23 L M H
BI3 BI11 BI19 X25 L M H
BI4 BI12 BI20 X27 L M H
BI5 BI13 BI21 X29 L M H
BI6 BI14 BI22 X31 L M H
BI7 BI15 BI23 X33 L M H
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Binary Inputs Jumper 19 V
Threshold1)
88 V
Threshold5)
176 V
Threshold9)
Slot 33 left
side
Slot 19 right
side
Slot 19 left
side
BI8 BI16 BI24 X35 L M H
1) Factory settings for devices with power supply voltages of DC 24 to 125 V
2) Factory settings for devices with power supply voltages of DC 110 to 250 V and AC 115 V
3) Factory settings for devices with power supply voltages of DC 220 to 250 V and AC 115 V
Table 3-9 Jumper setting of the PCB address of the input/output board C-I/O-10 for release 7SA522 .../FF
and higher with housing size 1/1
Jumper Insert location
Slot 19 left side Slot 19 right side
X71 H L
X72 L L
X73 H H
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Input/Output Board C-I/O-2 up to Release 7SA522 .../EE
There are two different releases of the input/output board C-I/O-2 available. For devices up to the release
7SA522.../EE the layout of the printed circuit board is shown in Figure 3-8, for devices of release 7SA522.../FF
and higher, it is shown in Figure 3-9.
[ein-ausgabebgr-c-io-2-240702-kn, 1, en_GB]
Figure 3-8 Input/output board C-I/O-2 up to release 7SA522.../EE with representation of the jumper
settings required for checking configuration settings
The contact type of binary output BO13 can be changed from normally open to normally closed (see also over-
view diagrams in section B Terminal Assignments):
with housing size 1/2: No. 3 in Figure 3-3, slot 33,
with housing size 1/1: No. 3 in Figure 3-4, slot 33 right.
Table 3-10 Jumper setting for Contact Type of binary output BO13
Jumper Open in quiescent state (NO) Closed in quiescent state (NC) Factory Setting
X41 1-2 2-3 1-2
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The set nominal current of the current input transformers are to be checked on the input/output board C-I/O-2.
All jumpers must be set for one nominal current, i.e. respectively one jumper (X61 to X64) for each input
transformer and additionally the common jumper X60. But: In the version with sensitive earth fault current
input (input transformer T8) there is no jumper X64.
Jumpers X71, X72 and X73 on the input/output board C-I/O-2 are used to set the bus address and must not be
changed. The following table shows the preset jumper positions.
Mounting location:
with housing size 1/2: No. 3 in Figure 3-3, slot 33,
with housing size 1/1: No. 3 in Figure 3-4, slot 33 right.
Table 3-11 Jumper settings of the PCB Address of the input/output board C-I/O-2
Jumper Factory Setting
X71 1-2 (H)
X72 1-2 (H)
X73 2-3 (L)
This board is available in two configuration variants:
•Variant with normal earth fault detection, PCB number C53207-A324-B50-*
•Variant with sensitive earth fault detection, PCB number C53207-A324-B60-*
A table imprinted on the printed-circuit board indicates the respective PCB number.
The nominal current or measuring range settings are checked on the input/output board C-I/O-2.
Mounting and Commissioning
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[ein-ausgabebgr-c-io-2-ab-ausgabe7-251103-oz, 1, en_GB]
Figure 3-9 Input/output board C-I/O-2 release 7SA522**.../FF or higher, with representation of the
jumper settings required for checking configuration settings
Table 3-12 Jumper setting for Nominal Current or Measuring Range
Jumper Nominal current 1 A
Measuring range 100 A
Nominal current 5 A
Measuring range 500 A
X51 1-2 1-2
X60 1-2 2-3
X61 3-5 4-5
X62 3-5 4-5
X63 3-5 4-5
X641) 3-5 4-5
1) Not for variant with sensitive earth fault detection
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Contacts of relays for binary outputs BO13, BO14 and BO15 can be configured as normally open or normally
closed (see also General Diagrams in the Appendix).
Table 3-13 Jumper setting for the Contact Type of the relays for BO13, BO14 and BO15
für Jumper ROpen in quiescent
state (NO)1)
Closed in quiescent state
(NC)
BO13 X41 1-2 2-3
BO14 X42 1-2 2-3
BO15 X43 1-2 2-3
1) Factory setting
The relays for the binary outputs BO8 to BO12 can be connected to common potential, or configured individu-
ally for BO8, BO11 and BO12 (BO9 and BO10 are without function in this context) (see also General Diagrams
in the Appendix).
Table 3-14 Jumper settings for the configuration of the Common Potential of BO8 through BA11 or for
configuration of BO8, BO11 and BO12 as single relays
Jumper BO8 through BO12
connected to
common potential 1)
BO8, BO11, BO12 configured as single
relays (BO9, BO10 without function)
X80 1-2, 3-4 2-3, 4-5
X81 1-2, 3-4 2-3, 4-5
X82 2-3 1-2
1) Factory setting
Jumpers X71, X72 and X73 serve for setting the bus address. Their position must not be changed. The
following table shows the preset jumper positions.
Table 3-15 Jumper setting of the Module Addresses of the input/output board C-I/O-2
Jumper Factory Setting
X71 1-2 (H)
X72 1-2 (H)
X73 2-3 (L)
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Input/output boardC-I/O-7
The PCB layout for the input/output board C-I/O-7 is shown in the following figure.
[ein-ausgabebgr-c-io-7-110303-st, 1, en_GB]
Figure 3-10 Input/output board C-I/O-7 with representation of the jumper settings required for checking
the configuration settings
Depending on the device version the contacts of some binary outputs can be changed from normally open to
normally closed (see Appendix, under Section B Terminal Assignments).
•In version 7SA522*-*U ((housing size 1/1 with 44 binary outputs) this is valid for the binary outputs BO30,
BO31, BO41 and BO42 (Figure 3-4, slot 19 left).
The following table shows the jumper settings for the contact mode.
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Table 3-16 Jumper setting for the Contact Mode of the relays for BO30, BO31, BO41 and BO42 on the
input/output board C-I/O-7 with housing size 1/1
Device
7SA522*-*
Circuit Board for Jumper Open in quiescent
state (NO)
Closed in quiescent state
(NC)
Factory Setting
U
Platz 19
links
BO30 X41 1-2 2-3 1-2
BO31 X42 1-2 2-3 1-2
BO41 X43 1-2 2-3 1-2
BO42 X44 1-2 2-3 1-2
Depending on the jumper setting there are 5 or 6 inputs available on this board. 6 binary inputs (BI17-BI22),
connected to common potential, or 5 binary inputs divided into 1 x 2 binary inputs (BI17-BI18), connected to
common potential and 1 x 3 binary inputs (BI19-BI21), connected to common potential. Please note that the
relationship between jumpers X110, X111 and X29 must always be correct.
Table 3-17 Number of inputs
Jumper 5 Inputs
1 x 2 and 1 x 3 Binary Inputs,
Connected to Common Potential
6 Inputs
1 x 6 Binary Inputs, Connected
to Common Potential
Factory Setting
X110 1-2 2-3 2-3
X111 2-3 1-2 1-2
X29 2-3 1-2 1-2
Check of the control voltages of the binary inputs:
BI17 to BI22 (with housing size 1/1 slot 19 left) according to Table 3-6.
Table 3-18 Jumper settings of Pickup Voltages of the binary inputs BI17 to BI22 on the input/output
board C-I/O-7
Binary Inputs Jumper 19 V Threshold1) 88 V Threshold5) 176 V Threshold9)
BI17 X21 L M H
BI18 X22 L M H
BI19 X23 L M H
BI20 X24 L M H
BI21 X25 L M H
BI22 X26 L M H
1) Factory settings for devices with power supply voltages of DC 24 to 125 V
2) Factory settings for devices with power supply voltages of DC 110 to 250 V and AC 115 V
3) Factory settings for devices with power supply voltages of DC 220 to 250 V and AC 115 V
Jumpers X71, X72 and X73 on the input/output board C-I/O-7 are used to set the bus address and must not be
changed. The following table lists the jumper presettings.
The mounting location of the board is shown in Figure 3-4.
Table 3-19 Jumper settings of the Board Address of the input/output board C-I/O-7 (for housing size 1/1
slot 19 left)
Jumper Mounting Location 19
A0 X71 1-2 (H)
A1 X72 2-3 (L)
A2 X73 1-2 (H)
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Schnittstellenmodule
Austausch von Schnittstellenmodulen
Die Schnittstellenmodule befinden sich auf der Prozessorbaugruppe C-CPU-1. Figure 3-11 zeigt die Ansicht auf
die Leiterplatte mit derAnordnung der Module.
[proz-bgr-ccpu1-m-schnittstmods-wlk-261102, 1, en_GB]
Figure 3-11 Prozessorbaugruppe C-CPU-1 mit Schnittstellenmodulen
Bitte beachten Sie:
•Ein Austausch der Schnittstellenmodule ist nur bei Geräten im Einbaugehäuse möglich. Geräte im
Aufbaugehäuse können nur im Werk umgerüstet werden.
•Es können nur Schnittstellenmodule eingesetzt werden, mit denen das Gerät auch entsprechend dem
Bestellschlüssel werkseitig bestellbar ist (siehe auch Anhang A Ordering Information and Accesso-
riesOrdering Information).
•Die Terminierung der busfähigen Schnittstellen gemäß Randtitel “RS485-Schnittstelle” muss ggf. sicher-
gestellt werden.
3.1.2.4
Mounting and Commissioning
3.1 Mounting and Connections
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Table 3-20 Austauschmodule für Schnittstellen
Schnittstelle Einbauplatz/Port Austauschmodul
Systemschnittstelle B nur Schnittstellenmodule mit denen
das Gerät entsprechend dem Bestells-
chlüssel werkseitig bestellbar ist (siehe
Anhang A Ordering Information and
AccessoriesOrdering Information)
Serviceschnittstelle C
Wirkschnittstelle 1 D FO5, FO6;
FO17 to FO19, FO30
Wirkschnittstelle 2 E
Die Bestellnummern der Austauschmodule finden Sie im Anhang unter Abschnitt A Ordering Information and
AccessoriesOrdering Information Zubehör.
RS232-Interface
Interface RS232 can be modified to interface RS485 and vice versa (see Figure 3-12 and Figure 3-13).
Figure 3-11 shows the C-CPU-1 PCB with the layout of the modules.
The following figure shows the location of the jumpers of interface RS232 on the interface module.
Surface-mounted devices with fibre optics connection have their fibre optics module fitted in the console
housing on the case bottom. The fibre optics module is controlled via an RS232 interface module at the associ-
ated CPU interface slot. For this application type the jumpers X12 and X13 on the RS232 module are plugged
in position 2-3.
[steckbruecken-rs232-020313-kn, 1, en_GB]
Figure 3-12 Location of the jumpers for configuration of RS232
Terminating resistors are not required for RS232. They are disconnected.
Jumper X11 is used to activate the flow control which is important for the modem communication.
Table 3-21 Jumper setting for CTS (Clear To Send; flow control) on the interface module
Jumper /CTS from Interface RS232 /CTS controlled by /RTS
X11 1-2 2-3 1)
1) Factory Setting
Jumper setting 2-3: The connection to the modem is usually established with a star coupler or fibre-optic
converter. Therefore the modem control signals according to RS232 standard DIN 66020 are not available.
Modem signals are not required since the connection to the SIPROTEC 4 devices is always operated in the half-
duplex mode. Please use the connection cable with order number 7XV5100-4.
Jumper setting 1-2: This setting makes the modem signals available, i. e. for a direct RS232-connection
between the SIPROTEC 4 device and the modem this setting can be selected optionally. We recommend to use
a standard RS232 modem connection cable (converter 9-pin to 25-pin).
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i
i
NOTE
For a direct connection to DIGSI with interface RS232 jumper X11 must be plugged in position 2-3.
RS485 Interface
The following figure shows the location of the jumpers of interface RS485 on the interface module.
Interface RS485 can be modified to Figure 3-12 interface RS232 and vice versa.
[steckbruecken-rs485-020313-kn, 1, en_GB]
Figure 3-13 Position of terminating resistors and the plug-in jumpers for configuration of the RS485 inter-
face
Profibus/DNP Interface
[steckbruecken-profibus-020313-kn, 1, en_GB]
Figure 3-14 Location of the jumpers for configuring the terminating resistors of the active electrical
module (PROFIBUS and DNP 3.0 interface)
EN100 Ethernet Module (IEC 61850)
SIPROTEC, 7SA6, Manual C53000-G1176-C156-7, Release date 02.2011 476 Profibus/DNP Interface Figure
3-19 Location of the jumpers for configuring the terminating resistors of the active electrical module
(PROFIBUS and DNP 3.0 interface) EN100 Ethernet Module (IEC 61850)
Terminierung
Bei busfähigen Schnittstellen ist beim jeweils letzten Gerät am Bus eine Terminierung notwendig, d.h. es
müssen Abschlusswiderstände zugeschaltet werden. Beim 7SA522 betrifft dies die Varianten mit RS485- oder
Profibus-/DNP-Schnittstellen.
Die Abschlusswiderstände befinden sich auf dem RS485- bzw. Profibus-Schnittstellenmodul, welches sich auf
der Prozessorbaugruppe C-CPU-1 befindet (lfd. Nr 1 in Figure 3-3 bis Figure 3-4).
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Figure 3-11 zeigt die Ansicht auf die Leiterplatte der C-CPU-1 mit der Anordnung der Module.
Das Modul mit Konfiguration als RS485-Schnittstelle ist in Figure 3-13, das Modul für die Profibus-Schnittstelle
in Figure 3-14 dargestellt.
Es müssen stets beide Brücken für die Konfiguration der Abschlusswiderstände eines Moduls gleichsinnig
gesteckt sein.
Im Lieferzustand sind die Brücken so gesteckt, dass die Abschlusswiderstände ausgeschaltet sind.
Eine Realisierung von Abschlusswiderständen kann auch extern erfolgen (z.B. am Anschlussmodul), wie in
Figure 3-15 dargestellt. In diesem Fall müssen die auf dem RS485- bzw. Profibus-Schnittstellenmodul befindli-
chen Abschlusswiderstände ausgeschaltet sein.
[externe-terminierung-020313-kn, 1, en_GB]
Figure 3-15 Terminierung der RS485-Schnittstelle (extern)
Reassembly
The assembly of the device is done in the following steps:
•Insert the boards carefully in the housing. The mounting locations of the boards are shown in Figure 3-3
and Figure 3-4. For the model of the device designed for surface mounting, use the metal lever to insert
the C-CPU- 1 board. Installation is easier with the lever.
•First plug in the plug connectors of the ribbon cable onto the input/output boards I/O and then onto the
processor board C-CPU-1. Be careful that no connector pins are bent! Don't use force!
•Connect the plug connectors of the ribbon cable between processor board C-CPU-1 and the front panel to
the front panel plug connector.
•Press plug connector interlocks together.
•Replace the front panel and screw it again tightly to the housing.
•Replace the covers again.
•Re-fasten the interfaces on the rear of the device housing. This is not necessary if the device is designed
for surface mounting.
Mounting
Panel Flush Mounting
Depending on the version, the device housing can be 1/2 or 1/1. For housing size 1/2 (Figure 3-16) there are 4
covers and 4 securing holes, for housing size 1/1 (Figure 3-17) there are 6 covers and 6 securing holes.
•Remove the 4 covers at the corners of the front cover, for housing size2/3 and 1/1 the 2 covers located
centrally at the top and bottom also have to be removed. The 4 or 6 elongated holes in the mounting
bracket thus become accessible.
•Insert the device into the panel cut-out and fasten it with four or six screws. For dimensions refer to
Section 4.23 Dimensions.
•Put the four or six covers back into place.
3.1.2.5
3.1.3
3.1.3.1
Mounting and Commissioning
3.1 Mounting and Connections
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•Connect a solid low-impedance protective earthing at the rear of the device with at least one M4 screw.
The cross-section of the earth wire must be equal to the cross-section of any other control conductor
connected to the device. The cross-section of the earth wire must be at least 2.5 mm2.
•Connections are realized via the plug terminals or screw terminals on the rear side of the device
according to the circuit diagram.
When using screwed connections with forked lugs or direct connection, before inserting wires the screws
must be tightened so that the screw heads are flush with the outer edge of the connection block.
A ring lug must be centred in the connection chamber, in such a way that the screw thread fits in the
hole of the lug.
The SIPROTEC 4 System Description has pertinent information regarding wire size, lugs, bending radii,
etc. Installation notes are also given in the brief reference booklet attached to the device.
[schalttafeleinbau-gehaeuse-4zeilig-display-halb-st-040403, 1, en_GB]
Figure 3-16 Panel flush mounting of a device (housing size 1/2)
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[schalttafeleinbau-gehaeuse-4zeilig-display-ein-st-040403, 1, en_GB]
Figure 3-17 Panel flush mounting of a device (housing size 1/1)
Rack and Cubicle Mounting
To install the device in a rack or cubicle, a pair of mounting rails; one for top, one for bottom are required. The
ordering codes are stated in Appendix, Section A Ordering Information and AccessoriesOrdering Information.
For housing size 1/2 (Figure 3-18) there are 4 covers and 4 securing holes, for housing size 1/1 (Figure 3-19)
there are 6 covers and 6 securing holes.
•Screw on loosely the two angle brackets in the rack or cabinet, each with four screws.
•Remove the 4 covers at the corners of the front cover, for housing size2/3 and 1/1 the 2 covers located
centrally at the top and bottom also have to be removed. The 4 or 6 elongated holes in the mounting
bracket can thus be accessed.
•Fasten the device to the mounting brackets with four or six screws.
•Put the four or six covers back into place.
•Tighten fast the eight screws of the angle brackets in the rack or cabinet.
•Connect a solid low-impedance protective earthing at the rear of the device with at least one M4 screw.
The cross-section of the earth wire must be equal to the cross-section of any other control conductor
connected to the device. The cross-section of the earth wire must be at least 2.5 mm2.
•Make the connections on the device's back panel using the plug or screw terminals as shown in the
wiring diagram.
For screw connections with forked lugs or direct connection, before inserting wires the screws must be
tightened so that the screw heads are flush with the outer edge of the connection block.
A ring lug must be centred in the connection chamber so that the screw thread fits in the hole of the lug.
The SIPROTEC 4 System Description has pertinent information regarding wire size, lugs, bending radii,
etc. Installation notes are also given in the brief reference booklet attached to the device.
3.1.3.2
Mounting and Commissioning
3.1 Mounting and Connections
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[montage-gehaeuse-4zeilig-display-halb-st-040403, 1, en_GB]
Figure 3-18 Installing a device in a rack or cubicle (housing size 1/2)
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[montage-gehaeuse-4zeilig-display-ein-st-040403, 1, en_GB]
Figure 3-19 Installing a device in a rack or cubicle (housing size 1/1)
Panel Mounting
For mounting proceed as follows:
•Secure the device to the panel with four screws. For dimensions see the Technical Data in Section
4.23 Dimensions.
•Connect the low-resistance operational and protective earth to the ground terminal of the device. The
crosssectional area of the ground wire must be equal to the cross-sectional area of any other control
conductor connected to the device. It must thus be at least 2.5 mm2.
•Alternatively, there is the possibility to connect the aforementioned earthing to the lateral earthing
surface with at least one M4 screw.
•Make the connections according to the circuit diagram via screw terminals, connections for optical fibres
and electrical communication modules via the console housings. The specifications concerning the
maximum cross-section, tightening torques, bending radii and strain relief given in the SIPROTEC 4
System Description must be observed. Installation notes are also given in the brief reference booklet that
comes with the device.
3.1.3.3
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3.1 Mounting and Connections
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Checking Connections
Checking Data Connections of Serial Interfaces
The tables in the following sections list the pin assignments for the different serial interfaces, the time
synchronization interface and the Ethernet interface of the device. The position of the connectors is depicted
in the following figures.
[dsub-buchsen-020313-kn, 1, en_GB]
Figure 3-20 9-pin D-subminiature female connectors
[ethernet-anschlussbuchsen-101103-kn, 1, en_GB]
Figure 3-21 Ethernet connector
Operator Interface
When the recommended communication cable is used (for order designation see Appendix A Ordering Infor-
mation and AccessoriesOrdering Information) correct connection between the SIPROTEC 4 device and the PC
or Laptop is automatically ensured
Service Interface
Check the data connection if the service interface is used to communicate with the device via hard wiring or
modem.
System Interface
For versions equipped with a serial interface to a control center, the user must check the data connection. The
visual check of the assignment of the transmission and reception channels is of particular importance. With
RS232 and fiber optic interfaces, each connection is dedicated to one transmission direction. Therefore the
output of one device must be connected to the input of the other device and vice versa.
With data cables, the connections are designated according to DIN 66020 and ISO 2110:
•TxD = Data Transmit
•RxD = Data Receive
•RTS = Request to send
3.2
3.2.1
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3.2 Checking Connections
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•CTS = Clear to send
•GND = Signal / Chassis Ground
The cable shield is to be earthed at both line ends. For extremely EMC-prone environments, the earth may be
connected via a separate individually shielded wire pair to improve immunity to interference.
Table 3-22 The assignments of the D-subminiature and RJ45 connector for the various interfaces
Pin No. Operator
interface
RS232 RS485 PROFIBUS FMS Slave, RS485 DNP3.0 RS485 Ethernet
EN 100
PROFIBUS DP Slave, RS485
1 Shield (with shield ends electrically connected) Tx+
2 RxD RxD - - - Tx-
3 TxD TxD A/A’ (RxD/TxD-N) B/B’ (RxD/TxD-P) A Rx+
4 - - - CNTR-A (TTL) RTS (TTL level) -
5 GND GND C/C’ (GND) C/C’ (GND) GND1 -
6 - - - +5 V (max. load < 100 mA) VCC1 Rx-
7 RTS RTS - 1) - - -
8 CTS CTS B/B’ (RxD/TxD-P) A/A’ (RxD/TxD-N) B -
9 - - - - - Non Exis-
tent
1) Pin 7 also carries the RTS signal with RS232 level when operated as RS485 Interface. Pin 7 must therefore
not 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' (GND). Verify that only the last device on the bus has the terminating resistors connected, and
that the other devices on the bus do not. The jumpers for the terminating resistors are located on the interface
module RS485 (see Figure 3-12) or on the Profibus module RS485 (see Figure 3-13). The terminating resistors
can also be connected externally (e.g. to the connection module as illustrated in Figure 3-15). In this case, the
terminating resistors located on the module must be disabled.
If the bus is extended, make sure again that only the last device on the bus has the terminating resistors
enabled, and that all other devices on the bus do not.
Time Synchronization Interface
It is optionally possible to process 5 V, 12 V or 24 V time synchronization signals, provided that these are
connected to the inputs named in the following table.
Table 3-23 D-subminiature connector assignment of the time synchronization interface
Pin No. Description Signal meaning
1 P24_TSIG Input 24 V
2 P5_TSIG Input 5 V
3 M_TSIG Return line
4- 1) - 1)
5 SHIELD Shield potential
6 - -
7 P12_TSIG Input 12 V
8P_TSYNC 1) Input 24 V 1)
9 SHIELD Shield potential
1) Assigned, but cannot be used
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Optical Fibres
!
WARNING
Do not look directly into the fiber-optic elements, not even with optical devices! Laser class 1
according to EN 60825-1.
²
For the protection data communication, refer to the following section.
The transmission via fiber optics is particularly insensitive to electromagnetic interference and thus ensures
galvanic isolation of the connection. Transmit and receive connections are shown with the symbols or
transmit and for receive.
The character idle state for the optical fibre interface is “Light off”. If the character idle state is to be changed,
use the operating program DIGSI, as described in the SIPROTEC 4 System Description.
Checking the Protection Data Communication
If the device features protection data interfaces for digital communication links, the transmission way must be
checked. The protection data communication is conducted either directly from device to device via optical
fibres or via communication converters and a communication network or a dedicated transmission medium.
Optical Fibres, Directly
!
WARNING
Laser Radiation Hazard!
Non-observance of the following measure can result in death, personal injury or substantial property
damage.
²Do not look directly into the fibre-optic elements, not even with optical devices! Laser class 1
according to EN 60825-1.
The direct optical fibre connection is visually inspected by means of an optical fibre connector. There is one
connection for each direction. The data output of one device must be connected to the data input of the other
device and vice versa. Transmission and receiving connections are identified with the symbols for
transmit and for receive. The visual check of the assignment of the transmission and reception channels
is important.
For short distances, laser class 1 is fulfilled if FO5 modules and the recommended fibres are used. In other
cases, the laser output may be higher
If using more than one device, the connections of all protection data interfaces are checked according to the
topology selected.
Communication Converter
Optical fibres are usually used for the connections between the devices and communication converters. The
optical fibres are checked in the same manner as the optical fibre direct connection which means for every
protection data interface.
Make sure that under the address 4502 CONNEC. 1 OVER or 4602 CONNEC. 2 OVER the right connection
type is parameterized.
3.2.2
Mounting and Commissioning
3.2 Checking Connections
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Further Connections
For further connections a visual inspection is sufficient for the time being. Electrical and functional controls
are performed during commissioning (see the following main section).
Checking the System Connections
!
WARNING
Warning of dangerous voltages
Non-observance of the following measures can result in death, personal injury or substantial prop-
erty damage.
²Therefore, only qualified people who are familiar with and adhere to the safety procedures and
precautionary measures shall perform the inspection steps.
!
CAUTION
Be careful when operating the device on a battery charger without a battery
Non-observance of the following measure can lead to unusually high voltages and consequently, the
destruction of the device.
²Do not operate the device on a battery charger without a connected battery. (For limit values see also
Technical Data, Section 4.1 General).
Before the device is energized for the first time, it should be in the final operating environment for at least 2
hours to equalize the temperature, to minimize humidity and avoid condensation. Connections are checked
with the device at its final location. The plant must first be switched off and earthed.
Proceed as follows in order to check the system connections:
•Protective switches for the power supply and the measured voltages must be switched off.
•Check the continuity of all current and voltage transformer connections against the system and connec-
tion diagrams:
– Are the current transformers earthed properly?
– Are the polarities of the current transformers the same?
– Is the phase relationship of the current transformers correct?
– Are the voltage transformers earthed properly?
– Are the polarities of the voltage transformers correct?
– Is the phase relationship of the voltage transformers correct?
–Is the polarity for current input Ι4 correct (if used)?
– Is the polarity for voltage input U4 correct (if used, e.g. with open delta winding or busbar voltage)?
•Check the functions of all test switches that are installed for the purposes of secondary testing and isola-
tion of the device. Of particular importance are test switches in current transformer circuits. Be sure these
switches short-circuit the current transformers when they are in the “test mode”.
3.2.3
Mounting and Commissioning
3.2 Checking Connections
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•The short circuit links of the connectors for the current circuits have to be checked. This can be done
using secondary test equipment or other test equipment for checking continuity. Make sure that terminal
continuity is not wrongly simulated in reverse direction via current transformers or their short-circuiters.
– Remove the front panel of the device (see also Figure 3-3 to Figure 3-4).
– Remove the ribbon cable connected to the input/output module with the measured current inputs
(on the front side it is the right PCB, for housing size 1/2 see Figure 3-3 slot 33, for housing size 1/1
see Figure 3-4 slot 33 right). Furthermore, remove the PCB so that there is no more contact with the
plug-in terminal.
– At the terminals of the device, check continuity for each pair of terminals that receives current from
the CTs.
– Firmly re-insert the I/O board. Carefully connect the ribbon cable. Be careful that no connector pins
are bent! Don't apply force!
– At the terminals of the device, again check continuity for each pair of terminals that receives current
from the CTs.
– Attach the front panel and tighten the screws.
•Connect an ammeter in the supply circuit of the power supply. A range of about 2.5 A to 5 A for the
meter is appropriate.
•Switch on m.c.b. for auxiliary voltage (supply protection), check the voltage level and, if applicable, the
polarity of the voltage at the device terminals or at the connection modules.
•The measured steady-state current should correspond to the quiescent power consumption of the device.
Transient movement of the ammeter merely indicates the charging current of capacitors.
•Remove the voltage from the power supply by opening the protective switches.
•Disconnect the measuring test equipment; restore the normal power supply connections.
•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.
•Open the miniature circuit breakers for the transformer voltage (VT mcb)
•Check tripping circuits to the circuit breakers.
•Check the close circuits to the power system circuit breakers.
•Verify that the control wiring to and from other devices is correct.
•Check the signalling connections.
•Close the protective switches.
Mounting and Commissioning
3.2 Checking Connections
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Commissioning
!
WARNING
Warning of dangerous voltages when operating an electrical device
Non-observance of the following measures can result in death, personal injury or substantial prop-
erty damage.
²Only qualified people shall work on and around this device. They must be thoroughly familiar with all
warnings and safety notices in this instruction manual as well as with the applicable safety steps,
safety regulations, and precautionary measures.
²Before making any connections, the device must be earthed at the protective conductor terminal.
²Hazardous voltages can exist in the power supply and at the connections to current transformers,
voltage transformers, and test circuits.
²Hazardous voltages can be present in the device even after the power supply voltage has been
removed (capacitors can still be charged).
²After removing voltage from the power supply, wait a minimum of 10 seconds before re-energizing
the power supply. This wait allows the initial conditions to be firmly established before the device is
re-energized.
²The limit values given in Technical Data must not be exceeded, neither during testing nor during
commissioning.
For tests with a secondary test equipment ensure that no other measurement voltages are connected and the
trip and close commands to the circuit breakers are blocked, unless otherwise specified.
!
DANGER
Hazardous voltages during interruptions in secondary circuits of current transformers
Non-observance of the following measure will result in death, severe personal injury or substantial
property damage.
²Short-circuit the current transformer secondary circuits before current connections to the device are
opened.
During the commissioning procedure, switching operations must be carried out. The tests described require
that they can be done without danger. They are accordingly not meant for operational checks.
!
WARNING
Warning of dangers evolving from improper primary tests
Non-observance of the following measure can result in death, personal injury or substantial property
damage.
²Primary tests may only be carried out by qualified persons who are familiar with commissioning
protection systems, with managing power systems and the relevant safety rules and guidelines
(switching, earthing etc.).
3.3
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Test Mode / Transmission Block
Activation and Deactivation
If the device is connected to a central control system or a server via the SCADA interface, then the information
that is transmitted can be modified with some of the protocols available (see Table “Protocol-dependent func-
tions” in the Appendix D.7 Protocol-dependent Functions).
If Test mode is set ON, then a message sent by a SIPROTEC 4 device to the main system has an additional test
bit. This bit allows the message to be recognized as resulting from testing and not an actual fault or power
system event. Furthermore it can be determined by activating the Transmission block that no indications at
all are transmitted via the system interface during test mode.
The SIPROTEC 4 System Description describes how to activate and deactivate test mode and blocked data
transmission. Note that when DIGSI is being used, the program must be in the Online operating mode for the
test features to be used.
Checking the Time Synchronisation Interface
If external time synchronization sources are used, the data of the time source (antenna system, time gener-
ator) are checked (see Section 4 under „Time Synchronization“). A correct function (IRIG B, DCF77) is recog-
nized in such a way that 3 minutes after the startup of the device the clock status is displayed as
synchron-
ized
, accompanied by the indication
Alarm Clock OFF
. For further information please refer to the
SIPROTEC System Description.
Table 3-24 Time status
No. Status text Status
1 – – – – – – – – synchronized
2 – – – – – – ST
3 – – – – ER – –
not synchronized
4 – – – – ER ST
5 – – NS ER – –
6 – – NS – – – –
Legend:
– – NS – – – –
– – – – ER – –
– – – – – – ST
time invalid
time fault
summertime
Testing the System Interface
Prefacing Remarks
If the device features a system interface and uses it to communicate with the control centre, the DIGSI device
operation can be used to test if messages are transmitted correctly. This test option should however definitely
“not”“ be used while the device is in service on a live system.
3.3.1
3.3.2
3.3.3
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!
DANGER
The sending or receiving of indications via the system interface by means of the test function is a
real information exchange between the SIPROTEC 4 device and the control centre. Connected oper-
ating equipment such as circuit breakers or disconnectors can be switched in this way!
Non-observance of the following measure will result in death, severe personal injury or substantial
property damage.
²Equipment used to allow switching such as circuit breakers or disconnectors is to be checked only
during commissioning. Do not under any circumstances check them by means of the testing mode
during “real” operation performing transmission and reception of messages via the system interface.
i
i
NOTE
After termination of the hardware test, the device will reboot. Thereby, all annunciation buffers are erased.
If required, these buffers should be extracted with DIGSI prior to the test.
The interface test is carried out using DIGSI in the Online operating mode:
•Open the Online directory by double-clicking; the operating functions for the device appear.
•Click on Test; the function selection appears in the right half of the window.
•Double-click on Testing Messages for System Interface shown in the list view. The dialog box Generate
Indications is opened (see Figure 3-22).
Structure of the Dialog Box
In the column Indication, all message texts that were configured for the system interface in the matrix will
then appear. In the column Setpoint you determine a value for the indications that shall be tested. Depending
on the type of message different entering fields are available (e.g. message ON / message OFF). By clicking
on one of the buttons you can select the desired value from the pull-down menu.
[schnittstelle-testen-110402-wlk, 1, en_GB]
Figure 3-22 System interface test with dialog box: Generating indications – Example
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Changing the operating state
On clicking one of the buttons in the column Action you will be prompted for the password No. 6 (for hard-
ware test menus). After correct entry of the password, individual annunciations can be initiated. To do so, click
on the button Send in the corresponding line. The corresponding message is issued and can be read out either
from the event log of the SIPROTEC4 device or from the substation control center.
Further tests remain enabled until the dialog box is closed.
Test in Indication Direction
For all information that is transmitted to the central station, test in Setpoint the desired options in the list
which appears:
•Make sure that each checking process is carried out carefully without causing any danger (see above and
refer to DANGER!)
•Click on Send and check whether the transmitted information reaches the control centre and shows the
desired reaction. Data which are normally linked via binary inputs (first character “>”) are likewise indi-
cated to the control centre with this procedure. The function of the actual binary inputs is tested sepa-
rately.
Exiting the Procedure
To end the System Interface Test, click on Close. The dialog box closes. The processor system is restarted, then
the device is ready for operation.
Test in Command Direction
Data which are normally linked via binary inputs (first character “>”) are likewise checked with this procedure.
The information transmitted in command direction must be indicated by the central station. Check whether
the reaction is correct.
Checking the switching states of the binary Inputs/Outputs
Prefacing Remarks
The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually and precisely controlled in
DIGSI. This feature is used to verify control wiring from the device to plant equipment (operational checks)
during commissioning. This test option should however definitely “not”“ be used while the device is in service
on a live system.
!
DANGER
A changing of switching states by means of the test function causes a real change of the operating
state at the SIPROTEC 4 device. Connected operating equipment such as circuit breakers or discon-
nectors will be switched in this way!
Non-observance of the following measure will result in death, severe personal injury or substantial
property damage.
²Equipment used to allow switching such as circuit breakers or disconnectors is to be checked only
during commissioning. Do not under any circumstances check them by means of the testing mode
during “real” operation performing transmission and reception of messages via the system interface.
i
i
NOTE
After termination of the hardware test the device will reboot. Thereby, all annunciation buffers are erased.
If required, these buffers should be extracted with DIGSI prior to the test.
The hardware test can be carried out using DIGSI in the Online operating mode:
3.3.4
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•Open the Online directory by double-clicking; the operating functions for the device appear.
•Click on Test; the function selection appears in the right half of the window.
•Double-click in the list view on Device inputs and outputs. The dialog box with this name is opened (see
Figure 3-23).
Structure of the Dialog Box
The dialog box is divided into three groups: BI for binary inputs, BO for binary outputs and LED for LEDs. An
accordingly labeled button is on the left of each group. By double-clicking a button, information regarding the
associated group can be shown or hidden.
In the column Status the present (physical) state of the hardware component is displayed. Indication is
displayed symbolically. The physical actual states of the binary inputs and outputs are indicated by an open or
closed switch symbol, the LEDs by switched on or switched off symbol.
The opposite state of each element is displayed in the column Scheduled. The display is in plain text.
The right-most column indicates the commands or messages that are configured (masked) to the hardware
components.
[ein-ausgabe-testen-110402-wlk, 1, en_GB]
Figure 3-23 Test of the Binary Inputs and Outputs — Example
Changing the operating state
To change the operating state of a hardware component, click on the associated switching field in the Sched-
uled column.
Before executing the first change of the operating state the password No. 6 will be requested (if activated
during configuration). After entry of the correct password a condition change will be executed. Further state
changes remain enabled until the dialog box is closed.
Test of the output relay
Each individual output relay can be energized allowing a check of the wiring between the output relay of the
7SA522 and the plant, without having to generate the message that is assigned to the relay. As soon as the
first change of state for any of the output relays is initiated, all output relays are separated from the internal
device functions, and can only be operated by the hardware test function. This means, that e.g. a TRIP
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command coming from a protection function or a control command from the operator panel to an output
relay cannot be executed.
Proceed as follows in order to check the output relay:
•Make sure that the switching operations caused by the output relays can be executed without any danger
(see above under DANGER!).
•Each output relay must be tested via the corresponding Scheduled field of the dialog box.
•Finish the testing (see margin heading below “Exiting the Procedure”), so that during further testings no
unwanted switchings are initiated.
Test of the binary inputs
To test the wiring between the plant and the binary inputs of the 7SA522the condition in the system which
initiates the binary input must be generated and the response of the device checked.
To do so, open the dialog box Hardware Test again to view the physical position of the binary input. The pass-
word is not yet required.
Proceed as follows in order to check the binary inputs:
•Each state in the system which causes a binary input to pick up must be generated.
•Check the reaction in the Status column of the dialog box. To do this, the dialog box must be updated.
The options may be found below under the margin heading “Updating the Display”.
•Finish the test sequence (see margin heading below “Exiting the Procedure”).
If, however, the effect of a binary input must be checked without carrying out any switching in the system, it
is possible to trigger individual binary inputs with the hardware test function. As soon as the first state change
of any binary input is triggered and the password No. 6 has been entered, all binary inputs are separated from
the system and can only be activated via the hardware test function.
Test of the LEDs
The light-emitting diodes (LEDs) 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 separated from the internal device
functionality and can only be controlled via the hardware test function. This means e.g. that no LED is illumi-
nated anymore by a protection function or by pressing the LED reset button.
Updating the Display
When the dialog box Hardware Test is opened, the present conditions of the hardware components at that
moment are read in and displayed.
An update is made:
•For the particular hardware component, if a command for change to another state was successful,
•For all hardware components if the Update button is clicked,
•For all hardware components with cyclical updating (cycle time is 20 sec) if the Automatic Update (20
sec) field is marked.
Exiting the Procedure
To end the hardware test, click on Close. The dialog box closes. Thus, all the hardware components are set
back to the operating state specified by the plant states. The processor system is restarted, then the device is
ready for operation.
Checking the Communication Topology
General
The communication topology can be checked from the PC using DIGSI.
3.3.5
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You can either connect the PC to the device locally using the operator interface at the front, or the service
interface at the back of the PC Figure 3-24). Or you can log into the device using a modem via the service
interface (example in Figure 3-25).
[topologie-ankopplung-pc-geraet-240702-kn, 1, en_GB]
Figure 3-24 PC interfacing directly to the device - example
[topologie-ankopplung-pc-modem-240702-kn, 1, en_GB]
Figure 3-25 PC interfacing via modem — schematic example
Checking a Connection using Direct Link
For two devices linked with fibre optical cables (as in Figure 3-24 or Figure 3-25), this connection is checked as
follows.
•Both devices at the link ends have to be switched on.
•Check in the operating indications or in the spontaneous indications:
–If the indication
PI1 with
(protection data interface 1 connected with no. 3243) is provided with
the device index of the other device, a link has been established and one device has detected the
other.
– If the protection data interface 2 has also been connected, a corresponding message will appear
(No. 3244).
•In case of an incorrect communication link, the message
PI1 Data fault
(No. 3229) or
PI2 Data
fault
(No.3231) will appear. In this case, recheck the fibre optical cable link.
– Have the devices been linked correctly and no cables been mixed up?
– Are the cables free from mechanical damage, intact and the connectors locked?
– Otherwise repeat check.
Continue with the margin heading “Consistency of Topology and Parameterization”.
Checking a Link with a Communication Converter
If a communication converter is used, please note the instructions enclosed with the device. The communica-
tion converter has a test setting where its outputs are looped back to the inputs.
Links via the communication converter are tested by means of local loop-back (Figure 3-26 links).
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[topologie-kommunikationsnetz-240702-kn, 1, en_GB]
Figure 3-26 Protection data communication via communication converter and communication network —
schematic example
!
DANGER
Opening the Communication Converter
There is danger to life by energized parts!
²Before opening the communication converter, it is absolutely necessary to isolate it from the auxiliary
supply voltage at all poles!
•Both devices at the link ends have to be switched on.
•First configure the communication converter CC-1:
– Disconnect the auxiliary supply voltage from both poles.
– Open the communication converter.
– Set the jumpers to the matching position for the correct interface type and transmission rate; they
must be identical with the parameterization of the 7SA522 (address 4502 CONNEC. 1 OVER for
protection data interface 1 and 4602 CONNEC. 2 OVER for protection data interface 2, see also
Subsection 2.4.2 Setting Notes).
– Move the communication converter into test position (jumper X32 in position 2-3).
– Close the communication converter housing.
•Reconnect the auxiliary supply voltage for the communication converter.
•The system interface (X.21 or G703.1) must be active and connected to the communication converter.
Check this by means of the “device ready”-contact of the communication converter (continuity at the NO
contact).
– If the “device ready”-contact of the communication converter doesn't close, check the connection
between the communication converter and the net (communication device). The communication
device must emit the correct transmitter clock to the communication converter.
•Change the interface parameters at the 7SA522 (at the device front or via DIGSI):
– Address 4502 CONNEC. 1 OVER = F.optic direct when you are testing protection data inter-
face 1,
– Address 4602 CONNEC. 2 OVER = F.optic direct, when you are testing protection data inter-
face.
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•Check the operating indications or in the spontaneous annunciations:
–Message 3217
PI1 Data reflec
(Protection interface 1 data reflection ON) when you test
protection data interface 1,
–Message 3218
PI2 Data reflec
(Protection interface 1 data reflection ON) when you test
protection data interface 2.
– When working with both interfaces, note that the correct interface of the 7SA522 is connected to its
associated communication converter.
– If the indication is not transmitted check for the following:
– Has the 7SA522 fibre optical transmitting terminal output been correctly linked with the fibre optical
receiving terminal input of the communication converter and vice versa (No erroneous inter-
changing)?
– Does the 7SA522 device have the correct interface module and is it working correctly?
– Are the fibre optic cables intact?
– Are the parameter settings for interface type and transmission rate at the communication converter
correct (see above; note the DANGER instruction!)?
– Repeat the check after correction, if necessary.
•Reset the interface parameters at the 7SA522 correctly:
– Address 4502 CONNEC. 1 OVER = required setting, when you have tested protection data interface
1,
– Address 4602 CONNEC. 2 OVER = required setting, when you have tested protection data interface
2.
•Disconnect the auxiliary supply voltage of the communication converter at both poles. Note the above
DANGER instruction!
•Reset the communication converter to normal position (X32 in position 1-2) and close the housing again.
•Reconnect the supply voltage of the communication converter.
Perform the above check at the other end with the device being connected there and its corresponding
communication converter.
Continue with the margin heading “Consistency of Topology and Parameterization”.
Consistency of Topology and Parameterisation
Having performed the above checks, the linking of a device pair, including their communication converters,
has been completely tested and connected to the auxiliary supply voltage. Now the devices communicate by
themselves.
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•Check now the Event Log or the spontaneous annunciations of the device you are working on:
–Indication No. 3243
PI1 with
(protection data interface 1 linked with) followed by the device
index of the other device, if interface 1 is applying.
–Indication No. 3244
PI2 with
(protection data interface 2 linked with) followed by the device
index of the other device, if interface 2 is applying.
–If the devices are at least connected once, the message No. 3458
Chaintopology
will appear..
–If no other devices are involved in the topology as an entity, the message No. 3464
Topol
complete
will then be displayed, too.
– And if the device configuration is also consistent, i.e. the prerequisites for setting the function scope
(Section 2.1.1 Functional Scope), Power System Data 1 (2.1.2.1 Setting Notes), Power System Data
2 (2.1.4.1 Setting Notes), topology and protection data interface parameters (Section 2.4.2 Setting
Notes) have been considered, the fault message, i.e. No.3229
PI1 Data fault
, for the interface
just checked will disappear. The communication and consistency test has now been completed.
– If the fault message of the interface being checked does not disappear, however, the fault must be
found and eliminated. The following tabele lists messages that indicate such faults.
Table 3-25 Inconsistency Messages
No LCD Text Meaning / Measures
3233
DT inconsis-
tent
“Device table inconsistent”: The indexing of the devices is inconsistent
(missing numbers or one number used twice, see Section 2.4.2 Setting
Notes)
3234
DT unequal
“Device table unequal”: The ID-numbers of the devices are unequal (see
Section 2.4.2 Setting Notes)
3235
Par. different
“Parameterization inconsistent”: Different functional parameters were set
for the devices. They have to be equal at both ends.
The following function parameters must agree to all ends:
•Phase sequence (address 235);
•If you work with teleprotection via the protection data interface (address 121 = SIGNALv.ProtInt), the
parameter FCT Telep. Dis. (address 2101) must be controlled;
•Where direction comparison with protection data interface is used in earth fault protection, parameter
Teleprot. E/F (address 132) must be taken into account.
Checking Further Links
If more than two devices are connected, that is if the protected object has more than two ends, or if two
devices are connectd via both protection data interfaces to create redundancy, repeat all checks for every
possible link as described above including the consistency check.
If all devices involved in the topology communicate properly and all parameters are consistent, the message
No. 3464
Topol complete
appears..
If there is a ring topology (only in connection with a 7SA522), the message No. 3457
Ringtopology
must
also appear after closing the ring.
However, if you are employing a ring topology, which only issues the indication
Ringtopology
instead of
Chaintopology
, the protection data communication is functionable, but the ring has not yet been closed.
Check the missing links as described above including the consistency test until all links to the ring have been
made.
Finally, there should be no more fault messages of the protection data interfaces.
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Test Mode for Teleprotection Scheme with Protection Data Interface
Local Test Mode
The “local test mode” can be used for commissioning or revision tests of the teleprotection scheme via protec-
tion data interface.
Select from the menus “Control” -> “Tagging” -> “Set” to set the “Test mode” tagging. The tagging is protected
against loss of the auxiliary voltage. The indication 3196
local Teststate
is output to indicate that the test
mode is activated.
When the local device is in test mode, all information transferred via the protection data interface is marked
with the attribute “Test mode”.
The teleprotection scheme via protection data interface can be tested as follows:
•A fault generated at the local device by some test equipment generates the required send signals.
•The send signals are transmitted to the remote end with the attribute“Test mode”.
•The remote end receives the send signal with the attribute “Test mode” and mirrors the received send
signals as its own send signals, likewise with the attribute “Test mode”, selectively for each phase back to
the local device (the received send signals are not evaluated in terms of protection).
•The local device receives the mirrored signals and feeds them into its own teleprotection schemes, where
they may cause the output of a trip signal.
i
i
NOTE
As long as a device is in “protection data interface test mode”, selective line protection is not ensured!
Checking for Breaker Failure Protection
General
If the device is equipped with the breaker failure protection and this function is used, the integration of this
protection function into the system must be tested under practical conditions.
Because of the manifold applications and various configuration possibilities of the plant it is not possible to
give a detailed description of the necessary test steps. It is important to consider the local conditions and the
protection and plant drawings.
Before starting the circuit tests it is recommended to isolate the circuit breaker of the feeder to be tested at
both ends, i.e. line disconnectors and busbar disconnectors should be open so that the breaker can be oper-
ated without risk.
!
CAUTION
Also for tests on the local circuit breaker of the feeder a trip command to the surrounding circuit breakers
can be issued for the busbar.
Non-observance of the following measure can result in minor personal injury or property damage.
²First disable the trip commands to the adjacent (busbar) breakers, e.g. by interrupting the associated
control voltages.
Before the breaker is closed again for normal operation the trip command of the feeder protection routed to
the circuit breaker must be disconnected so that the trip command can only be initiated by the breaker failure
protection.
Although the following list does not claim to be complete, it may also contain points which are to be ignored
in the current application.
3.3.6
3.3.7
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Auxiliary Contacts of the CB
The circuit breaker auxiliary contact(s) form an essential part of the breaker failure protection system in case
they have been connected to the device. Make sure the correct assignment has been checked.
External Initiation Conditions
If the breaker failure protection can also be started by external protection devices, the external start conditions
are checked. Depending on the device version and the setting of the breaker failure protection, 1-pole or 3-
pole trip are possible. The pole discrepancy check of the device or the actual breaker may lead to 3-pole trip-
ping after 1-pole tripping. Therefore check first how the parameters of the breaker failure protection are set.
Also see Section 2.18.2 Setting Notes, addresses 3901 ff.
In order for the breaker failure protection to be started, a current must flow at least through the monitored
phase and the earth. This may be a secondary injected current.
After every start, the indication
BF Start
(No. 1461) must appear in the spontaneous indications or fault
indications.
If only 1-pole initiation is possible:
•Start by 1-pole trip command of the external protectionL1 :
Binary input functions
>BF Start L1
and if necessary
>BF release
(in spontaneous or fault indica-
tions). Trip command (dependent on settings).
•Start by 1-pole trip command of the external protectionL2 :
Binary input functions
>BF Start L2
and if necessary
>BF release
(in spontaneous or fault indica-
tions). Trip command (dependent on settings).
•Start by 1-pole trip command of the external protectionL3 :
Binary input functions
>BF Start L3
and if necessary
>BF release
(in spontaneous or fault indica-
tions). Trip command (dependent on settings).
•Start by 3-pole trip command of the external protection via all three binary inputs L1, L2 and L3:
Binary input functions
>BF Start L1
,
>BF Start L2
and
>BF Start L3
and if necessary
>BF
release
(in spontaneous or fault indications). 3-pole trip command.
For 3-pole initiation:
•Start by 3-pole trip command of the external protection :
Binary input functions
>BF Start 3pole
and if necessary
>BF release
(in spontaneous or fault indi-
cations). Trip command (dependent on settings).
Switch off test current.
If start is possible without current flow:
•Starting by trip command of the external protection without current flow:
Binary input functions
>BF Start w/o I
and if necessary
>BF release
(in spontaneous or fault indi-
cations). Trip command (dependent on settings).
Busbar tripping
The most important thing is the check of the correct distribution of the trip commands to the adjacent circuit
breakers in case of breaker failure.
The adjacent circuit breakers are those of all feeders which must be tripped in order to ensure interruption of
the fault current should the local breaker fail. These are therefore the circuit breakers of all feeders which feed
the busbar 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 adjacent circuit breakers largely
depends on the system topology.
In particular with multiple busbars the trip distribution logic for the surrounding circuit breakers must be
checked. Here check for every busbar section that all circuit breakers which are connected to the same busbar
section as the feeder circuit breaker under observation are tripped, and no other breakers.
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Tripping of the Remote End
If the trip command of the circuit breaker failure protection must also trip the circuit breaker at the remote
end of the feeder under observation, the transmission channel for this remote trip must also be checked. This
is done together with transmission of other signals according to Sections “Testing of the Teleprotection
Scheme with ...” further below.
Termination of the Checks
All temporary measures taken for testing must be undone, e.g. especially switching states, interrupted trip
commands, changes to setting values or individually switched off protection functions.
Current, Voltage, and Phase Rotation Testing
≥ 10 % of Load current
The connections of the current and voltage transformers are tested using primary quantities. Load current of
at least 10 % of the nominal current of the device is necessary. The line is energized and will remain in this
state during the measurements.
With proper connections of the measuring circuits, none of the measured-values supervision elements in the
device should pick up. If an element detects a problem, the causes which provoked it may be viewed in the
Event Log.
If current or voltage summation errors occur, then check the matching factors (see Section 2.1.2.1 Setting
Notes).
Messages from the symmetry monitoring could occur because there actually are asymmetrical conditions in
the network. If these asymmetrical conditions are normal service conditions, the corresponding monitoring
functions should be made less sensitive (see Section 2.19.1.6 Setting Notes).
Quantities
Currents and voltages can be viewed in the display field on the front of the device or the operator interface via
a PC. They can be compared to the actual measured values, as primary and secondary quantities.
If the measured values are not plausible, the connection must be checked and corrected after the line has
been isolated and the current transformer circuits have been short-circuited. The measurements must then be
repeated.
Phase Rotation
The phase rotation must correspond to the configured phase rotation, in general a clockwise phase rotation. If
the system has an anti-clockwise phase rotation, this must have been considered when the power system data
was set (address 235 PHASE SEQ.). Incorrect direction of rotation is indicated
Fail Ph. Seq.
(No. 171.
The measured value phase allocation must be checked and corrected, if required, after the line has been
isolated and current transformers have been short-circuited. The phase rotation check must then be repeated.
VT miniature circuit breaker
Open the miniature circuit breaker of the feeder voltage transformers. The measured voltages in the opera-
tional measured values appear with a value close to zero (small measured voltages are of no consequence).
Check in the spontaneous indications that the VT mcb trip was entered (Indication
>FAIL:Feeder VT
“ON”
in the spontaneous indications). Beforehand it has to be assured that the position of the VT mcb is connected
to the device via a binary input.
Close the VT mcb again: The above indication appears in the spontaneous indications as “OFF”, i.e.,
>FAIL:Feeder VT
“OFF”
If one of the annunciations does not appear, check the connection and allocation of these signals.
If the “ON” state and the “OFF” state are swapped, the contact type (H-active or L-active) must be checked and
corrected.
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If synchronism check is used and if the assigned VT mcb auxiliary contact is connected to the device, its func-
tion must also be checked. When switching off the protective switch the indication
>FAIL:U4 VT
“ON”
appears, after switching on the protective switch the indication
>FAIL:U4 VT
“OFF” appears.
Switch off the protected power line.
Directional Check with Load Current
≥ 10 % of Load Current
The correct connection of the current and voltage transformers is tested via the protected line using the load
current. For this purpose, connect the line. The load current the line carries must be at least 0.1·ΙN. The load
current should be in-phase or lagging the voltage (resistive or resistive-inductive load). The direction of the
load current must be known. If there is a doubt, network or ring loops should be opened. The line remains
energized during the test.
The direction can be derived directly from the operational measured values. Initially the correlation of the
measured load direction with the actual direction of load flow is checked. In this case the normal situation is
assumed whereby the forward direction (measuring direction) extends from the busbar towards the line (see
the following Figure).
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.
[lastscheinleistung-110402-wlk, 1, en_GB]
Figure 3-27 Apparent Load Power
The power measurement provides an initial indication as to whether the measured values have the correct
polarity. If both the active power as well as the reactive power have the wrong sign, the polarity in address
201 CT Starpoint must be checked and rectified.
However, power measurement itself is not able to detect all connection errors. Accordingly, the impedances
of all six measuring loops are evaluated. These can also be found as primary and secondary quantities in the
operational measured values.
All six measured loops must have the same impedance components (R and X). Small variations may result due
to the non-symmetry of the measured values. In addition, the following applies for all impedances when the
load is in the first quadrant:
R, X both positive, when power flows into the line,
R, X both negative, when power flows towards the busbar.
In this case the normal situation is assumed whereby the forward direction (measuring direction) extends
from the busbar towards the line. In the case of capacitive load, caused by e.g. underexcited generators or
charging currents, the X-components may all have the opposite sign.
If significant differences in the values of the various loops are present, or if the individual signs are different,
then individual phases in the current or voltage transformer circuits are swapped, not connected correctly, or
3.3.9
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the phase allocation is incorrect. After isolation of the line and short-circuiting of the current transformers the
connections must be checked and corrected. The measurements must then be repeated.
Finally, switch off the protected power line.
Polarity Check for the Voltage Input U4
Depending on the application of the voltage measuring input U4, a polarity check may be necessary. If no
measuring voltage is connected to this input, this section is irrelevant.
If the input U4 is used for measuring a voltage for overvoltage protection (P.System Data 1 address 210 U4
transformer = Ux transformer), no polarity check is necessary because the polarity is irrelevant here.
The voltage magnitude was checked before.
If the input U4 is used for the measurement of the displacement voltage Uen (P.System Data 1 address 210
U4 transformer = Udelta transf.), the polarity together with the current measurement is checked (see
below).
If input U4 is used for measuring a voltage for synchronism check (P.System Data 1 address 210 U4
transformer = Usy2 transf.), the polarity must be checked as follows using the synchronism check func-
tion.
Only for Synchronism Check
The device must be equipped with the synchronism and voltage check function which must be configured
under address 135 Enabled (see section 2.1.1.2 Setting Notes).
The synchronisation voltage Usy2 must be entered correctly at address 212 Usy2 connection (see Section
2.1.2.1 Setting Notes).
If there is no transformer between the two measuring points, address 214 φ Usy2-Usy1 must be set to0°
(see Section 2.1.2.1 Setting Notes).
If the measurement is made across a transformer, this angle setting must correspond to the phase rotation
resulting from the vector group of the transformer (see also the example in Section2.1.2.1 Setting Notes).
If necessary, different transformation ratios of the transformers may have to be considered from both meas-
uring points Usy1 and Usy2 at address 215 Usy1/Usy2 ratio.
The synchronism and voltage check must be switched ON under address 3501 FCT Synchronism.
An additional help for the connection check are the messages 2947
Sync. Udiff>
and 2949
Sync. φ-
diff>
in the spontaneous annunciations.
•Circuit breaker is open. The feeder is isolated (zero voltage). The VTmcb's of both voltage transformer
circuits must be closed.
•For the synchronism check the program AR OVERRIDE = YES (address 3519) is set; the other programs
(addresses 3515 to 3518) are set to NO.
•Via binary input (No.2906
>Sync. Start AR
) initiate the measuring request. The synchronism check
must release closing (message
Sync. release
, No. 2951). If not, check all relevant parameters again
(synchrocheck configured and enabled correctly, see Sections 2.1.1.2 Setting Notes, 2.1.2.1 Setting
Notes und 2.14.2 Setting Notes).
•Address 3519 AR OVERRIDE must be set to NO.
•Then the circuit breaker is closed while the line isolator is open (see Figure 3-28). Both voltage trans-
formers therefore measure the same voltage.
•The programAR SYNC-CHECK = YES (address 3515) is set for synchronism check.
•Via binary input (No.2906
>Sync. Start AR
) initiate the measuring request. The synchronism check
must release closing (message
Sync. release
, No.2951).
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[synchronkontrolle-messspannungen-250702-kn, 1, en_GB]
Figure 3-28 Measuring voltages for the synchrocheck — example
•If not, first check whether one of the before named messages 2947
Sync. Udiff>
or 2949
Sync. φ-
diff>
is available in the spontaneous messages.
The indication
Sync. Udiff>
indicates that the magnitude (ratio) adaptation is incorrect. Check
address 215 Usy1/Usy2 ratio and recalculate the adaptation factor, if necessary.
The indication
Sync. φ-diff>
indicates that the phase relation, in this example of the busbar voltage,
does not match the setting at address 212 Usy2 connection (see Section 2.1.2.1 Setting Notes).
When measuring across a transformer, address 214 φ Usy2-Usy1 must also be checked; this must
adapt the vector group (see Section2.1.2.1 Setting Notes). If these are correct, there is probably a reverse
polarity of the voltage transformer terminals forUsy2.
•The program AR Usy1>Usy2< = YES (address 3517) and AR SYNC-CHECK = YES (address 3515) is set
for synchronism check.
•Open the VT mcb of the measuring point Usy2 (No. 362
>FAIL:U4 VT
).
•Via binary input (No.2906
>Sync. Start AR
) a measuring request is entered. There is no close release.
If there is, the VT mcb for the measuring point Usy2 is not allocated. Check whether this is the required
state, alternatively check the binary input
>FAIL:U4 VT
(No. 362).
•Reclose the VT mcb of the measuring point Usy2.
•Open the circuit breaker.
•The program AR Usy1<Usy2> = YES (address 3516) and AR Usy1>Usy2< = NO (address 3517) is set
for synchronism check.
•Via binary input (No.2906
>Sync. Start AR
) initiate the measuring request. The synchronism check
must release closing (message
Sync. release
, No. 2951). If not, check all voltage connections and
the corresponding parameters again carefully as described in Section 2.1.2.1 Setting Notes.
•Open the VT mcb of the measuring pointUsy1 (No. 361
>FAIL:Feeder VT
).
•Via binary input (No. 2906
>Sync. Start AR
) initiate the measuring request. No close release is given.
•Reclose the VT mcb of the measuring point Usy1 wieder einschalten.
Addresses 3515 to 3519must be restored as they were changed for the test. If the allocation of the LEDs or
signal relays was changed for the test, this must also be restored.
Polarity Check for the Current Input Ι4
If the standard connection of the device is used whereby current input Ι4 is connected in the starpoint of the
set of current transformers (refer also to the connection circuit diagram in the Appendix C Connection Exam-
ples), then the correct polarity of the earth current path in general automatically results.
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If, however, the current Ι4 is derived from a separate summation CT or from a different point of measurement,
e.g. transformer star-point current or earth current of a parallel line, an additional polarity check with this
current is necessary.
If the device features the sensitive current input for Ι4 and if it is used in an isolated or resonant-earthed
system, the polarity check for I4 was already carried out with the earth fault check according to the previous
section. Then this section can be ignored.
Apart from that the test is carried out with a disconnected trip circuit and primary load current. It must be
noted that during all simulations not exactly corresponding with cases that occur in practice, the asymmetry of
measured values may cause the measured value monitoring to pick up. They must therefore be ignored during
such tests.
!
DANGER
Hazardous voltages during interruptions in secondary circuits of current transformers
Non-observance of the following measure will result in death, severe personal injury or substantial
property damage.
²Short-circuit the current transformer secondary circuits before current connections to the device are
opened.
Ι4 from Own Line
To generate a displacement voltage, the e-n winding of one phase in the voltage transformer set (e.g. L1) is
bypassed (refer to Figure 3-29). If no connection to the e-n windings of the voltage transformer is available,
the corresponding phase is open circuited on the secondary side. Via the current path only the current from
the current transformer in the phase from which the voltage in the voltage path is missing, is connected; the
other CTs are short-circuited. If the line carries resistive-inductive load, the protection is in principle subject to
the same conditions that exist during an earth fault in the direction of the line.
At least one stage of the earth fault protection must be set to be directional (address 31x0 of the earth fault
protection). The pickup threshold of this stage must be below the load current flowing on the line; if necessary
the pickup threshold must be reduced. Note down the parameters that you have changed.
After switching the line on and off again, the direction indication must be checked: in the fault log the
messages
EF Pickup
and
EF forward
must at least be present. If the directional pickup is not present,
either the earth current connection or the displacement voltage connection is incorrect. If the wrong direction
is indicated, either the direction of load flow is from the line toward the busbar or the earth current path has a
swapped polarity. In the latter case, the connection must be rectified after the line has been isolated and the
current transformers short-circuited.
The voltages can be read on the display at the front, or called up in the PC via the operator or service interface,
and compared with the actual measured quantities as primary or secondary values. The voltages can also be
read out with the Web-Monitor. For devices with protection data interface, besides the magnitudes of the
phaseto- phase and the phase-to-earth voltages, the phase angles can be read out, thus enabling to verify the
correct phase sequence and polarity of individual voltage transformer.
In the event that the pickup alarms were not even generated, the measured earth (residual) current may be
too small.
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[polaritaetspruefung-i4-holmgreen-250702-kn, 1, en_GB]
Figure 3-29 Polarity check for Ι4, example with current transformer configured in a Holmgreen connection
i
i
NOTE
If parameters were changed for this test, they must be returned to their original state after completion of
the test!
Ι4 from Parallel Line
If Ι4 is the current measured on a parallel line, the above procedure is done with the set of current trans-
formers of the parallel line (Figure 3-30). The same method as above is used here, except that a single phase
current from the parallel feeder is measured. The parallel line must carry load while the protected line should
carry load. The line remains switched on for the duration of the measurement.
If the polarity of the parallel line earth current measurement is correct, the impedance measured in the tested
loop (in the example of Figure 3-30 this is L1-E) should be reduced by the influence of the parallel line (power
flow in both lines in the same direction). The impedance can be read out as primary or secondary quantity in
the list of operational measured values.
If, on the other hand, the measured impedance increases when compared to the value without parallel line
compensation, the current measuring input I4 has a swapped polarity. After isolation of both lines and short-
circuiting of the current transformer secondary circuits, the connections must be checked and rectified. Subse-
quently the measurement must be repeated.
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[polaritaetspruefung-parallelleitung-250702-kn, 1, en_GB]
Figure 3-30 Polarity check of Ι4, example with earth current of a parallel line
Ι4 from a Power Transformer Starpoint
If Ι4 is the earth current measured in the star-point of a power transformer and intended for the earth fault
protection direction determination (for earthed networks), then the polarity check can only be carried out with
zero sequence current flowing through the transformer. A test voltage source is required for this purpose
(singlephase low voltage source).
!
CAUTION
Feeding of zero sequence currents via a transformer without broken delta winding.
Inadmissible heating of the transformer is possible!
²Zero sequence current should only be routed via a transformer if it has a delta winding, therefore e.g.
Yd, Dy or Yy with a compensating winding.
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!
DANGER
Energized equipment of the power system! Capacitive coupled voltages at disconnected equipment of the
power system !
Non-observance of the following measure will result in death, severe personal injury or substantial
property damage.
²Primary measurements must only be carried out on disconnected and earthed equipment of the
power system!
The configuration shown in Figure 3-31 corresponds to an earth current flowing through the line, in other
words an earth fault in the forward direction.
At least one stage of the earth fault protection must be set to be directional (address 31xx of the earth fault
protection). The pickup threshold of this stage must be below the load current flowing on the line; if necessary
the pickup threshold must be reduced. The parameters that have been changed, must be noted.
[polaritaetspruefung-trafosternp-250702-kn, 1, en_GB]
Figure 3-31 Polarity check of Ι4, example with earth current from a power transformer star point
After switching the test source on and off again, the direction indication must be checked: The fault log must
at least contain the messages
EF Pickup
and
EF forward
. If the directional pickup is missing, a connection
error of the earth current connection Ι4 is present. If the wrong direction is indicated, the earth current
connection Ι4 has a swapped polarity. In the latter case, the connection must be corrected after the test source
has been switched off. The measurements must then be repeated.
If the pickup alarm is missing altogether, this may be due to the fact that the test current is too small.
i
i
NOTE
If parameters were changed for this test, they must be returned to their original state after completion of
the test !
Measuring the Operating Time of the Circuit Breaker
Only for Synchronism Check
If the device is equipped with the function for synchronism and voltage check and it is applied, it is necessary -
under asynchronous system conditions - that the operating time of the circuit breaker is measured and set
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correctly when closing. If the synchronism check function is not used or only for closing under synchronous
system conditions, this section is irrelevant.
For measuring the operating time a setup as shown in Figure 3-32 is recommended. The timer is set to a range
of 1 s and a graduation of 1 ms.
The circuit breaker is closed manually. At the same time the timer is started. After closing the circuit breaker
poles the voltage Usy1 or Usy2appears and the timer is stopped. 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 be repeated.
It is particularly favourable to calculate the mean value from several (3 to 5) successful switching attempts.
Set the calculated time under address 239 als T-CB close (under P.System Data 1). Select the next
lower settable value.
i
i
NOTE
The operating time of the accelerated output relays for command tripping is taken into consideration by
the device itself. The trip command is to be allocated to such a relay. If this is not the case, then add 3 ms
to the measured circuit breaker operating time for achieving a greater response time of the “normal” output
relay. If high-speed relays are used, on the other hand, you must deduct 4 ms from the measured circuit
breaker operating time.
[messung-der-ls-eigenzeit-260602-kn, 1, en_GB]
Figure 3-32 Measuring the circuit breaker closing time
Testing of the Teleprotection System with Distance Protection
i
i
NOTE
If the device is intended to operate with teleprotection, all devices used for the transmission of the signals
must initially be commissioned according to the corresponding instructions.
The following section applies only for the conventional transmission procedures. It is not relevant for usage
with protection data interfaces; refer also to the subsection “Test Mode for Teleprotection Scheme with
Protection Data Interface”.
For the functional check of the signal transmission, the earth fault protection should be disabled, to avoid
signals from this protection influencing the tests: address 3101 FCT EarthFltO/C = OFF.
Checking with Permissive Schemes
Requirements: Teleprot. Dist. is configured in address 121 to one of the comparison schemes using
permissive signal, i.e.POTT or Dir.Comp.Pickup or UNBLOCKING. Furthermore, at address 2101 FCT
3.3.13
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Telep. Dis. ON is switched. The corresponding send and receive signals must be assigned to the corre-
sponding binary output and input. For the echo function, the echo signal must be separately assigned to the
transmit output!
Detailed information on the permissive scheme function is available in Section 2.6 Teleprotection for distance
protection.
A simple check of the signal transmission path from one line end is possible via the echo function if these
permissive schemes are used. The echo function must be activated at both line ends, i.e. address 2501 FCT
Weak Infeed = ECHO only only; with the setting ECHO and TRIP a trip command may result at the
remote end of the check!
A short-circuit is simulated outside Z1, with POTT or UNBLOCKING inside Z1B, with Dir.Comp.Pickup some-
where in forward direction. This may be done with secondary injection test equipment. As the device at the
opposite line end does not pick up, the echo function comes into effect there, and consequently a trip
command is issued at the line end being tested.
If no trip command appears, the signal transmission path must be checked again, especially also the assign-
ment of the echo signals to the transmit outputs.
In case of a phase-segregated transmission the above-mentioned checks are carried out for each phase. The
correct phase allocation is also to be checked.
This test must be performed at both line ends, in the case of three terminal lines at each end for each signal
transmission path.
The functioning of the echo delay time and the derivation of the circuit breaker switching status should also
be tested at this time (the functioning of the protection at the opposite line end is tested):
The circuit breaker of the protected feeder must be opened. The circuit breaker at the opposite line end also
must be opened. As described above, a fault is again simulated. A receive signal impulse delayed by somewhat
more than twice the signal transmission time appears via the echo function at the opposite line end, and the
device generates a trip command.
The circuit breaker at the opposite line end is now closed (while the isolators remain open). After simulation of
the same fault, the receive and trip command appear again. In this case however, they are additionally
delayed by the echo delay time of the device at the opposite line end (0.04 s presetting, address 2502 Trip/
Echo DELAY).
If the response of the echo delay is opposite to the sequence described here, the operating mode of the corre-
sponding binary input (H-active/L-active) at the opposite line end must be rectified.
The circuit breaker must be opened again.
These tests must be performed at both line ends, on a three terminal line at each line end for each transmis-
sion path. However, please finally observe the last margin heading “Important for all procedures”!
Checking in Blocking Scheme
Requirements: Teleprot. Dist. is configured in address 121 to the comparison schemes using blocking
signal, i.e BLOCKING; in addition, at address 2101 FCT Telep. Dis. ON is switched. Naturally the corre-
sponding send and receive signals must also be assigned to the corresponding binary output and input.
For more details about the function of the blocking scheme refer to Subsection 2.6 Teleprotection for distance
protection. In the case of the blocking scheme, communication between the line ends is necessary.
On the transmitting end, a fault in the reverse direction is simulated, while at the receiving end a fault in Z1B
but beyond Z1 is simulated. This can be achieved with a set of secondary injection test equipment at each end
of the line. As long as the transmitting end is transmitting, the receiving end may not generate a trip signal,
unless this results from a higher distance stage. After the simulated fault at the transmitting line end has been
cleared, the receiving line end remains blocked for the duration of the transmit prolongation time of the trans-
mitting line end (Send Prolong., address 2103). If applicable, the transient blocking time of the receiving
line end (TrBlk BlockTime, address 2110) appears additionally if a finite delay time TrBlk Wait Time
(address 2109) has been set and exceeded.
In case of a phase-segregated transmission the above-mentioned checks are carried out for each phase. The
correct phase allocation is also to be checked.
This test must be performed at both line ends, on a three terminal line at each line end for each transmission
path. However, please finally observe the last margin heading “Important for all schemes”!
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Checking with Permissive Underreach Transfer Trip
Prerequisites: Teleprot. Dist.. is configured in address 121 to a permissive underreach transfer trip
scheme, i.e. PUTT (Z1B) or PUTT (Pickup). Furthermore, FCT Telep. Dis. is switched ON in address
2101. Naturally the corresponding send and receive signals must also be assigned to the corresponding binary
output and input.
Detailed information on the function of the permissive underreach transfer trip is available in Section 2.6 Tele-
protection for distance protection. Communication between the line ends is necessary.
On the transmitting end, a fault in zone Z1 must be simulated. This may be done with secondary injection test
equipment.
Subsequently, on the receiving end, when using PUTT (Z1B) a fault inside Z1B, but outside Z1 is simulated.
Tripping takes place immediately, (or in T1B), without signal transmission only in a higher distance stage. In
case of direct transfer trip, an immediate trip is always executed at the receiving end.
In case of a phase-segregated transmission the above-mentioned checks are carried out for each phase. The
correct phase allocation is also to be checked.
This test must be performed at both line ends, on a three terminal line at each line end for each transmission
path. However, please finally observe the last margin heading “Important for all schemes”!
Important for all Schemes
If the earth fault protection was disabled for the signal transmission tests, it may be re-enabled now. If setting
parameters were changed for the test (e.g. mode of the echo function or timers for unambiguous observation
of sequences), these must now be re-set to the prescribed values.
Testing of the Teleprotection System with Earth-fault Protection
This section is only relevant if the device is connected to an earthed system and earth fault protection is
applied. The device must therefore be provided with the earth fault detection function according to its
ordering code (16th MLFB position = 4 or 5 or 6 or 7). Which group of characteristics is to be available is deter-
mined during device configuration to Earth Fault O/C (address 131). Furthermore, the teleprotection
must be used for the earth fault protection (address 132 Teleprot. E/F configured to one of the possible
methods). If none of this is the case, this section is not relevant.
If the signal transmission path for the earth fault protection is the same path that was already tested in
conjunction with the distance protection according to the previous Section, then this Section is of no conse-
quence and may be skipped.
For the functional check of the earth fault protection signal transmission, the distance protection should be
disabled, to avoid interference of the tests by signals from the distance protection: address 1201 FCT
Distance = OFF.
Checking with Permissive Schemes
Requirements: Teleprot. E/F is configured in address 132 to one of the comparison schemes using
permissive signal, i.e. Dir.Comp.Pickup or UNBLOCKING; in addition, at address 3201 FCT Telep. E/F
ON is switched. The corresponding send and receive signals must be assigned to the corresponding binary
output and input. For the echo function, the echo signal must be separately assigned to the transmit output.
Detailed information on the function of the permissive scheme is given in Section 2.8 Teleprotection for earth
fault overcurrent protection (optional).
A simple check of the signal transmission path from one line end is possible via the echo circuit if these release
techniques are used. The echo function must be activated at both line ends, i.e. address 2501 FCT Weak
Infeed = ECHO only; with the setting ECHO and TRIP at the remote end of the check a trip command
may result!
An earth fault is simulated in the direction of the line. This may be done with secondary test equipment. As
the device at the opposite line end does not pick up, the echo function comes into effect there, and conse-
quently a trip command is generated at the line end being tested.
If no trip command appears, the signal transmission path must be checked again, especially also the assign-
ment of the echo signals to the transmit outputs.
3.3.14
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This test must be carried out at both line ends, in the case of three terminal lines at each end for each signal
transmission path.
The functioning of the echo delay time and monitoring of the circuit breaker switching status must also be
tested at this time if this has not already been done in the previous section (the operation of the protection at
the opposite line end is checked):
The circuit breaker on the protected feeder must be opened, as must be the circuit breaker at the opposite line
end. A fault is again simulated as before. A receive signal impulse delayed by somewhat more than twice the
signal transmission time appears via the echo function at the opposite line end, and the device generates a
trip command.
The circuit breaker at the opposite line end is now closed (while the isolators remain open). After simulation of
the same fault, the receive and trip command appear again. In this case however, they are additionally
delayed by the echo delay time of the device at the opposite line end (0.04 s presetting, address 2502 Trip/
Echo DELAY).
If the response of the echo delay is contrary to the sequence described here, the operating mode of the corre-
sponding binary input (H–active/L–active) at the opposite line end must be rectified.
The circuit breaker must be opened again.
This test must also be carried out at both line ends, in the case of three terminal lines at each line end and for
each signal transmission path. Finally, please observe the last margin heading “Important for All Schemes”!
Checking in Blocking Scheme
Prerequisites: Teleprot. E/F is configured in address 132 to one of the comparison schemes using
blocking signal, i.e BLOCKING. Furthermore, FCT Telep. E/F is switched ON at address 3201. The corre-
sponding send and receive signals must be assigned to the corresponding binary output and input.
For more details about the function of the blocking scheme refer to Section2.8 Teleprotection for earth fault
overcurrent protection (optional). In the case of the blocking scheme, communication between the line ends
is necessary.
An earth fault in reverse direction is simulated at the transmitting line end. Subsequently, a fault at the
receiving end in the direction of the line is simulated. This can be achieved with a set of secondary injection
test equipment at each end of the line. As long as the transmitting end is transmitting, the receiving end may
not generate a trip signal, unless this results from a higher distance stage. After the simulated fault at the
transmitting line end is switched off, the receiving line end remains blocked for the duration of the transmit
prolongation time of the transmitting line end (Send Prolong., address 3203). If applicable, the transient
blocking time of the receiving line end (TrBlk BlockTime, address 3210) is added if a finite delay time
TrBlk Wait Time (address 3209) has been set and exceeded.
This test must be performed at both line ends, on a three terminal line at each line end for each transmission
path. However, please finally observe the last margin heading “Important for All Schemes”!
Important for all Schemes
If the distance protection was switched off for the signal transmission tests, it may be switched on now. If
setting parameters were changed for the test (e.g. mode of the echo function or timers for unambiguous
observation of sequences), these must now be re-set to the prescribed values.
Check of the Signal Transmission for Breaker Failure Protection and/or End
Fault Protection
If the transfer trip command for breaker failure protection or stub fault protection is to be transmitted to the
remote end, this transmission must also be checked.
To check the transmission the breaker failure protection function is initiated by a test current (secondary) with
the circuit breaker in the open position. Make sure that the correct circuit breaker reaction takes place at the
remote end.
Each transmission path must be checked on lines with more than two ends.
3.3.15
Mounting and Commissioning
3.3 Commissioning
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Check of the Signal Transmission for Internal and External Remote Tripping
The 7SA522 provides the possibility to transmit a remote trip signal to the opposite line end if a signal trans-
mission path is available for this purpose. This remote trip signal may be derived from both an internally
generated trip signal as well as from any signal coming from an external protection or control device.
If an internal signal is used, the initiation of the transmitter must be checked. If the signal transmission path is
the same and has already been checked as part of the previous sections, it need not be checked again here.
Otherwise the initiating event is simulated and the response of the circuit breaker at the opposite line end is
verified.
In the case of the distance protection, the permissive underreach scheme may be used to trip the remote line
end. The procedure is then the same as was the case for permissive underreach (under “Checking with Permis-
sive Underreach Transfer Trip”); however the received signal causes a direct trip.
For the remote transmission, the external command input is employed on the receiving line end; it is therefore
a prerequisite that: DTT Direct Trip is set to Enabled in address 122 and FCT Direct Trip is set to
ON in address 2201. If the signal transmission path is the same and has already been checked as part of the
previous sections, it need not be checked again here. A function check is sufficient, whereby the externally
derived command is executed. For this purpose, the external tripping event is simulated and the response of
the circuit breaker at the opposite line end is verified.
Testing User-defined Functions
The device 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 must be checked.
A general procedure cannot in the nature of things be specified. Configuration of these functions and the set
value conditions must be actually known beforehand and tested. Especially, possible interlocking conditions of
the switching devices (circuit breakers, isolators, grounding electrodes) must be observed and checked.
Trip and Close Test with the Circuit Breaker
The circuit breaker and tripping circuits can be conveniently tested by the device 7SA522.
The procedure is described in detail in the SIPROTEC 4 System Description.
If the check does not produce the expected results, the cause may be established from the text in the display
of the device or the PC. If necessary, the connections of the circuit breaker auxiliary contacts must be checked:
It must be noted that the binary inputs used for the circuit breaker auxiliary contacts must be assigned sepa-
rately for the CB test. This means it is not sufficient that the auxiliary contacts are allocated to the binary
inputs No. 351 to 353, 379 and 380 (according to the possibilities of the auxiliary contacts); additionally, the
corresponding No. 366 to 368 or 410 and/or 411 must be allocated (according to the possibilities of the auxil-
iary contacts). In the CB test only the latter ones are analyzed. See also Section 2.20.2 Circuit breaker trip test.
Furthermore, the ready state of the circuit breaker for the CB test must be indicated to the binary input with
No. 371.
Switching Test of the Configured Operating Equipment
Switching by Local Command
If the configured operating devices were not switched sufficiently in the hardware test already described, all
configured switching devices must be switched on and off from the device via the integrated control element.
The feedback information of the CB position injected via binary inputs should be read out and compared with
the actual breaker position.
For devices with graphic display this is easy to do with the control display.
3.3.16
3.3.17
3.3.18
3.3.19
Mounting and Commissioning
3.3 Commissioning
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The switching procedure is described in the SIPROTEC 4 System Description. The switching authority must be
set in correspondence with the source of commands used. With the switching mode, you can choose between
locked and unlocked switching. In this case, you must be aware that unlocked switching is a safety risk.
Switching from a Remote Control Centre
If the device is connected to a remote substation via a system (SCADA) interface, the corresponding switching
tests may also be checked from the substation. Please also take into consideration that the switching authority
is set in correspondence with the source of commands used.
Triggering Oscillographic Recording for Test
In order to verify the reliability of the protection relay even during inrush processes, closing tests can be
carried out to conclude the commissioning process. Oscillograhpic records provide the maximum information
about the behavior of the protection relay.
Prerequisite
Along with the capability of storing fault recordings via pickup of the protection function, the 7SA522 also has
the capability of capturing the same data when commands are given to the device via the DIGSI software, the
serial interface, or a binary input. For the latter, the information
>Trig.Wave.Cap.
must be allocated to a
binary input. In this case, a fault record is triggered e.g. via binary input when the protected object is ener-
gized.
Such a test fault record triggered externally (i.e. not caused by pickup of a protection function) is processed
like a normal oscillographic record, i.e. a fault log with number is generated which univocally identifies an
oscillographic record. However, these recordings are not displayed in the trip log as they are not fault events.
Start Test Measurement Recording
To trigger test measurement recording with DIGSI, click on Test in the left part of the window. Double click in
the list view the Test Wave Form entry (see Figure 3-33).
3.3.20
Mounting and Commissioning
3.3 Commissioning
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[7sa-testmessschrieb-starten-310702-kn, 1, en_GB]
Figure 3-33 Triggering oscillographic recording with DIGSI — example
Oscillographic recording is immediately started. During the recording, an annunciation is output in the left
area of the status line. Bar segments additionally indicate the progress of the procedure.
The SIGRA or the Comtrade Viewer program is required to view and analyze the oscillographic data.
Mounting and Commissioning
3.3 Commissioning
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Final Preparation of the Device
The used terminal screws must be tightened, including those that are not used. All the plug connectors must
be correctly inserted.
!
CAUTION
Do not apply force!
The tightening torques must not be exceeded as the threads and terminal chambers may otherwise
be damaged!
²
The setting values should be checked again if they were changed during the tests. Check if protection,
control and auxiliary functions to be found with the configuration parameters are set correctly (Section
2.1.1 Functional Scope, Functional Scope). All desired functions must be switched ON. Ensure that a copy of
the setting values is stored on the PC.
Check the internal clock of the device. If necessary, set the clock or synchronize the clock if the element is not
automatically synchronized. Further details on this subject are described in /1/ SIPROTEC 4 System Description.
The indication buffers are deleted under Main Menu → Annunciation → Set/Reset, so that in the future they
only contain information on actual events and states. The numbers in the switching statistics should be reset
to the values that were existing prior to the testing.
The counters of the operational measured values (e.g. operation counter, if available) are reset under Main
Menu → Measurement → Reset.
Press theESC key, several times if necessary, to return to the default display.
Clear the LEDs on the front panel by pressing the LED key, so that they only show real events and states. In
this context, saved output relays are reset, too. Pressing the LED key also serves as a test for the LEDs on the
front panel because they should all light when the button is pressed. If the LEDs display states relevant by that
moment, these LEDs, of course, stay lit.
The green “RUN” LED must light up, whereas the red “ERROR” must not light up.
Close the protective switches. If test switches are available, then these must be in the operating position.
The device is now ready for operation.
3.4
Mounting and Commissioning
3.4 Final Preparation of the Device
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Technical Data
This chapter presents the technical data of SIPROTEC 4 7SA522 device and its individual functions, including
the limit values that must not be exceeded under any circumstances. The electrical and functional data of fully
equipped devices are followed by the mechanical data, with dimensional drawings.
4.1 General 430
4.2 Distance Protection 441
4.3 Power Swing Detection (with impedance pickup) (optional) 444
4.4 Distance Protection Teleprotection Schemes 445
4.5 Earth Fault Protection (optional) 446
4.6 Earth Fault Protection Teleprotection Schemes (optional) 455
4.7 Weak-infeed Tripping (classical) 456
4.8 Weak-infeed Tripping (French Specification) 457
4.9 Protection Data Interface and Communication Topology (optional) 458
4.10 External Direct and Remote Tripping 461
4.11 Time Overcurrent Protection 462
4.12 Instantaneous High-current Switch-onto-fault Protection 465
4.13 Automatic Reclosure (optional) 466
4.14 Synchronism and Voltage Check (optional) 467
4.15 Voltage Protection (optional) 468
4.16 Frequency Protection (optional) 471
4.17 Fault Locator 472
4.18 Circuit Breaker Failure Protection (optional) 473
4.19 Monitoring Functions 474
4.20 Transmission of Binary Information (optional) 476
4.21 User-defined Functions (CFC) 477
4.22 Additional Functions 481
4.23 Dimensions 484
4
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General
Analogue Inputs and Outputs
Nominal Frequency fN50 Hz or 60 Hz (adjustable)
Current Inputs
Nominal current ΙN1 A or 5 A
Power Consumption per Phase and Earth Path
- at ΙN = 1 A Approx. 0.05 VA
- at ΙN = 5 A Approx. 0.3 VA
- for sensitive earth fault detection at 1A Approx.. 0.05 VA
Current Overload Capability per Current Input
- thermal (rms) 500 A for 1 s
150 A for 10 s
4 · ΙN continuous
- dynamic (pulse current) 1250 A (half-cycle)
Current Overload Capability for Sensitive Earth Current Input
- thermal (rms) 300 A for 1 s
100 A for 10 s
15 A continuous
- dynamic (pulse current) 750 A(half-cycle)
Voltage Inputs
Rated Voltage UN80 V to 125 V (adjustable)
Power consumption per phase at100 V ≤ 0.1 VA
Voltage Overload Capability in Voltage Path per Input
- thermal (rms) 230 V continuous
Auxiliary voltage
DC Voltage
Voltage supply via integrated converter
Rated auxiliary voltage Uaux- DC 24 V/48 V DC 60 V/110 V/
125 V
DC 110 V/125 V/
220 V/250 V
DC 220 V/250 V
Permissible voltage ranges DC 19 V to
58 V
DC 48 V to
150 V
DC 88 V to 300 V DC 176 V to
300 V
Superimposed AC ripple voltage,
Peak to peak ≤ 15 % of the auxiliary nominal voltage
Power input
- not energized Approx. 5 W
- energized
7SA522*-*A/E/J Approx. 12 W
7SA522*-*C/G/L/N/Q/S Approx. 15 W
7SA522*-*D/H/M/P/R/T/W Approx. 18 W
4.1
4.1.1
4.1.2
Technical Data
4.1 General
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7SA522*-*U Approx. 20 W
Plus approx. 1.5 W per interface module
Bridging time for failure / short circuit of DC
auxiliary voltage
≥ 50 ms at Uaux = 48 V und Uaux ≥ 110 V
≥ 20 ms at Uaux = 24 V und Uaux = 60 V
AC Voltage
Voltage Supply via Integrated Converter
Nominal Auxiliary Voltage AC Uaux AC 115 V
Permissible voltage ranges AC 92 V to 132 V
Power Input (at AC 115 V/ 230 V)
- not energized ca. 7 VA
- energized
7SA522*-*A/E/J Approx. 17 VA
7SA522*-*C/G/L/N/Q/S Approx. 20 VA
7SA522*-*D/H/M/P/R/T/W Approx. 23 VA
7SA522*-*U Approx. 25 VA
Plus approx. 1,5 VA per Interface Module
Bridging time for failure/short circuit of alternating auxil-
iary voltage
≥ 50 ms
Binary Inputs and Outputs
Binary Inputs
Variant Quantity
7SA522*-*A/E/J 8 (configurable)
7SA522*-*C/G/L/N/Q/S 16 (configurable)
7SA522*-*U 22 (configurable)
7SA522*-*D/H/M/P/R/T/W 24 (configurable)
Rated voltage range DC 24 V to 250 V, in 3 ranges, bipolar
Switching Thresholds Switching Thresholds, adjustable voltage range with jumpers
- for rated voltages DC 24 V/48 V
DC 60 V/110 V/125 V
Uhigh ≥ DC 19 V
Ulow ≤ DC 10 V
- for rated voltages DC 110 V/125 V/220 V/250 V Uhigh ≥ DC 88 V
Ulow ≤ DC 44 V
- for rated voltages DC 220 V/250 V Uhigh ≥ DC 176 V
Ulow ≤ DC 88 V
Current consumption, energized Approx. 1.8 mA
independent of the control voltage
Maximum admissible voltage DC 300 V
Impulse filter on input 220 nF coupling capacitance at 220 V with recovery time > 60 ms
4.1.3
Technical Data
4.1 General
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Binary Outputs
Signalling / Command Relays (see also terminal assignments in the Appendix)
Quantity and Data According to the Order Variant (configurable)
Order Variant UL listed NO Contact
(normal) 1)
NO Contact
(fast) 1)
NO/NC (select-
able) 1)
NO contact
(high-speed) 1)
7SA522*-*A/E/J x 7 7 1 -
7SA522*-*C/G/L x 14 7 2 -
7SA522*-*N/Q/S x 7 10 1 5
7SA522*-*D/H/M x 21 7 3 -
7SA522*-*P/R/T x 14 10 2 5
7SA522*-*U x 30 7 6 -
7SA522*-*W x - 18 3 10
Switching capability ON 1000 W/VA 1000 W/VA
OFF 30 VA
40 W resistive
25 W/VA at L/R ≤ 50 ms
1000 W/VA
Switching voltage
DC 250 V
AC 250 V 200 V (max.)
Permissible current per contact ( continuous) 5 A
Permissible current per contact (close and hold) /
pulse current
30 A for 0.5 s (NO contact)
Total current on common path 5 A continuous
30 A für 0.5 s
Operating time, approx. 8 ms 5 ms 8 ms 1 ms
Alarm relay 1)With 1 NC contact or 1 NO contact (switchable)
Switching capability ON 1000 W/VA
OFF 30 VA
40 W resistive
25 W at L/R ≤ 50 ms
Switching voltage 250 V
Permissible current per contact 5 A continuous
30 A for 0.5 s
1) UL-listed with the following rated data:
AC 120 V Pilot duty, B300
AC 240 V Pilot duty, B300
AC 240 V 5 A General Purpose
DC 24 V 5 A General Purpose
DC 48 V 0.8 A General Purpose
DC 240 V 0.1 A General Purpose
AC 120 V 1/6 hp (4.4 FLA)
AC 240 V 1/2 hp (4.9 FLA)
Communication Interfaces
Protection Data Interface
see Section “Protection Data Interfaces and Communication Topology”
4.1.4
Technical Data
4.1 General
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Operator Interface
Connection Front side, non-isolated, RS232,
9-pin D-subminiature female connector for connection of a PC
Operation With DIGSI
Transmission rate Min. 4800 Baud; max. 115200 Baud;
Factory Setting: 38400 Baud; Parity: 8E1
Transmission distance 15 m / 50 feet
Service / Modem Interface (optional)
Connection
Acc. to ordered variant
isolated interface for data transfer
Operation With DIGSI
RS232/RS485
Connection for Flush-Mounted Housing Rear panel, mounting location “C”,
9-pole D-subminiature Female Connector
Shielded data cable
Connector for surface mounted case At two-tier terminal on the housing bottom1)
at the inclined housing on the case bottom2)
9-pole D-subminiature Female Connector
Shielded data cable
Test voltage 500 V; 50 Hz
Transmission speed min. 4800 Baud; max. 115200 Baud
Factory setting 38400 Baud
RS232
Bridgeable distance 15 m
RS485
Bridgeable distance 1000 m
Fibre optic cable (FO)
FO connector type ST connector
Connection for Flush-Mounted Housing Rear panel, mounting location “C”
Connector for surface mounted case In console housing at device bottom
optical wavelength λ = 820 nm
Laser Class 1 according to EN
60825-1/-2
when using glass fiber 50 μm/125 μm or
when using glass fiber 62,5 μm/125 μm
Permissible Optical Link Signal Attenua-
tion
max. 8 dB, bei Glasfaser 62,5 μm/125 μm
Bridgeable distance max. 1.5 km
Character idle state Selectable, factory setting “Light off”
1)Up to release /DD
2)Release /EE and higher
System Interface (optional)
Connection
acc. to version ordered
potentialfreie Schnittstelle für Datentransfer zu einer Leitstelle
RS232
Connection for flush-mounted housing rear panel, slot “B”,
9-pole D-subminiature female connector
Technical Data
4.1 General
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Connection for surface-mounted
housing
at the bottom side of the console housing
9-pole D-subminiature female connector
Test voltage 500 V; 50 Hz
Transmission rate min. 4800 Baud, max. 38400 Baud
Factory setting 19200 baud
Transmission distance max. 15 m
RS485
Connection for flush-mounted housing rear panel, slot “B”,
9-pole D-subminiature female connector
Connection for surface-mounted
housing
at the bottom side of the console housing
9-pole D-subminiature female connector
Test voltage 500 V; 50 Hz
Transmission rate min. 4800 Bd, max. 38400 Bd
Factory setting 19200 baud
Transmission distance max. 1 km
Optical fibre cable (FO
FO connector type ST connector
Connection for flush-mounted housing rear panel, slot “B”
Connection for surface-mounted
housing
at bottom side of the console housing
Optical wavelength λ = 820 nm
Laser class 1 according to EN
60825-1/-2
Using glass fiber 50/125 μm or
Using glass fibre 62.5/125 μm
Permissible optical signal attenuation Max. 8 dB, with glass fibre 62.5/125 μm
Maximum transmission distance max. 1.5 km
Character idle state Selectable, factory setting“Light off”
Profibus RS485 (FMS and DP)
Connection for flush-mounted housing rear panel, slot “B”,
9-pole D-subminiature female connector
Connection for surface-mounted
housing
at the bottom side of the console housing
9-pole D-subminiature female connector
Test voltage 500 V; 50 Hz
Transmission rate bis 12 MBaud
Transmission distance 1000 m at ≤ 93.75 kBaud
500 m at ≤ 187.5 kBaud
200 m at ≤ 1.5 MBaud
100 m at ≤ 12 MBaud
Profibus FO (FMS and DP)
FO connector type ST connector single ring / double ring
FMS: depending on ordered version;
DP: only double ring available
Connection for flush-mounted housing rear panel, slot “B”
Connection for surface-mounted
housing
Please use the version with Profibus RS485 in the console housing and a sepa-
rate electrical/ optical converter.
Transmission rate Conversion by means of external OLM up to 1.5 MBaud
≥ 500 kBaud for normal version
≤ 57600 Baud with detached operator panel
Recommended transmission rate: > 500 kBaud
Optical wavelength λ = 820 nm
Technical Data
4.1 General
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Laser class 1 according to EN
60825-1/-2
Using glass fiber 50/125 μm or
Using glass fibre 62.5/125 μm
Permissible optical signal attenuation Max. 8 dB, with glass fibre 62.5/125 μm
Transmission distance between two
modules with redundant optical ring
topology and glass fibre 62.5/125 m
2 m with plastic fibre
500 kBit/s max. 1.6 km
1500 kBit/s 530 m
Character idle state (status for “No
character”)
Light OFF
Max. number of modules in optical
rings with 500 kB/s or 1500 kB/s
41
DNP3.0 RS485
Connection for flush-mounted housing rear panel, slot “B”,
9-pole D-subminiature female connector
Connection for surface-mounted
housing
in console housing
Test voltage 500 V; 50 Hz
Transmission rate up to 19200 Baud
Transmission distance max. 1 km
DNP3.0 FO
FO connector type ST connector receiver/transmitter
Connection for flush-mounted housing rear panel, slot “B”
Connection for surface-mounted
housing
in console housing
Transmission rate up to 19200 Baud
Optical wavelength λ = 820 nm
Laser class 1 according to
EN60825-1/-2
Using glass fibre 50/125 μm or
Using glass fibre 62.5/125 μm
Permissible optical signal attenuation max. 8 dB, with glass fibre 62.5/125 μm
Transmission distance max. 1.5 km
Ethernet electrical (EN 100) for IEC 61850 and DIGSI
Connection for flush-mounted housing rear panel, slot “B”
2 x RJ45 female connector
100BaseT acc. to IEEE802.3
Connection for surface-mounted
housing
in console housing
Test voltage (female connector) 500 V; 50 Hz
Transmission rate 100 MBit/s
Transmission distance 20 m
Ethernet optisch (EN100) für IEC 61850 und DIGSI
FO connector type ST connector receiver/transmitter
Connection for flush-mounted housing rear panel, slot “B”
Connection for surface-mounted
housing
not available
Transmission rate λ = 1350 nm
Optical wavelength 100 MBit/s
Laser class 1 according to
EN60825-1/-2
Using glass fibre 50 μm/125 μm or Using glass fibre 62,5 μm/125 μm
Permissible optical signal attenuation max. 5 dB, with glass fibre 62,5 μm/125 μm
Transmission distance max. 800 m
Technical Data
4.1 General
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Time Synchronisation Interface
Time synchronization DCF77/IRIG B signal (telegram format IRIG-B000)
Connection for flush-mounted housing rear panel, slot “A”;
9-pole D-subminiature female connector
Connection for surface-mounted
housing
At the double-deck terminal on the case bottom
Signal nominal voltages Selectable 5 V, 12 V or 24 V
Test voltage 500 V; 50 Hz
Signal levels and burdens DCF77/IRIG-B:
Nominal Signal Voltage
5 V 12 V 24 V
UIHigh 6.0 V 15.8 V 31 V
UILow 1.0 V at ΙILow = 0.25 mA 1.4 V at ΙILow = 0.25 mA 1.9 V at ΙILow = 0.25 mA
ΙIHigh 4.5 mA to 9.4 mA 4.5 mA to 9.3 mA 4.5 mA to 8.7 mA
RI890 Ω at UI = 4 V 1930 Ω at UI = 8.7 V 3780 Ω at UI = 17 V
640 Ω at UI = 6 V 1700 Ω at UI = 15.8 V 3560 Ω at UI = 31 V
Electrical Tests
Specifications
Standards: IEC 60255 (product standards))
IEEE Std C37.90.0/.1/.2
UL 508
VDE 0435
For more standards see also individual functions
Insulation Test
Standards: IEC 60255-5 and IEC 60870-2-1
High voltage test (routine test)
All circuits except power supply, Binary Inputs, High
Speed Outputs, Communication Interface and Time
Synchronization Interfaces
2.5 kV (rms), 50 Hz
High voltage test (routine test)
Auxiliary voltage, binary inputs and high speed outputs
DC 3.5 kV
High voltage test (routine test)
only isolated communication and time synchronization
interfaces
500 V (rms), 50 Hz
Impulse voltage test (type test)
All Circuits Except Communication and Time Synchroni-
zation Interfaces, Class III
5 kV (peak), 1.2/50 μs, 0.5 Ws, 3 positive and 3 negative
impulses at intervals of 5 s
EMC Tests for Interference Immunity (Type Tests)
Standards: IEC 60255-6 and -22, (product standards)
EN 61000-6-2 (generic standard)
VDE 0435 part 301DIN VDE 0435-110
4.1.5
Technical Data
4.1 General
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High frequency test
IEC 60255-22-1, Class III
and VDE 0435 Teil 303, Class III
2.5 kV (Peak); 1 MHz; τ = 15 μs; 400 surges per s; test duration
2 s; Ri = 200 Ω
Electrostatic discharge
IEC 60255-22-2, Class IV
and IEC 61000-4-2, Class IV
8 kV contact discharge; 15 kV air discharge, both polarities;
150 pF; Ri = 330 Ω
Irradiation with HF field, frequency sweep
IEC 60255-22-3, Class III
IEC 61000-4-3, Class III
10 V/m; 80 MHz to 1000 MHz; 80 % AM; 1 kHz
10 V/m; 800 MHz to 960 MHz; 80 % AM; 1 kHz
20 V/m; 1,4 GHz to 2,0 GHz; 80 % AM; 1 kHz
Irradiation with HF field, single frequencies
IEC 60255-22-3, IEC 61000-4-3, Class III
– amplitude-modulated
– pulse-modulated
10 V/m
80 MHz; 160 MHz; 450 MHz; 900 MHz; 80 % AM; 1 kHz; duty
cycle > 10 s
900 MHz; 50 % PM, repetition frequency 200 Hz
Fast transient disturbances
Burst IEC 60255-22-4 and IEC 61000-4-4, Class IV
4 kV; 5 ns/50 ns; 5 kHz; burst length = 15 ms; repetition 300
ms; both polarities; Ri = 50 Ω; test duration 1 min
High energy surge voltages (SURGE),
IEC 61000-4-5 installation Class 3
- Auxiliary voltage
– Analog measuring inputs, binary inputs, relay outputs
Pulse: 1.2 μs/50 μs
common mode: 2 kV; 12 Ω; 9 µF
diff. mode: 1 kV; 2 Ω; 18 µF
common mode: 2 kV; 42 Ω; 0,5 µF
diff. mode: 1 kV; 42 Ω; 0,5 µF
Line conducted HF, amplitude modulated
IEC 61000-4-6, Class III
10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz
Power system frequency magnetic field
IEC 60255-6
IEC 61000-4-8, Class IV
0,5 mT; 50 Hz,
30 A/m continuous; 300 A/m for 3 s; 50 Hz
Oscillatory Surge Withstand Capability
IEEE Std C37.90.1
2.5 kV (Peak); 1 MHz; τ = 15 μs; 400 Surges per s; test duration
2 s; Ri = 200 Ω
Fast Transient Surge Withstand Cap.
IEEE Std C37.90.1
4 kV; 5 ns/50 ns; 5 kHz; burst length = 15 ms; repetition rate
300 ms; both polarities; Ri = 50 Ω; test duration 1 min
Radiated Electromagnetic Interference
IEEE Std C37.90.2
35 V/m; 25 MHz to 1000 MHz
Damped oscillations IEC 60694, IEC 61000-4-12 2.5 kV (peak value), polarity alternating 100 kHz, 1 MHz, 10
MHz and 50 MHz Ri = 200 Ω
EMC Tests for Interference Emission (Type Test)
Standard: EN 61000-6-3 (generic standard)
Radio noise voltage to lines, only auxiliary voltage
IECCISPR 22
150 kHz to 30 MHz
Limit class B
Interference field strength
IEC-CISPR 22
30 MHz to 1000 MHz
Limit class B
Harmonic currents on the network lead at AC 230 V
IEC 61000-3-2
Class A limits are observed
Voltage fluctuations and flicker on the network lead at
AC 230 V
IEC 61000-3-3
Limits are observed
Technical Data
4.1 General
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Mechanical Tests
Vibration and Shock Resistance during Stationary Operation
Standards: IEC 60255-21 and IEC 60068
Oscillation
IEC 60255-21-1, Class 2
IEC 60068-2-6
Sinusoidal
10 Hz to 60 Hz: ± 0,075 mm amplitude;
60 Hz to 150 Hz: 1 g Acceleration
Frequency sweep 1 octave/min
20 cycles in 3 orthogonal axes
Shock
IEC 60255-21-2, Class 1
IEC 60068-2-27
Semi-sinusoidal
5 g acceleration, duration 11 ms,
each 3 shocks (in both directions of the 3 axes)
Seismic vibration
IEC 60255-21-3, Class 1
IEC 60068-3-3
Sinusoidal
1 Hz to 8 Hz: ± 3,5 mm amplitude (horizontal axis)
1 Hz to 8 Hz: ± 1,5 mm amplitude (vertical axis)
8 Hz to 35 Hz: 1 g acceleration (horizontal axis)
8 Hz to 35 Hz: 0,5 g acceleration (vertical axis)
Frequency sweep 1 octave/min
1 cycle in 3 orthogonal axes
Vibration and Shock Resistance during Transport
Standards: IEC 60255-21 and IEC 60068
Oscillation
IEC 60255-21-1, Class 2
IEC 60068-2-6
Sinusoidal
5 Hz to 8 Hz: ± 7,5 mm amplitude;
8 Hz to 150 Hz: 2 g acceleration
frequency sweep 1 octave/min
20 cycles in 3 orthogonal axes
Shock
IEC 60255-21-2, Class 1
IEC 60068-2-27
Semi-sinusoidal
15 g acceleration, duration 11 ms,
each 3 shocks (in both directions of the 3 axes)
Continuous shock
IEC 60255-21-2, Class 1
IEC 60068-2-29
Semi-sinusoidal
10 g acceleration, duration 16 ms,
1000 shocks each in both directions of the 3 axes
Climatic Stress Tests
Temperatures
Standards: IEC 60255-6
Type tested (acc. IEC 60086-2-1 and -2, Test Bd) -25 °C to +85 °C or -13 °F to +185 °F
Admissible temporary operating temperature (tested for
96 h)
-20 °C to +70 °C or -4 °F to +158 °F (legibility of display may be
restricted from +55 °C or 131 °F)
Recommended for permanent operation (according to
IEC 60255-6)
-5 °C to +55 °C or 23 °F to +131 °F
If max. half of the inputs and outputs are subjected to the max.
permissible values
Limit temperatures for storage -25 °C to +55 °C or -13 °F to +131 °F
Limit temperatures during transport -25 °C to +70 °C or -13 °F to +158 °F
4.1.6
4.1.7
Technical Data
4.1 General
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Storage and transport of the device with factory packaging!
1) Limit temperatures for normal operation (i.e. output
relays not energized)
-20 °C to +70 °C or -4 °F to +158 °F
1) Limit temperatures under maximum load (max. cont.
admissible input and output values)
–5 °C to +40 °C for 1/2 and 1/1 housing
1) UL-certified according to Standard 508 (Industrial Control Equipment)
Humidity
Admissible humidity Annual average ≤ 75 % relative humidity;
On 56 days of the year up to 93% relative humidity. Condensa-
tion must be avoided in operation!
It is recommended that all devices be installed so that they are not exposed to direct sunlight nor subject to large fluctu-
ations in temperature that may cause condensation to occur.
Deployment Conditions
The protection device is designed for installation in normal relay rooms and plants, so that electromagnetic immunity is
ensured if installation is done properly.
In addition the following is recommended:
•Contacts and relays operating within the same cabinet or on the same relay board with digital protection equip-
ment, should be in principle provided with suitable surge suppression components.
•For substations with operating voltages of 100 kV and above, all external cables shall be shielded with a conductive
shield earthed at both ends. For substations with lower operating voltages, no special measures are normally
required.
•For substations with lower operating voltages, no special measures are normally required. When removed, many
components are electrostatically endangered; when handling the EEC standards (standards for Electrostatically
Endangered Components) must be observed. The modules, boards, and device are not endangered when the
device is completely assembled.
Certifications
UL listing UL recognition
7SA522*-*A***-****
Models with threaded terminals
7SA522*-*J***-****
Models with plug–in terminals
7SA522*-*C***-**** 7SA522*-*L***-****
7SA522*-*D***-**** 7SA522*-*M***-****
7SA522*-*U***-****
7SA522*-*W***-****
Construction
Housing 7XP20
Dimensions See dimensional drawings, Section4.23 Dimensions
Device (for maximum number of components) Size Weight
For panel flush mounting
1/26 kg
1/110 kg
For panel surface mounting
1/211 kg
1/119 kg
4.1.8
4.1.9
4.1.10
Technical Data
4.1 General
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Degree of protection according to IEC 60529
For equipment of the panel surface mounting housing IP 51
For equipment of the panel flush-mounting housing
Front IP 51
Rear IP 50
For human safety IP 2x with cover
UL-certification conditions Type 1 for front panel mounting
Technical Data
4.1 General
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Distance Protection
Earth Impedance Ratio
RE/RL-0.33 to 7.00 Increments 0.01
XE/XL-0.33 to 7.00 Increments 0.01
Separate for first and higher zones
K00.000 to 4.000 Increments 0.o01
PHI (K0) -135.00° to +135.00°
Separate for first and higher zones
The matching factors for earth impedance are valid also for fault locating.
Mutual Impedance Ratio
RM/RL0.00 to 8.00 Increments 0.01
XM/XL0.00 to 8.00 Increments 0.01
The matching factors for the mutual impedance ratio are valid also for fault locating.
Phase preference
For double earth fault in earthed net Block leading phase-earth
Block lagging phase-earth
Release all associated loops
Release only phase-to-earth loops
Release of phase-to-phase loops
For double earth fault in isolated or resonant-earthed
systems
L3(L1) acyclic
L1(L3) acyclic
L2(L1) acyclic
L1(L2) acyclic
L3(L2) acyclic
L2(L3) acyclic
L3(L1) cyclic
L1(L3) cyclic
All associated loops
Earth fault detection
Earth current3Ι0> for ΙN = 1 A 0.05 A to 4.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 20.00 A
Earth voltage 3U0> 1 V to 100 V; ∞ Increments 1 V
Dropout to pickup ratio ca. 0.95
Measuring tolerances for sinusoidal measured values ± 5 %
Distance Measurement
Charakteristic Polygonal or MHO characteristic; 6 independent zones and 1
controlled zone
Setting ranges polygon:
IPh> = min. current, phases for IN = 1 A 0.05 A to 4.00 A Increments 0.01 A
for IN = 5 A 0.25 A to 20.00 A
4.2
Technical Data
4.2 Distance Protection
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X = reactance reach for IN = 1 A 0.050 Ω to 600.000 Ω Increments 0.001 Ω
for IN = 5 A 0.010 Ω to 120.000 Ω
R = resistance tolerance phase-phase for IN = 1 A 0.050 Ω to 600.000 Ω Increments 0.001 Ω
for IN = 5 A 0.010 Ω to 120.000 Ω
RE = resistance tolerance phase-earth for IN = 1 A 0.050 Ω to 600.000 Ω Increments 0.001 Ω
for IN = 5 A 0.010 Ω to 120.000 Ω
φLine = line angle 10° to 89° Increments 1°
φDist = angle of distance protection characteristic 30° to 90° Increments 1°
αPol = tilt angle for 1st zone 0° to 30° Increments 1°
Direction determination for polygonal characteristic:
For all types of faults With phase-true, memorized or cross-polarized voltages
Directional sensitivity Dynamically unlimited
stationary approx. 1 V
Each zone can be set to operate in forward or reverse direction, non-directional or ineffective.
Setting ranges of the MHO characteristic:
IPH> = min. current, phases for IN = 1 A 0.05 A to 4.00 A Increments 0.01 A
for IN = 5 A 0.25 A to 20.00 A
Zr = impedance range for IN = 1 A 0.050 Ω to 200.000 Ω Increments 0.001 Ω
for IN = 5 A 0.010 Ω to 40.000 Ω
φLine = line angle 10° to 89° Increments 1°
φDist = angle of distance protection characteristic 30° to 90° Increments 1°
Polarization With memorized or cross-polarized voltages
Each zone can be set to operate in forward or reverse direction or ineffective.
Load trapezoid:
RLoad = minimum load resistance for IN = 1 A 0.050 Ω to 600.000 Ω; ∞ Increments 0.001 Ω
for IN = 5 A 0.010 Ω to 120.000 Ω; ∞
φLoad = maximum load angle 20° to 60° Increments 1°
Drop-off to pick-up ratio
– currents ca. 0.95
– impedances ca. 1.06
Measured value correction Mutual impedance matching for parallel lines
Measuring tolerances for sinusoidal measured values
Times
Shortest trip time Approx. 17 ms (50 Hz) /15 ms (60 Hz) with fast relay and
Approx. 12 ms (50 Hz) /10 ms (60 Hz) with high-speed relay
Dropout time Approx. 30 ms
Technical Data
4.2 Distance Protection
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Stage timers 0.00 s to 30.00 s; ∞
for all zones; separate time
setting possibilities for single-
phase and multiphase faults for
the zones Z1, Z2, and Z1B
Increments 0.01 s
Time expiry tolerances 1 % of setting value or 10 ms
The set times are pure delay times.
The interval from fault inception to trip command is made up of the set delay time plus the measuring time.
The minimum measuring time is 10 ms, for faults close to the set zone boundary the maximum measuring time is
approximately 40 ms.
Emergency Operation
In case of measured voltage failure, e.g. voltage transformer mcb trip see Section “Time Overcurrent Protection”
Technical Data
4.2 Distance Protection
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Power Swing Detection (with impedance pickup) (optional)
Power swing detection Rate of change of the impedance phasor and
observation of the impedance trajectory
Maximum power swing frequency Approx. 10 Hz
Power swing blocking programs Blocking of Z1 and Z1B
Blocking of Z2 and higher zones
Blocking of Z1 and Z2
Block all zones
Power swing trip Trip following instable power swings
(out-of-step)
4.3
Technical Data
4.3 Power Swing Detection (with impedance pickup) (optional)
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Distance Protection Teleprotection Schemes
Operating Mode
For two line ends With one channel for each direction or
with three channels for each direction for phase segregated transmission
For three line ends With one channel for each direction or connection
Underreach scheme
Method Transfer trip with overreaching zone Z1B
Direct transfer trip
Send signal prolongation 0.00 s bis 30.00 s Increments 0.01 s
Underreach Schemes via a Protection Data Interface (optional)
Phase-segregated for two or three line ends
Method Transfer trip with overreaching zone Z1B
Send signal prolongation 0.00 s bis 30.00 s Increments 0.01 s
Overreach schemes
Method Permissive Overreach Transfer Trip (POTT) (with overreaching
zone Z1B)
Unblocking (with overreaching zone Z1B)
Blocking (with overreaching zone Z1B) Pilot wire comp.
Send signal prolongation 0.00 s to 30.00 s Increments 0.01 s
Enable delay 0.000 s bis 30.000 s Increments 0.001 s
Transient blocking time 0.00 s to 30.00 s Increments 0.01 s
Wait time for transient blocking 0.00 s to 30.00 s; ∞ Increments 0.01 s
Echo delay time 0.00 s to 30.00 s Increments 0.01 s
Echo impulse duration 0.00 s to 30.00 s Increments 0.01 s
Time expiry tolerances 1 % of setting value or 10 ms
The set times are pure delay times with definite time protection.
Overreach Schemes via Protection Data Interface (optional)
Phase-segregated for two or three line ends
Method Signalvergleich (mit Übergreifzone Z1B)
Send signal prolongation 0.00 s to 30.00 s Increments 0.01 s
Enable delay 0.000 s bis 30.000 s Increments 0.001 s
Transient blocking time 0.00 s to 30.00 s Increments 0.01 s
Wait time for transient blocking 0.00 s to 30.00 s; ∞ Increments 0.01 s
Echo delay time 0.00 s to 30.00 s Increments 0.01 s
Echo impulse duration 0.00 s to 30.00 s Increments 0.01 s
Time expiry tolerances 1 % of setting value or 10 ms
The set times are pure delay times with definite time protection.
4.4
Technical Data
4.4 Distance Protection Teleprotection Schemes
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Earth Fault Protection (optional)
Characteristics
Definite time stages 3Ι 0>>>, 3Ι 0>>, 3Ι 0>
Inverse time stage (IDMT) 3Ι 0P
one of the characteristics according to
Figure 4-1 to Figure 4-4 can be selected
Voltage-dependent stage (U 0 inverse) Characteristics according to Figure 4-5
Zero-sequence power protection Characteristics according to Figure 4-6
Very high set current stage
High current pickup 3Ι 0>>> for Ι N = 1 A 0.05 A to 25.00 A Increments 0.01 A
for Ι N = 5 A 0.25 A to 125.00 A
Delay T3Ι0>>> 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Dropout ratio Approx. 0.95 for Ι/Ι N ≥ 0.5
Pickup time (fast relays/high-speed relays) Approx. 30 ms/25 ms
Dropout time Approx. 30 ms
Tolerances Current 3 % of setting value or 1 % nominal current
Time 1 % of setting value or 10 ms
The set times are pure delay times with definite time protection.
High-current Stage
Pickup value 3Ι 0>> for Ι N = 1 A 0.05 A to 25.00 A Increments0.01 A
for Ι N = 5 A 0.25 A to 125.00 A
Delay T3Ι0>> 0.00 s to 30.00 s
oder ∞ (ineffective)
Increments0.01 s
Dropout ratio Approx. 0.95 for Ι/Ι N ≥ 0.5
Pickup time (fast relays/high-speed relays) Approx. 30 ms/25 ms
Dropout time Approx. 30 ms
Tolerances Current 3 % of setting value or 1 % nominal current
Time 1 % of setting value or 10 ms
The set times are pure delay times with definite time protection.
Overcurrent stage
Pickup value 3Ι 0> for Ι N = 1 A 0.05 A to 25.00 A
or
0.003 A to 25.000 A
Increments 0.01 A
Increments 0.001 A
for Ι N = 5 A 0.25 A to 125.00 A
or
0.015 A to 125.000 A
Increments 0.01 A
Increments 0.001 A
Delay T3Ι0> 0.00 s to 30.00 s
oder ∞ (ineffective)
Increments 0.01 s
Dropout ratio Approx. 0.95 for Ι/Ι N ≥ 0.5
4.5
Technical Data
4.5 Earth Fault Protection (optional)
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Pickup time (fast relays/high-speed relays)
(1.5 · set value)
(2.5 · set value)
Approx. 40 ms/35 ms
Approx. 30 ms/25 ms
Dropout time Approx. 30 ms
Tolerances Current 3 % of setting value or 1 % nominal current
Time 1 % of setting value or 10 ms
The set times are pure delay times with definite time protection.
Inverse Current Stage (IEC)
Pickup value 3Ι 0P for Ι N = 1 A 0.05 A to 25.00 A
or
0.003 A to 25.000 A
Increments 0.01 A
Increments 0.001 A
for Ι N = 5 A 0.25 A to 125.00 A
or
0.015 A to 125.000 A
Increments 0.01 A
Increments 0.001 A
Time factor T3Ι0P 0.05 s to 3.00 s
or ∞ (ineffective)
Increments 0.01 s
Additional time delayT3Ι0P verz 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Characteristics see Figure 4-1
Tolerances
Pickup and dropout thresholds 3Ι 0p 3 % of setting value, or 1 % nominal current
Pickup time for ≤ Ι/3Ι 0P ≤ 20 and T3I0P ≥ 1 s 5 % of set value ± 15 ms
Defined times v
Inverse Current Stage (ANSI)
Pickup value 3Ι 0P for Ι N = 1 A 0.05 A to 25.00 A
oder
0.003 A to 25.000 A
Increments0.01 A
Increments0.001 A
for Ι N = 5 A 0.25 A to 125.00 A
or
0.015 A to 125.000 A
Increments0.01 A
Increments0.001 A
Time factor D3Ι0P 0.50 s to 15.00 s
or ∞ (ineffective)
Increments0.01 s
Additional time delay T3Ι0P verz 0.00 s to 30.00 s
or ∞ (ineffective)
Increments0.01 s
Characteristics see Figure 4-2 and Figure 4-3
Tolerances
Pickup and dropout thresholds 3Ι 0p 3 % of set value, or 1 % nominal current
Pickup time for 2 ≤ Ι/3Ι 0P ≤ 20 and D3I0P ≥ 1 s 5 % of set value ± 15 ms
Defined times 1 % of set value or 10 ms
Technical Data
4.5 Earth Fault Protection (optional)
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Inverse Current Stage (logarithmic inverse)
Pickup value 3Ι 0P for Ι N = 1 A 0.05 A to 25.00 A
or
0.003 A to 25.000 A
Increments 0.01 A
Increments 0.001 A
for Ι N = 5 A 0.25 A to 125.00 A
or
0.015 A to 125.000 A
Increments 0.01 A
Increments 0.001 A
Start current factor3Ι 0P FAKTOR 1.0 to 4.0 Increments 0.1
Time factor T3Ι0P 0.05 s to 15.00 s; ∞ Increments 0.01 s
Maximum time T3Ι0P max 0.00 s to 30.00 s Increments 0.01 s
Minimum time T3Ι0P min 0.00 s to 30.00 s Increments 0.01 s
Additional time delay T3Ι0P verz 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Characteristics see Figure 4-4
Tolerances
Pickup and dropout thresholds 3Ι 0p 3 % of set value, or 1 % nominal current
Pickup time for 2 ≤ Ι/3Ι 0P ≤ 20 and T3I0P ≥ 1 s 5 % of set value ± 15 ms
Defined times 1 % of setting value or 10 ms
Zero Sequence Voltage Stage (U0 inverse)
Pickup value 3Ι 0P for Ι N = 1 A 0.05 A to 25.00 A
or
0.003 A to 25.000 A
Increments 0.01 A
Increments 0.001 A
for Ι N = 5 A 0.25 A to 125.00 A
or
0.015 A to 125.000 A
Increments 0.01 A
Increments 0.001 A
Pickup value 3U 0> 1.0 V to 10.0 V Increments 0.1 V
Voltage factor U 0 inv. minimal 0.1 V to 5.0 V Increments 0.1 V
Additional time delay Tdirectional 0.00 s to 32.00 s Increments 0.01 s
Tnon-directional 0.00 s to 32.00 s Increments 0.01 s
Characteristics see Figure 4-5
Tolerances times 1 % of setting value or 10 ms
Dropout ratio Strom Approx. 0.95 for Ι/Ι N ≥ 0.5
Spannung Approx. 0.95 for 3U 0 ≥ 1 V
Zero Sequence Output Stage (power stage)
Pickup value 3Ι 0P for Ι N = 1 A 0.05 A to 25.00 A
or
0.003 A to 25.000 A
Increments 0.01 A
Increments 0.001 A
for Ι N = 5 A 0.25 A to 125.00 A
or
0.015 A to 125.000 A
Increments 0.01 A
Increments 0.001 A
Pickup value S FORWARD for Ι N = 1 A 0.1 VA to 10.0 VA Increments 0.1 VA
for Ι N = 5 A 0.5 VA to 50.0 VA
Additional time delay T3ΙOPverz 0.00 s to 30.00 s; ∞ Increments 0.01 s
Technical Data
4.5 Earth Fault Protection (optional)
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Characteristics see Figure 4-6
Tolerances pickup values 1 % of set value at sensitive earth current transformer
Tolerances times 5 % of set value or 15 ms at sensitive earth current transformer
6 % of set value or 15 ms at normal earth current transformer /
without earth current transformer
Inrush Restraint
Second harmonic content for inrush 10 % to 45 % Increments 1 %
Referred to fundamental wave
Inrush blocking is cancelled above for ΙN = 1 A 0.50 A to 25.00 A Increments 0.01 A
for ΙN = 5 A 2.50 A to 125.00 A
Inrush restraint may be switched effective or ineffective for each individual stage.
Determination of Direction
Each zone can be set to operate in forward or reverse direction, non-directional or ineffective.
Direction measurement with ΙE (= 3 Ι0) and 3 U0 and ΙY or Ι2 and U2
with ΙE (= 3 Ι0) and 3 U0 and ΙY
with ΙE (= 3 Ι0) and ΙY ((starpoint current of a power trans-
former)
with Ι2 and U2 (negative sequence quantities)
with zero-sequence power
Limit values
Displacement voltage 3U0> 0.5 V to 10.0 V Increments 0.1 V
Starpoint current of a power transformer
ΙY>
for ΙN = 1 A 0.05 A to 1.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 5.00 A
Negative sequence current 3Ι2> for ΙN = 1 A 0.05 A to 1.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 5.00 A
Negative sequence voltage 3U2> 0.5 V to 10.0 V Increments 0.1 V
“Forward” angle
Capacitive alpha 0° to 360° Increments 1°
Inductive beta 0° to 360° Increments 1°
Tolerances pickup values 10 % vom Einstellwert bzw. 5 % Nennstrom bzw. 0.5 V
Tolerance forward angle 5°
Re-orientation time after direction changeUmorientier-
ungszeit bei Fehlerwechsel
Approx. 30 ms
Technical Data
4.5 Earth Fault Protection (optional)
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[td-kennl-amz-n-iec-oz-060802, 1, en_GB]
Figure 4-1 Trip time characteristics of inverse time overcurrent stage, acc. IEC (phases and earth)
Technical Data
4.5 Earth Fault Protection (optional)
450 SIPROTEC 4, 7SA522, Manual
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[td-kennl-amz-n-ansi-1-oz-060802, 1, en_GB]
Figure 4-2 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth)
Technical Data
4.5 Earth Fault Protection (optional)
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[td-kennl-amz-n-ansi-2-oz-060802, 1, en_GB]
Figure 4-3 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth)
Technical Data
4.5 Earth Fault Protection (optional)
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[td-kennlinie-amz-log-invers-oz-060802, 1, en_GB]
Figure 4-4 Trip time characteristic of the inverse time overcurrent stage with logarithmic-inverse charac-
teristic
Logarithmic inverse t = T3Ι0Pmax — T3Ι0P·Ιn(Ι/3I0P)
Note: For Ι/3I0P > 35 the time for Ι/3I0P = 35 applies
[td-kennl-nullspg-zeitschutz-oz-060802, 1, en_GB]
Figure 4-5 Trip time characteristics of the zero sequence voltage protection U0 inverse
Technical Data
4.5 Earth Fault Protection (optional)
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[ausloesekennl-nullspg-schutz-wlk-190802, 1, en_GB]
Figure 4-6 Tripping characteristics of the zero-sequence power protection
This characteristic applies for: Sref = 10 VA and T3ΙOPAdd.T_DELAY = 0 s.
Technical Data
4.5 Earth Fault Protection (optional)
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Earth Fault Protection Teleprotection Schemes (optional)
Operating Mode
For two line ends One channel for each direction or three channels each direction for phase-segregated trans-
mission
For three line ends With one channel for each direction or connection
Overreach schemes
Method Dir. comp. pickup
Directional unblocking scheme
Directional blocking scheme
Send signal prolongation 0.00 s to 30.00 s Increments 0.01 s
Enable delay 0.000 s to 30.000 s Increments 0.001 s
Transient blocking time 0.00 s to 30.00 s Increments 0.01 s
Wait time for transient blocking 0.00 s to 30.00 s; ∞ Increments 0.01 s
Time expiry tolerances 1 % of setting value or 10 ms
The set times are pure delay times
Overreach Schemes via Protection Data Interface (optional)
Phase-segregated for two or three line ends
Method Dir. comp. pickup
SendesignalverlängerungSend signal prolongation 0.00 s bis 30.00 s Increments 0.01 s
Enable delay 0.000 s bis 30.000 s Increments 0.001 s
Transient blocking time 0.00 s bis 30.00 s Increments 0.01 s
Wait time for transient blocking 0.00 s bis 30.00 s; ∞ Increments 0.01 s
Echo delay time 0.00 s bis 30.00 s Increments 0.01 s
Echo impulse duration 0.00 s bis 30.00 s Increments 0.01 s
Time expiry tolerances 1 % of setting value or 10 ms
The set times are pure delay times
4.6
Technical Data
4.6 Earth Fault Protection Teleprotection Schemes (optional)
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Weak-infeed Tripping (classical)
Operating Mode
Phase segregated undervoltage detection after reception of a carrier signal from the remote end
Undervoltage
Setting value UPhE< 2 V to 70 V Increments1 V
Dropout to pickup ratio Approx. 1.1
Pickup tolerance ≤ 5 % of setting value, or 0.5 V
Times
Echo delay/release delay 0.00 s to 30.00 s Increments 0.01 s
Echo impulse duration/release prolongation 0.00 s to 30.00 s Increments 0.01 s
Echo blocking duration after echo 0.00 s to 30.00 s Increments 0.01 s
Pickup tolerance 1 % of setting value or 10 ms
4.7
Technical Data
4.7 Weak-infeed Tripping (classical)
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Weak-infeed Tripping (French Specification)
Operating Mode
Phase segregated undervoltage detection after reception of a carrier signal from the remote end Setting
Undervoltage
Setting value UPhE< (Faktor) 0.10 to 1.00 Increments 0.01
Dropout/pickup ratio Approx. 1.1
Pickup tolerance ≤ 5 %
Times
Receive prolongation 0.00 s to 30.00 s Increments 0.01 s
Extension time 3Ι0> 0.00 s to 30.00 s Increments 0.01 s
Alarm time 3Ι0> 0.00 s to 30.00 s Increments 0.01 s
Delay (single-pole) 0.00 s to 30.00 s Increments 0.01 s
Delay (multi-pole) 0.00 s to 30.00 s Increments 0.01 s
Time constant τ 1 s to 60 s Increments 1 s
Pickup tolerance 1 % of setting value or 10 ms
4.8
Technical Data
4.8 Weak-infeed Tripping (French Specification)
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Protection Data Interface and Communication Topology (optional)
Protection Data Interfaces
Number 1 or 2
Connection of optical fibre cable Mounting location“D” for 1 connection or “D” and “E” for 2 connec-
tions
for flush-mounted housing on the rear side
for surface-mounted housing at the upper side of the console housing
Connection modules for protection data interface, depending on the ordered version
FO5
FO30 (IEEE C37.94)
Distance, maximum 1.5 km
Connector Type ST connector
Optical wavelength λ = 820 nm
Fibre Type Multimode 62.5 μm /125 μm
Transmit output (peak) min. Type max.
50 μm /125 μm, NA = 0.21)
62.5 μm /125 μm, NA = 0,2751)
-19.8 dBm
-16.0 dBm
-15.8 dBm
-12.0 dBm
-12.8 dBm
-9.0 dBm
Receiver sensitivity (peak)
– Optical power for high level
– Optical power for low level
max. -40 dBm
min. -24 dBm
Optical budget min. 4.2 dB for 50 μm /125 μm , NA = 0.21)
min. 8 dB for 62.5 μm /125 μm , NA = 0.2751)
Laser class 1 according to EN 60825-1/-2 Using glass fibre 62.5 μm /125 μm and 50 μm /125 μm
Reach for multimode optical fibre, an optical signal attenuation of 3
dB/km is used for calculating light with a wavelength of λ = 820
nm
Attenuators required no
1) Numeric opening (NA = sin φ (coupling angle)
FO6
Distance, maximum 3.5 km
Connector Type ST connector
Optical wavelength λ = 820 nm
Fibre Type Multimode 62.5 μm /125 μm
Transmit output (avg) min. Typ
50 μm /125 μm, NA = 0.21)
62.5 μm /125 μm, NA = 0.2751)
-18.0 dBm
-17.0 dBm
-15.0 dBm
-12.0 dBm
Receiver sensitivity (avg) min. -33 dBmavg
Optical budget min. 15.0 dB for 50 μm /125 μm , NA = 0.21)
min. 16.0 B for 62.5 μm /125 μm , NA = 0.2751)
Laser class 1 according to EN 60825-1/-2 Using glass fibre 62.5 μm /125 μm and 50 μm /125 μm
Reach for multimode optical fibre, an optical signal attenuation of 3
dB/km is used for calculating light with a wavelength of λ = 820
nm
4.9
Technical Data
4.9 Protection Data Interface and Communication Topology (optional)
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Attenuators required no
1) Numeric opening (NA = sin φ (coupling angle)
FO17
Distance, maximum 24 km
Connector Type LC duplex connector, SFF (IEC 61754–20 Standard)
Protocol full-duplex
Baudrate 155 Mbits/s
Receiver interfacing AC
Optical wavelength λ = 1300 nm
Fibre Type Monomode 9 μm /125 μm
Transmit output coupled in Monomodefaster min. -15.0 dBmavg
max. -8.0 dBmavg
Receiver sensitivity min. -28.0 dBmavg
max. -31.0 dBmavg
Optical budget 13.0 dB
Laser Class 1 according to EN 60825–1/-2 Using glass fibre 9 μm /125 μm
Reach for multimode optical fibre, an optical signal attenuation of 0.3
dB/km is used for calculating light with a wavelength of λ =
1300 nm
Attenuators required non
FO18
Distance, maximum 60 km
Connector Type LC duplex connector, SFF (IEC 61754–20 Standard)
Protocol full-duplex
Baudrate 155 Mbits/s
Receiver interfacing AC
Optical wavelength λ = 1300 nm
Fibre Type Monomode 9 μm /125 μm
Transmit output coupled in Monomodefaster min. -5.0 dBmavg
max. -0 dBmavg
Receiver sensitivity min. -34.0 dBmavg
max. -34.5 dBmavg
Optical budget 29.0 dB
Laser Class 1 according to EN 60825–1/-2 Using glass fibre 9 μm /125 μm
Reach for multimode optical fibre, an optical signal attenuation of 0.3
dB/km is used for calculating light with a wavelength of λ =
1300 nm
Attenuators required for distances of less than 25 km (15.5 miles)1)
1) If protection data interface communication is used for distances of less than 25 km or 15.5 miles , the
transmit output has to be reduced by a set of optical attenuators. Both attenuators can be installed on one
side.
FO19
Distance, maximum 100 km
Connector Type LC duplex connector, SFF (IEC 61754–20 Standard)
Protocol full-duplex
Baudrate 155 Mbits/s
Technical Data
4.9 Protection Data Interface and Communication Topology (optional)
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Receiver interfacing AC
Optical wavelength λ = 1550 nm
Fibre Type Monomode 9 μm /125 μm
Transmit output coupled in Monomodefaster min. -5.0 dBmavg
max. -0 dBmavg
Receiver sensitivity min. -34.0 dBmavg
max. -34.5 dBmavg
Optical budget 29.0 dB
Laser Class 1 according to EN 60825–1/-2 Using glass fibre 9 μm /125 μm
Reach for multimode optical fibre, an optical signal attenuation of 0.2
dB/km is used for calculating light with a wavelength of λ =
1550 nm
Attenuators required for distances of less than 50 km (31.1 miles)1)
1) If protection data interface communication is used for distances of less than 50 km or 31.1 miles, the
transmit output has to be reduced by a set of optical attenuators. Both attenuators can be installed on one
side.
- Character idle state “Light off”
Protection Data Communication
Direct connection :
Transmission rate 512 kBit/s
Fibre type refer to table above
Optical wavelength
Permissible link signal attenuation
Transmission distance
Connection via communication networks:
Kommunikationsumsetzer see Appendix A Ordering Information and AccessoriesOrdering Information
Section Accessories
Supported network interfaces G703.1 with 64 kBit/s
X.21 with 64 kBit/s or 128 kBit/s or 512 kBit/s
S0 (ISDN) with 64 kBit/s
Pilot wires with 128 kBit/s
Connection to communication
converter
see table above under module FO5
Transmission rate 64 kBit/s with G703.1
512 kBit/s or 128 kBit/s or 64 kBit/s with X.21
Pilot wires with 128 kBit/s
S0 (ISDN) with 64 kBit/s
Max. runtime time 0.1 ms to 30 ms Increments 0.1 ms
Max. runtime difference 0.000 ms to 3.000 ms Increments 0.001 ms
Transmission accuracy CRC 32 according to CCITT or ITU
Technical Data
4.9 Protection Data Interface and Communication Topology (optional)
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External Direct and Remote Tripping
External Trip of the Local Breaker
Operating time, total Approx. 11 ms
Trip time delay 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Time expiry tolerances 1 % of setting value or 10 ms
The set times are pure delay times
4.10
Technical Data
4.10 External Direct and Remote Tripping
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Time Overcurrent Protection
Operating modes
As emergency overcurrent protection or back-up overcurrent protection
Emergency overcurrent protection Operates on failure of the measured voltage,
• On trip of a voltage transformer mcb (via binary input)
• For pickup of the “Fuse-Failure-Monitor”
Back-up overcurrent protection Operates independent of any events
Characteristics
Definite dime stages (definite) IPh>>>, 3Ι0>>>, ΙPh>>, 3Ι0>>, ΙPh>, 3Ι0>
Inverse time stages (IDMT) ΙP, 3Ι0P; one of the characteristics according to
Figure 4-1 to Figure 4-3 (see Technical Data Section “Earth Fault Protection”) can
be selected
High-set Current Stages
Pickup valueΙPh>> (phases) for ΙN = 1 A 0.10 A to 25.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.50 A to 125.00 A
or ∞ (ineffective)
Pickup value 3Ι0>> (earth) for ΙN = 1 A 0.05 A to 25.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.25 A to 125.00 A
or ∞ (ineffective)
Delay TΙPh>> (phases) 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Delay T3Ι0>> (earth) 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Dropout ratio Approx. 0.95 for Ι/ΙN ≥ 0.5
Pickup times (fast relays/high-speed relays) Approx. 25 ms/20 ms
Dropout times Approx. 30 ms
Tolerances Currents 3 % of setting value or 1 % nominal current
Times 1 % of setting value or 10 ms
The set times are pure delay times
Overcurrent Stages
Pickup value ΙPh> (phases) for ΙN = 1 A 0.10 A to 25.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.50 A to 125.00 A
or ∞ (ineffective)
Pickup value 3Ι0> (earth) for ΙN = 1 A 0.05 A to 25.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.25 A to 125.00 A
or ∞ (ineffective)
Delay TΙPh> (phases) 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
4.11
Technical Data
4.11 Time Overcurrent Protection
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Delay T3Ι0> (earth) 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Dropout ratio Approx. 0.95 for Ι/ΙN ≥ 0.5
Pickup times (fast relays/high-speed relays) Approx. 25 ms/20 ms
Dropout times Approx. 30 ms
Tolerances Currents 3 % of setting value or 1 % nominal current
Times 1 % of setting value or 10 ms
The set times are pure delay times
Inverse Time Stages (IEC)
Pickup value ΙPh (phases) for ΙN = 1 A 0.10 A to 4.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.50 A to 20.00 A
or ∞ (ineffective)
Pickup value 3Ι0P (earth) for ΙN = 1 A 0.05 A to 4.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.25 A to 20.00 A
or ∞ (ineffective)
Time multipliers TΙP (phases) 0.05 s to 3.00 s
or ∞ (ineffective)
Increments 0.01 s
T3Ι0P (earth) 0.05 s to 3.00 s
or ∞ (ineffective)
Increments 0.01 s
Additional time delays TΙP delayed (phases) 0.00 s to 30.00 s Increments 0.01 s
T3Ι0P delayed (earth) 0.00 s to 30.00 s Increments 0.01 s
Characteristics see Figure 4-1
Tolerances
Pickup/dropout thresholds Ιp, 3Ι0p 3% of set value, or 1% nominal current
Pickup time for 2 ≤ Ι/ΙP ≤ 20 and TIP ≥ 1 s
Pickup time for 2 ≤ Ι/3Ι0P ≤ 20 and T3I0P ≥ 1 s
5% of set value ± 15 ms
5% of set value ± 15 ms
Defined times 1 % of setting value or 10 ms
Inverse Time Stages (ANSI)
Pickup value ΙPh (phases) for ΙN = 1 A 0.10 A to 4.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.50 A to 20.00 A
or ∞ (ineffective)
Pickup value 3Ι0P (earth) for ΙN = 1 A 0.05 A to 4.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.25 A to 20.00 A
or ∞ (ineffective)
Time multipliers DΙP (phases) 0.50 s to 15.00 s
or ∞ (ineffective)
Increments 0.01 s
D3Ι0P (earth) 0.50 s to 15.00 s
or ∞ (ineffective)
Increments 0.01 s
Additional time delays TΙP delayed (phases) 0.00 s to 30.00 s Increments 0.01 s
T3Ι0P delayed (earth) 0.00 s to 30.00 s Increments 0.01 s
Characteristics see Figure 4-2 and Figure 4-3
Technical Data
4.11 Time Overcurrent Protection
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Tolerances
Pickup/dropout thresholds Ιp, 3Ι0p 3% of set value, or 1% nominal current
Pickup time for 2 ≤ Ι/ΙP ≤ 20 and DIP ≥ 1 s
Pickup time for 2 ≤ Ι/3Ι0P ≤ 20 and D3I0P ≥ 1 s
5% of set value ± 15 ms
5% of set value ± 15 ms
Defined times 1 % of setting value or 10 ms
Stub Fault Protection
Pickup value ΙPh>>>(phases) for ΙN = 1 A 0.10 A to 25.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.50 A to 125.00 A
or ∞ (ineffective)
Pickup value 3Ι0 >>>(earth) for ΙN = 1 A 0.05 A to 25.00 A
or ∞ (ineffective)
Increments 0.01 A
for ΙN = 5 A 0.25 A to 125.00 A
or ∞ (ineffective)
Delays TΙPh>>> 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
T3Ι0>>> 0.00 s to 30.00 s
or ∞ (ineffective)
Increments 0.01 s
Dropout to pickup ratio Approx. 0.95 for Ι/ΙN ≥ 0.5
Pickup times (fast relays/high-speed relays) Approx. 25 ms/20 ms
Dropout times Approx. 30 ms
Tolerance currents Currents 3 % of setting value or 1 % nominal current
Times 1 % of setting value or 10 ms
The set times are pure delay times.
Technical Data
4.11 Time Overcurrent Protection
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Instantaneous High-current Switch-onto-fault Protection
Pickup
Pickup value Ι>>> for ΙN = 1 A 1.00 A to 25.00 A Increments 0.01 A
for ΙN = 5 A 5.00 A to 125.00 A
Drop-off to pick-up ratio Approx. 90 %
Pick-up tolerance 3 % of setting value or 1 % von ΙN
Times
Shortest trip time Approx. 13 ms for fast relays
Approx. 8 ms for high-speed relays
4.12
Technical Data
4.12 Instantaneous High-current Switch-onto-fault Protection
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Automatic Reclosure (optional)
Automatic Reclosures
Number of reclosures Max. 8,
first 4 with individual settings
Type (depending on ordered version) 1-pole, 3-pole or 1-/3-pole
Control With pickup or trip command
Action Times
Initiation possible without pickup and action time
0.01 s to 300.00 s; ∞ Increments 0.01 s
Different dead times before
reclosure can be set for all operating modes and cycles
0.01 s to 1800.00 s; ∞ Increments 0.01 s
Dead times after evolving fault recognition 0,01 s to 1800,00 s Increments 0.01 s
Reclaim time after successful AR cycle 0,50 s to 300,00 s Increments 0.01 s
Blocking time after dynamic Blocking 0.5 s
Blocking time after manual closing 0.50 s to 300.00 s; 0 Increments 0.01 s
Start signal monitoring time 0,01 s to 300,00 s Increments 0.01 s
Circuit breaker monitoring time 0,01 s to 300,00 s Increments 0.01 s
Adaptive Dead Time/Reduced Dead Time/Dead Line Check
Adaptive dead time With voltage measurement or
with close command transmission
Action Times
Initiation possible without pickup and action time
0.01 s to 300.00 s; ∞ Increments 0.01 s
Maximum dead time 0,50 s to 3000,00 s Increments 0.01 s
Voltage measurement dead line or bus 2 V to 70 V (Ph-E) Increments 1 V
Voltage measurement live or bus 30 V to 90 V (Ph-E) Increments 1 V
Voltage measuring time 0,10 s to 30,00 s Increments 0.01 s
Time delay for close command transmission 0.00 s to 300.00 s; ∞ Increments 0.01 s
4.13
Technical Data
4.13 Automatic Reclosure (optional)
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Synchronism and Voltage Check (optional)
Operating Modes
Operating modes
with automatic reclosure
Synchronism check
Live bus - dead line
Dead bus - live line
Dead bus and dead line
Bypassing
Or combination of the above
Synchronism Closing the circuit breaker under asynchronous power condi-
tions possible (with circuit breaker action time)
Operating modes
for manual closure
As for automatic reclosure,
independently selectable
Voltages
Maximum operating voltage 20 V to 140 V (phase-to-phase) Increments 1 V
U< for dead status 1 V to 60 V (phase-to-phase) Increments 1 V
U> for voltage present 20 V to 125 V (phase-to-phase) Increments 1 V
Tolerances 2 % of the pickup value or 1 V
Dropout to pickup ratio approx. 0.9 (U>) or 1.1 (U<)
ΔU measurement
Voltage difference 1.0 V to 60.0 V (phase-to-phase) Increments 0,1 V
Tolerance 1 V
Dropout to pickup ratio Approx. 1,05
Synchronous power conditions
Δφ measurement 2° to 80° Increments 1°
Tolerance 2°
Δf measurement 0.03 Hz to 2.00 Hz Increments 0,01 Hz
Tolerance 15 mHz
Enable delay 0,00 s to 30,00 s Increments 0.01 s
Asynchronous power conditions
Δf measurement 0.03 Hz to 2.00 Hz Increments 0,01 Hz
Tolerance 15 mHz
Max. angle error 5° for Δf ≤ 1 Hz
10° for Δf > 1 Hz
Synchronous/asynchronous limits 0,01 Hz
Circuit breaker operating time 0,01 s to 0,60 s Increments 0.01 s
Times
Minimum time for filtering the measured values Approx. 80 ms
Maximum measuring time 0.01 s to 600.00 s; ∞ Increments 0.01 s
Tolerance of all timers 1 % of setting value or 10 ms
4.14
Technical Data
4.14 Synchronism and Voltage Check (optional)
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Voltage Protection (optional)
Phase-to-earth overvoltage
Over voltage UPh>> 1.0 V to 170.0 V; ∞ Increments 0,1 V
Delay TUPh>> 0.00 s to 100.00 s; ∞ Increments 0.01 s
OvervoltageUPh> 1.0 V to 170.0 V; ∞ Increments 0,1 V
Delay TUPh> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 0.30 to 0.99 Increments 0.01
Pickup time approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time approx. 30 ms
Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Phase-to-phase overvoltages
OvervoltageUPhPh>> 2.0 V to 220.0 V; ∞ Increments 0,1 V
Delay TUPhPh>> 0.00 s to 100.00 s; ∞ Increments 0.01 s
OvervoltageUPhPh> 2.0 V to 220.0 V; ∞ Increments 0,1 V
Delay TUPhPh> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 0.30 to 0.99 Increments 0.01
Pickup time approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time approx. 30 ms
Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Overvoltage positive sequence system U1
OvervoltageU1>> 2.0 V to 220.0 V; ∞ Increments 0.1 V
Delay TU1>> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Overvoltage U1> 2.0 V to 220.0 V; ∞ Increments 0.1 V
Delay TU1> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout ratio 0.30 to 0.99 Increments 0.01
Compounding Can be switched on/off
Pick-up times Approx. 35 ms (50 Hz)/Approx. 30 ms (60 Hz)
Dropout time Approx. 30 ms
Tolerances Voltages 3 % of setting value or 1 V
Times 1 % of setting value or 10 ms
Overvoltage negative sequence system U2
OvervoltageU2>> 2.0 V to 220.0 V; ∞ Increments 0,1 V
Delay TU2>> 0.00 s to 100.00 s; ∞ Increments 0.01 s
OvervoltageU2> 2.0 V to 220.0 V; ∞ Increments 0,1 V
Delay TU2> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 0,30 to 0,99 Increments 0.01
Pickup time Approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time Approx. 30 ms
4.15
Technical Data
4.15 Voltage Protection (optional)
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Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Overvoltage zero-sequence system 3U0 or any single-phase voltage UX
Overvoltage 3U0>> 1.0 V to 220.0 V; ∞ Increments 0,1 V
Delay T3U0>> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Overvoltage 3U0> 1.0 V to 220.0 V; ∞ Increments 0,1 V
Delay T3U0> 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 0.30 to 0,.9 Increments 0.01
Pickup time
With repeated measurement approx. 75 ms (50 Hz)/approx. 65 ms (60 Hz)
Without repeated measurement approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time
With repeated measurement approx. 75 ms (50 Hz)
Without repeated measurement approx. 30 ms (50 Hz)
Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Phase-to-earth undervoltage
Under voltage UPh<< 1.0 V to 100.0 V Increments 0,1 V
Delay TUPh<< 0.00 s to 100.00 s; ∞ Increments 0.01 s
Under voltage UPh< 1.0 V to 100.0 V Increments 0,1 V
Delay TUPh< 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 1.01 to 1.20 Increments 0.01
Current criterion Can be switched on/off
Pickup time Approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time Approx. 30 ms
Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Undervoltages phase-to-phase
UndervoltageUPhPh<< 1.0 V to 175.0 V Increments 0,1 V
Delay TUPhPh<< 0.00 s to 100.00 s; ∞ Increments 0.01 s
UndervoltageUPhPh< 1.0 V to 175.0 V Increments 0,1 V
Delay TUPhPh< 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 1.01 to 1.20 Increments 0.01
Current criterion Can be switched on/off
Pickup time Approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time Approx. 30 ms
Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Undervoltage positive sequence system U1
UndervoltageU1<< 1.0 V to 100.0 V Increments 0,1 V
Delay TU1<< 0.00 s to 100.00 s; ∞ Increments 0.01 s
Technical Data
4.15 Voltage Protection (optional)
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Under voltage U1< 1.0 V to 100.0 V Increments 0,1 V
Delay TU1< 0.00 s to 100.00 s; ∞ Increments 0.01 s
Dropout to pickup ratio 1.01 to 1.20 Increments 0.01
Current criterion Can be switched on/off
Pickup time Approx. 35 ms (50 Hz)/approx. 30 ms (60 Hz)
Dropout time Approx. 30 ms
Tolerances Voltages 3 % of set value or 1 V
Times 1 % of setting value or 10 ms
Technical Data
4.15 Voltage Protection (optional)
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Frequency Protection (optional)
Frequency Elements
Quantity 4, depending on setting effective on f< or f>
Pick-up Values
f> or f< adjustable for each element
for fN = 50 Hz 45.50 Hz to 54.50 Hz Increments 0.01 Hz
for fN = 60 Hz 55.50 Hz to 64.50 Hz Increments 0.01 Hz
Times
Pickup times f>, f< Approx. 85 ms
Dropout times f>, f< Approx. 30 ms
Delay times T 0.00 s to 600.00 s Increments 0.01 s
The set times are pure delay times.
Note on dropout times:
Dropout was enforced by current = 0 A and voltage = 0 V.
Enforcing the dropout by means of a frequency change below the dropout threshold extends the dropout times.
Dropout Frequency
Δf = | pickup value – dropout value | Approx. 20 mHz
Operating Range
In voltage range Approx. 0.65 · UN up to 230 V (phase-phase)
In frequency range 25 Hz to 70 Hz
Tolerances
Frequencies f>, f< in specific range (fN ± 10 %) 15 mHz in range ULL: 50 V to 230 V
Time delays T(f<, f>) 1 % of setting value or 10 ms
4.16
Technical Data
4.16 Frequency Protection (optional)
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Fault Locator
Start With trip command or drop-off
Setting range reactance (secondary),
miles or km
for ΙN = 1 A 0.0050 Ω/km to 9.5000 Ω/km Increments 0.001 Ω/km
for ΙN = 5 A 0.0010 Ω/km to 1.9000 Ω/km
for ΙN = 1 A 0.0050 Ω/mile to 15.0000 Ω/mile Increments 0.001 Ω/
mile
for ΙN = 5 A 0.0010 Ω/mile to 3.0000 Ω/mile
Parallel line compensation (selectable) Can be switched on/off
The setting values are the same as for distance protection (see
Section 4.2 Distance Protection)
Taking into consideration the load current in case of
single-phase earth faults
Correction of the X-value, can be activated and deactivated
Output of the fault distance in Ω primary and Ω secondary,
in km or miles line length1)
in % of the line length1)
Measuring tolerances
with sinusoidal quantities
2.5 % vom Fehlerort
bei 30° ≤ φk ≤ 90° und Uk/UN ≥ 0.1
Further output options (depending on ordered version) As analog value 0 mA to 22.5 mA;
as BCD-code 4 Bit units + 4 Bit tens + 1 Bit hundreds + validity
bit
- BCD output time 0.01 s to 180.00 s; ∞ Increments 0.01 s
1) Output of the fault distance in km, miles, and % requires homogeneous lines
4.17
Technical Data
4.17 Fault Locator
472 SIPROTEC 4, 7SA522, Manual
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Circuit Breaker Failure Protection (optional)
Circuit breaker monitoring
Current flow monitoring for ΙN = 1 A 0.05 A to 20.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 100.00 A
Zero sequence current monitoring for ΙN = 1 A 0.05 A to 20.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 100.00 A
Dropout to pickup ratio Approx. 0.95
Tolerance 5 % of set value or 1 % of nominal current
Monitoring of circuit breaker auxiliary contact position
for 3-pole tripping binary input for CB auxiliary contact
for 1-pole tripping 1 binary input for auxiliary contact per pole or
1 binary input for series connection NO contact and NC contact
Note::
The circuit breaker failure protection can also operate without the indicated circuit breaker auxiliary contacts, but the
function range is then reduced.
Auxiliary contacts are necessary for the circuit breaker failure protection for tripping without or with a very low current
flow (e.g. Buchholz protection) and for stub fault protection and circuit breaker pole discrepancy supervision.
Initiation conditions
For circuit breaker failure protection Internal or external 1-pole trip 1)
Internal or external 3-pole trip 1)
Internal or external 3-pole trip without current1)
1) Via binary inputs
Times
Pickup time Approx. 5 ms with measured quantities present,
Approx. 20 ms after switch-on of measured quantities
Dropout time, internal (overshoot time) ≤ 15 ms at sinusoidal measured values,
≤ 25 ms maximum
Delay times for all stages 0.00 s to 30.00 s; ∞ Increments 0.01 s
Tolerance 1 % of setting value or 10 ms
End fault protection
With signal transmission to the opposite line end
Time delay 0.00 s to 30.00 s; ∞ Increments 0.01 s
Tolerance 1 % of setting value or 10 ms
Pole discrepancy supervision
Initiation criterion Not all poles are closed or open
Monitoring time 0.00 s to 30.00 s; ∞ Increments 0.01 s
Tolerance 1 % of setting value or 10 ms
4.18
Technical Data
4.18 Circuit Breaker Failure Protection (optional)
SIPROTEC 4, 7SA522, Manual 473
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Monitoring Functions
Measured values
Current sum ΙF = | ΙL1 + ΙL2 + ΙL3 + kΙ · ΙE | >
SUM.I Threshold · ΙN + SUM.FACTORΙ ·Σ | Ι |
- SUM.ΙLimit for ΙN = 1 A 0.05 A to 2.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 10.00 A Increments 0.01 A
- SUM.FACTORΙ0.00 to 0.95 Increments 0.01
Voltage sum UF = | UL1 + UL2 + UL3 + kU · UEN | > 25 V
Current Symmetry | Ιmin |/| Ιmax | < BAL.FACTOR.Ι
as long as Ιmax/ΙN > BAL.ΙLIMIT/ΙN
- BAL.FACTOR.Ι0.10 to 0.95 Increments 0.01
BAL.ΙLIMIT for ΙN = 1 A 0.10 A to 1.00 A Increments 0.01 A
for ΙN = 5 A 0.50 A to 5.00 A Increments 0.01 A
T BAL.ΙLIMIT 5 s to 100 s Increments 1 s
Broken conductor One conductor without current, the others with current
(monitoring of current transformer circuits on current step
change in one phase without residual current)
Voltage Symmetry | Umin |/| Umax | < BAL.FACTOR.U
as long as | Umax | > BAL.ULIMIT
- BAL.FACTORU 0.58 to 0.95 Increments 0.01
- BAL.ULIMIT 10 V to 100 V Increments 1 V
- T BAL.ULIMIT 5 s to 100 s Increments 1 s
Voltage phase sequence UL1 before UL2 before UL3
as long as | UL1|. | UL2| . | UL3| > 40 V/√3
Non-symmetrical voltages
(Fuse failure monitoring)
3 · U0 > FFM U> or 3 · U2 > FFM U>
and at the same time
3 · Ι0 < FFM Ι< and 3 · Ι2 < FFM Ι<
- FFM U> 10 V to 100 V Increments 1 V
- FFM Ι< for ΙN = 1 A 0.10 A to 1.00 A Increments 0.01 A
for ΙN = 5 A 0.50 A to 5.00 A Increments 0.01 A
Three-phase measuring voltage failure
(Fuse failure monitoring)
all UPh-E < FFM UMEAS <
and at the same time
all ΔΙPh < FFM Ιdelta
and
all ΙPh > (ΙPh> (Dist.))
- FFM UMEAS < 2 V to 100 V Increments 1 V
- FFM Ιdelta for ΙN = 1 A 0.05 A to 1.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 5.00 A Increments 0.01 A
- T U SUPERVISION (wait time for additional measured
voltage failure monitoring)
0.00 s to 30.00 s Increments 0.01 s
- T U mcb 0 ms to 30 ms Increments 1 ms
Phase angle positive sequence power Message when the angle lies inside the area of the P-Q level
parameterised by φA and φB
- φA, φB 0° to 259° Increments 1°
4.19
Technical Data
4.19 Monitoring Functions
474 SIPROTEC 4, 7SA522, Manual
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- Ι1 for ΙN = 1 A 0.05 A to 2.00 A Increments 0.01 A
for ΙN = 5 A 0.25 A to 10.00 A Increments 0.01 A
- U1 2 V to 70 V Increments 1 V
Response Time Approx. 30 ms
Trip Circuit Supervision
Number of monitored circuits 1 to 3
Operation per circuit With 1 binary input or with 2 binary inputs
Pickup and Dropout Time Approx. 1 s to 2 s
Settable delay time for operation with 1 binary input 1 s to 30 s Increments 1 s
Technical Data
4.19 Monitoring Functions
SIPROTEC 4, 7SA522, Manual 475
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Transmission of Binary Information (optional)
General
Note: The setting for remote signal reset delay for communication failure may be 0 s to 300 s or ∞. With setting ∞
annunciations are maintained indefinitely.
Remote Commands
Number of possible remote commands 4
Operating times, total approx.
Transmission rate 512 kBit/s 128 kBit/s 64 kBit/s
2 ends, minimum
typical
12 ms
14 ms
14 ms
16 ms
16 ms
18 ms
3 ends, minimum
typical
13 ms
15 ms
16 ms
19 ms
21 ms
24 ms
Drop-off times, total approx.
Transmission rate 512 kBit/s 128 kBit/s 64 kBit/s
2 ends, minimum
typical
10 ms
12 ms
12 ms
14 ms
13 ms
16 ms
3 ends, minimum
typical
10 ms
12 ms
13 ms
16 ms
18 ms
21 ms
The operating times refer to the entire signal path from the initiation of the binary inputs until the output of commands
via fast output relays. For high-speed relays (7SA522*-*N/P/Q/R/S/T/E/W) approx. 5 ms can be subtracted from the time
values.
Remote Indications
Number of possible remote signals 24
Operating times, total approx.
Transmission rate 512 kBit/s 128 kBit/s 64 kBit/s
2 ends, minimum
ypical
12 ms
14 ms
14 ms
16 ms
16 ms
18 ms
3 ends, minimum
ypical
13 ms
15 ms
16 ms
19 ms
21 ms
24 ms
Drop-off times, total approx.
Transmission rate 512 kBit/s 128 kBit/s 64 kBit/s
2 ends, minimum
ypical
10 ms
12 ms
12 ms
14 ms
13 ms
16 ms
3 ends, minimum
ypical
10 ms
12 ms
13 ms
16 ms
18 ms
21 ms
The operating times refer to the entire signal path from the initiation of the binary inputs until the output of commands
via fast output relays. For high-speed relays (7SA522*-*N/P/Q/R/S/T/W) approx. 5 ms can be subtracted from the time
values.
4.20
Technical Data
4.20 Transmission of Binary Information (optional)
476 SIPROTEC 4, 7SA522, Manual
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User-defined Functions (CFC)
Function Blocks and their Possible Allocation to the Priority Classes
Function Module Comments Task Level
MW_BEARB PLC1_BEARB PLC_BEARB SFS_BEARB
ABSVALUE Magnitude Calculation X – – –
ADD Addition X X X X
ALARM Alarm clock X X X X
AND AND - Gate X X X X
BLINK Flash block X X X X
BOOL_TO_CO Boolean to Control (conversion) – X X –
BOOL_TO_DI Boolean to Double Point
(conversion)
– X X X
BOOL_TO_IC Bool to Internal SI, Conversion – X X X
BUILD_DI Create Double Point Annuncia-
tion
– X X X
CMD_CANCEL Cancel command X X X X
CMD_CHAIN Switching Sequence – X X –
CMD_INF Command Information – – – X
COMPARE Measured value comparison X X X X
CONNECT Connection – X X X
COUNTER Counter X X X X
CV_GET_STATUS Information status of the
metered value, decoder
X X X X
D_FF D- Flipflop – X X X
D_FF_MEMO Status Memory for Restart X X X X
DI_GET_STATUS Information status double point
indication, decoder
X X X X
DI_SET_STATUS Double point indication with
status, encoder
X X X X
DI_TO_BOOL Double Point to Boolean
(conversion)
– X X X
DINT_TO_REAL DoubleInt after real, adapter X X X X
DIST_DECODE Double point indication with
status, decoder
X X X X
DIV Division X X X X
DM_DECODE Decode Double Point X X X X
DYN_OR Dynamic OR X X X X
LIVE_ZERO Live zero monitoring, nonlinear
characteristic
X – – –
LONG_TIMER Timer (max.1193h) X X X X
LOOP Feedback Loop X X X X
LOWER_SETPOINT Lower Limit X – – –
MUL Multiplication X X X X
MV_GET_STATUS Information status measured
value, decoder
X X X X
MV_SET_STATUS Measured value with status,
encoder
X X X X
NAND NAND - Gate X X X X
4.21
Technical Data
4.21 User-defined Functions (CFC)
SIPROTEC 4, 7SA522, Manual 477
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NEG Negator X X X X
NOR NOR - Gate X X X X
OR OR - Gate X X X X
REAL_TO_DINT Real after DoubleInt, adapter X X X X
REAL_TO_UINT Real after U-Int, adapter X X X X
RISE_DETECT Rising edge detector X X X X
RS_FF RS- Flipflop – X X X
RS_FF_MEMO Status memory for restart X X X X
SI_GET_STATUS Information status single point
indication, decoder
X X X X
SI_SET_STATUS Single point indication with
status, encoder
X X X X
SQUARE_ROOT Root Extractor X X X X
SR_FF SR- Flipflop – X X X
SR_FF_MEMO Status memory for restart X X X X
ST_AND AND gate with status X X X X
ST_NOT Negator with status X X X X
ST_OR OR gate with status X X X X
SUB Substraction X X X X
TIMER Timer – X X –
TIMER_SHORT Simple timer – X X –
UINT_TO_REAL U-Int to real, adapter X X X X
UPPER_SETPOINT Upper Limit X – – –
X_OR XOR - Gate X X X X
ZERO_POINT Zero Supression X – – –
General limits
Description Limit Comments
Maximum number of all CFC charts considering all task
levels
32 When the limit is exceeded, an error indica-
tion is output by the device. Consequently,
the device starts monitoring. The red
ERROR-LED lights up.
Maximum number of all CFC charts considering one task
level
16 Only error message
(Evolving error in processing procedure)
Maximum number of all CFC inputs considering all charts 400 When the limit is exceeded, an error indica-
tion is output by the device. Consequently,
the device starts monitoring. The red
ERROR-LED lights up.
Maximum number of inputs of one chart for each task level
(number of unequal information items of the left border
per task level)
400 Only error message; here the number of
elements of the left border per task level is
counted. Since the same information is
indicated at the border several times, only
unequal information is to be counted.
Maximum number of reset-resistant flipflops
D_FF_MEMO, RS_FF_MEMO, SR_FF_MEMO
350 When the limit is exceeded, an error indica-
tion is output by the device. Consequently,
the device starts monitoring. The red
ERROR-LED lights up.
Technical Data
4.21 User-defined Functions (CFC)
478 SIPROTEC 4, 7SA522, Manual
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Device-specific Limits
Description Limit Comments
Maximum number of concurrent changes to planned inputs
per task level
Chart inputs per task level
50 When the limit is exceeded, an error indica-
tion is output by the device. Consequently,
the device starts monitoring. The red
ERROR-LED lights up.
Maximum number of chart outputs per task level 150
Additional Limits
Additional limits 1) for the following 4 CFC blocks:
Task Level
TIMER 2) 3) TIMER_SHORT2) 3) CMD_CHAIN D_FF_MEMO
MW_BEARB
350
PLC1_BEARB 15 30 20
PLC_BEARB
SFS_BEARB
1) When the limit is exceeded, an error indication is output by the device. Consequently, the device starts
monitoring. The red ERROR-LED lights up.
2) TIMER and TIMER_SHORT share the available timer resources. The relation is TIMER = 2 · system timer and
TIMER_SHORT = 1 · system timer. For the maximum used timer number the following side conditions are valid:
(2 · number of TIMERs + number of TIMER_SHORTs) < 20. The LONG_TIMER is not subject to this condition.
3) The time values for the blocks TIMER and TIMER_SHORT must not be smaller than the time resolution of the
device, i.e. 5 ms, otherwise the blocks will not start with the starting impulse issued.
Maximum Number of TICKS in the Task Levels
Task Level Limit in TICKS 1)
MW_BEARB (Measured Value Processing) 10 000
PLC1_BEARB (Slow PLC Processing) 1 900
PLC_BEARB (Fast PLC Processing) 200
SFS_BEARB (switchgear interlocking) 10 000
1) When the sum of TICKS of all blocks exceeds the limits before-mentioned, an error message is output by
CFC.
Processing Times in TICKS required by the Individual Elements
Individual Element Number of TICKS
Block, basic requirement 5
Each input more than 3 inputs for generic modules 1
Connection to an input signal 6
Connection to an output signal 7
Additional for each chart 1
Operating sequence module CMD_CHAIN 34
Flipflop D_FF_MEMO 6
Loop module LOOP 8
Decoder DM_DECODE 8
Dynamic OR DYN_OR 6
Addition ADD 26
Subtraction SUB 26
Multiplication MUL 26
Technical Data
4.21 User-defined Functions (CFC)
SIPROTEC 4, 7SA522, Manual 479
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Individual Element Number of TICKS
Division DIV 54
Square root SQUARE_ROOT 83
Timer TIMER_SHORT 8
Timer LONG_TIMER 11
Blinker lamp BLINK 11
Counter COUNTER 6
Adaptor REAL_TO_DINT 10
Adaptor REAL_TO_UINT 10
Alarm clock ALARM 21
Comparison COMPARE 12
Decoder DIST_DECODE 8
Technical Data
4.21 User-defined Functions (CFC)
480 SIPROTEC 4, 7SA522, Manual
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Additional Functions
Measured values
Operational measured values for currents ΙL1; ΙL2; ΙL3; 3Ι0; Ι1; Ι2; ΙY; ΙP; ΙEE;
in A primary and secondary and in % ΙNperation
Tolerance 0.5 % of measured value or 0.5 % o ΙN
Operational measured values for voltages UL1-E, UL2-E, UL3-E; 3U0, U0, U1, U2, U1Ko, Usy2 (phase-to-earth
connection)
in kV primary, in V secondary or in % of UNOperation/√3
Tolerance 0.5 % of measured value, or 0.5 % of UN
Operational measured values for voltages Ux, Uen
in V secondary
Tolerance 0.5 % of measured value, or 0.5 % of UN
Operational measured values for voltages UL1-L2, UL2-L3, UL3-L1, Usy2 (LL-Anschluss)
in kV primary, in V secondary or in % of UNBetrieb
Tolerance 0.5 % of measured value or 0.5 % of UN
Operational measured values for impedances RL1-L2, RL2-L3, RL3-L1, RL1-E, RL2-E, RL3-E,
XL1-L2, XL2-L3, XL3-L1, XL1-E, XL2-E, XL3-E
in Ω primary and secondary
Operational measured values for power S; P; Q (apparent, active and reactive power)
in MVA; MW; Mvar primary and %N
(operational nominal power) = √3 · UN · ΙN
Tolerance 1 % of SN atΙ/ΙN and U/UN in range 50 to 120 %
1 % of PN at Ι/ΙN and U/UN in range 50 to 120 % and ABS(cos ϕ) in
range 0.7 to 1
1 % of QN at Ι/ΙN and U/UN in range 50 to 120 % and ABS(cos ϕ) in
range 0.7 to 1
Operating measured value for power factor cos φ
Tolerance 0.02
Counter values for energy Wp+, Wq+; Wp-; Wq- (real and reactive energy)
in kWh (MWh oder GWh) or
in kVARh (MVARh oder GVARh)
Tolerance 1) 5 % for Ι > 0,5 ΙN, U > 0,5 UN and | cosφ | ≥ 0,707
Operating measured values for frequency f in Hz and % fN
Range 94 % to 106 % of fN
10 mHz or 0.02 % of fN
Operational measured values for synchro check Usy1; Usy2; Udiff in kV primär
fsy1; fsy2; fdiff in Hz;
φdiff in °
Long-term mean value ΙL1dmd; ΙL2dmd; ΙL3dmd; Ι1dmd;
Pdmd; Pdmd Forw, Pdmd Rev;
Qdmd; Qdmd Forw; Qdmd Rev;
Sdmd
In primary values
4.22
Technical Data
4.22 Additional Functions
SIPROTEC 4, 7SA522, Manual 481
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Minimum and maximum values ΙL1; ΙL2; ΙL3; Ι1; ΙL1d; ΙL2d; ΙL3d; Ι1d;
UL1-E; UL2-E; UL3-E; U1;
UL1-L2; UL2-L3; UL3-L1; 3U0;
P Forw; P Rev; Q Forw; Q Rev; S; Pd; Qd; Sd;
cos φ Pos; cos φ Neg; f
In primary values
Remote measured values for currents ΙL1; ΙL2; ΙL3 of remote end in A primary
φ(ΙL1); φ(ΙL2); φ(ΙL3), referred to the local voltage UL1-E
in °
Remote measured values for voltages UL1; UL2; UL3 of remote end in kV primary
φ(UL1); φ(UL2); φ(UL3), referred to the local voltageUL1-E in °
1) bei Nennfrequenz
Operational Indication Buffer
Capacity 200 records
Fault Logging
Capacity 8 faults with a total of max. 600 messages and up to 100 binary signal traces (marks)
Fault Recording
Number of stored fault records Max. 8
Storage time Max. 5 s for each fault
Approx. 15 s in total
Sampling rate at fN = 50 Hz 1 ms
Sampling rate at fN = 60 Hz 0,83 ms
Statistics (serial protection data interface)
Availability of transmission for applications with protec-
tion data interface
Availability in %/min and %/h
Delay time of transmission Resolution 0.01 ms
Switching Statistics
Number of trip events caused by the device Separately for each breaker pole (if single-pole tripping is
possible)
Number of automatic reclosures initiated by the device Separate for 1-pole and 3-pole AR;
Separately for 1st AR cycle
and for all further cyles
Total of interrupted currents Pole segregated
Maximum interrupted current Pole segregated
Real Time Clock and Buffer Battery
Resolution for operational messages 1 ms
Resolution for fault messages 1 ms
Buffer battery Type: 3 V/1 Ah, Type CR 1/2 AA
Self-discharging time approx. 10 years
Technical Data
4.22 Additional Functions
482 SIPROTEC 4, 7SA522, Manual
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IEC 61850 GOOSE (inter-device communication)
The GOOSE communication service of IEC 61850 is qualified for switchgear interlocking. The runtime of GOOSE
messages with the protection relay picked up depends on the number of connected IEC 61850 clients. For the devices
applications with protective functions have to be checked in terms of their required runtime. In each case, the manufac-
turer has to be consulted to define the requirements that ensure that the application functions safely.
Technical Data
4.22 Additional Functions
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Dimensions
Housing for Panel Flush Mounting or Cubicle Mounting (Size1/2)
[massbild-schrankeinbau-gr-1-2-7sa522-050802, 1, en_GB]
Figure 4-7 Dimensions of a device for panel flush mounting or cubicle installation (size 1/2)
4.23
4.23.1
Technical Data
4.23 Dimensions
484 SIPROTEC 4, 7SA522, Manual
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Housing for Panel Flush Mounting or Cubicle Mounting (Size 1/1)
[massbild-schrankeinbau-gr-1-1-oz-040615, 1, en_GB]
Figure 4-8 Dimensions of a device for panel flush mounting or cubicle installation (size 1/1)
4.23.2
Technical Data
4.23 Dimensions
SIPROTEC 4, 7SA522, Manual 485
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Panel Surface Mounting (Housing Size 1/2)
[massbild-schalttafelaufbau-gr-1-2-oz-050802, 1, en_GB]
Figure 4-9 Dimensions of a device for panel surface mounting (size 1/2)
Dimensions of a device for panel surface mounting (size 1/1)
[massbild-schalttafelaufbau-gr-1-1-oz-050802, 1, en_GB]
Figure 4-10 Dimensions of a device for panel surface mounting (size 1/1)
4.23.3
4.23.4
Technical Data
4.23 Dimensions
486 SIPROTEC 4, 7SA522, Manual
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Ordering Information
7 8 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(position 1 to 9)
7 S A 5 2 2 – – + L/M/N
Measuring Inputs (4 x U, 4 x Ι)Pos. 7
Ιph = 1 A, Ιe = 1 A (min. = 0.05 A) 1
Ιph = 1 A, Ιe = sensitive (min. = 0.003 A) 2
Ιph = 5 A, Ιe = 5 A (min. = 0.25 A) 5
Ιph = 5 A, Ιe = sensitive (min. = 0.003 A) 6
Auxiliary Voltage (Power Supply, Pickup Threshold of Binary Inputs) Pos. 8
DC 24 V to 48 V, binary input threshold 19 V 2) 2
DC 60 V to 125 V 1), binary input threshold 19 V 2) 4
DC 110 V to 250 V 1), AC 115 V, binary input threshold 88 V 2) 5
DC 220 V to 250 V, AC 115 V, binary input threshold 176 V 2) 6
Housing / Number of Binary Inputs (BI) and Outputs (BO) Pos. 9
Flush mounting housing with screwed terminals, 1/2 x 19”, 8 BI, 16 BO A
Flush mounting housing with screwed terminals, 1/1 x 19”, 16 BI, 24 BO C
Flush mounting housing with screwed terminals, 1/1 x 19”, 24 BI, 32 BO D
Surface mounting housing with two-tier terminals, 1/2 x 19”, 8 BI, 16 BO E
Surface mounting housing with two-tier terminals, 1/1 x 19”, 16 BI, 24 BO G
Surface mounting housing with two-tier terminals, 1/1 x 19”, 24 BI, 32 BO H
Flush mounting housing with plug-in terminals, 1/2 x 19”, 8 BI, 16 BO J
Flush mounting housing with plug-in terminals, 1/1 x 19”, 16 BI, 24 BO L
Flush mounting housing with plug-in terminals, 1/1 x 19”, 24 BI, 32 BO M
Flush mounting housing with screwed terminals, 1/1 x 19”, 16 BI, 24 BO (thereof 5 with high-speed relay) N
Flush mounting housing with screwed terminals, 1/1 x 19”, 24 BI, 32 BO (thereof 5 with high-speed relay) P
Surface mounting housing with two-tier terminals, 1/1 x 19”, 16 BI, 24 BO (thereof 5 with high-speed relay) Q
Surface mounting housing with two-tier terminals, 1/1 x 19”, 24 BI, 32 BO (thereof 5 with high-speed relay) R
Flush mounting housing with plug-in terminals, 1/1 x 19”, 16 BI, 24 BO (thereof 5 with high-speed relay) S
Flush mounting housing with plug-in terminals, 1/1 x 19”, 24 BI, 32 BO (thereof 5 with high-speed relay) T
Flush mounting housing with screwed terminals, 1/1 x 19”, 22 BI, 44 BO U
Flush mounting housing with screwed terminals, 1/1 x 19”, 24 BI, 32 BO (thereof 10 with high-speed relay) W
1) with plug-in jumper one of the 2 voltage ranges can be selected
2) for each binary input one of 3 pickup threshold ranges can be selected with plug-in jumper
78 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(position 10 to 16)
7 S A 5 2 2 – – + L/M/N
A.1
Ordering Information and AccessoriesOrdering Information
A.1 Ordering Information
488 SIPROTEC 4, 7SA522, Manual
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Region-specific Default/Language Settings and Function Versions1)Pos. 10
Region DE, German language (language can be changed) A
Region World, English language (GB) (language can be changed) B
Region US, language English (US) (language can be changed) C
Region FR, French language (language can be changed) D
Region world, Spanish language (language can be changed) E
Region world, Italian language (language can be changed) F
1) Regulations for Region-specific Default and Function Settings:
Region World: Default setting f = 50 Hz and line length in km, no zero sequence power protection.
Region US: Default setting f = 60 Hz and line length in miles, only ANSI-inverse characteristic available, no zero sequence
power protection.
Region FR: Default setting f = 50 Hz and line length in km, with zero sequence power protection and weak infeed logic
according to the French Specification.
Region DE: Default setting f = 50 Hz and line length in km, only IEC inverse characteristic available, no logarithmic
inverse characteristic for earth fault protection, no zero sequence power protection, U0 inverse for earth fault protection
available.
7 8 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(position 10 to 16)
7 S A 5 2 2 – – + L/M/N
Port B Pos. 11
None 0
System port, IEC protocol 60870-5-103, electrical RS232 1
System port, IEC protocol 60870-5-103, electrical RS485 2
System port, IEC protocol 60870-5-103, optical 820 nm, ST connector 3
System port, Profibus FMS slave, electrical RS485 4
System port, Profibus FMS slave, optical 820°nm, double ring, ST-connector 6
For further protocols see additional information L (position 21 to 22) 9
Port C und D Pos. 12
None 0
DIGSI/Modem, electrical RS232, port C 1
DIGSI/Modem, electrical RS485, port C 2
DIGSI/Modem, optical 820 nm, ST-connector, port C 3
With port C and D see additional information M (position 23 to 24) 9
7 8 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(Stelle 21 bis 22)
7 S A 5 2 2 – – + L
Additional information L, further protocols port B Pos. 21, 22
System port, Profibus DP slave, electrical RS485 0, A
System port, Profibus DP slave, optical 820 nm, double ring, ST-connector 0, B
System port, DNP3.0, electrical RS485 0, G
System port, DNP3.0, optical 820 nm, double ring, ST-connector 0, H
System port, IEC 61850, 100 MBit Ethernet, double, electrical 0, R
System port, IEC 61850, 100 MBit Ethernet, double, optical 0, S
Ordering Information and AccessoriesOrdering Information
A.1 Ordering Information
SIPROTEC 4, 7SA522, Manual 489
C53000-G1176-C155-9, Edition 05.2016
7 8 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(Stelle 23 bis 24)
7 S A 5 2 2 – – + M
Additional information M, port C Pos. 23
None 0
DIGSI/Modem, electrical RS232 1
DIGSI/Modem, electrical RS485 2
DIGSI/Modem, Optical 820 nm, ST-Connector 3
Additional Information M, Port D Pos. 24
FO5 optical 820 nm, 2-ST connector, length of optical fibre up to 1.5 km for multimode-fibre for the
communication converter or FO direct connection
A
FO5 optical 820 nm, 2-ST connector, length of optical fibre up to 3.5 km for multimode-fibre for FO direct
connection
B
FO17 optical 1300 nm, 2-LC connector, length of optical fibre up to 24 km for monomode-fibre for FO
direct connection
G
FO18 optical 1300 nm, 2-LC connector, length of optical fibre up to 60 km for monomode-fibre for FO
direct connection
H
FO19 optical 1550 nm, 2-LC connector, length of optical fibre up to 100 km for monomode-fibre for FO
direct connection
J
FO30 optical 820 nm, 2-ST connector, length of optical fibre up to 1.5 km for multimode-fibre for the
communication networks with IEEE C37.94 interface or FO direct connection1)
S
1) This interface is only available in the flush-mounted housing (MLFB position 9).
78 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(Stelle 10 bis 16)
7 S A 5 2 2 – – + L/M/N
Functions 1 Pos. 13
Only three-pole tripping, without BCD-output fault location 0
Only three-pole tripping, with BCD-output fault location 1
Single/three-pole tripping, without BCD-output fault location 4
Single/three-pole tripping, with BCD-output fault location 5
With Function 1 and Port E see additional information N 9
Functions 2 Pos. 14
Distance pickup Z<, Polygon, without power swing option, without parallel line compensation C
Distance pickup Z<, MHO, without power swing option, without parallel line compensation E
Distance pickup Z<, Polygon, with power swing option, without parallel line compensation F
Distance pickup Z<, MHO, with power swing option, without parallel line compensation H
Distance pickup Z<, Polygon, without power swing option, with parallel line compensation 1) K
Distance pickup Z<, MHO, without power swing option, with parallel line compensation 1) M
Distance pickup Z<, Polygon, with power swing option, with parallel line compensation 1) N
Distance pickup Z<, MHO, with power swing option, with parallel line compensation 1) Q
1) only available with “1” or “5” on position 7
Ordering Information and AccessoriesOrdering Information
A.1 Ordering Information
490 SIPROTEC 4, 7SA522, Manual
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Functions 3 Pos. 15
Automatic Reclosure Synchro-Chec Breaker Failure Protection Voltage Protection
Frequency Protection
without without without without A
without without without with B
without without with without C
without without with with D
without with without without E
without with without with F
without with with without G
without with with with H
with without without without J
with without without with K
with without with without L
with without with with M
with with without without N
with with without with P
with with with without Q
with with with with R
Functions 4 Pos. 16
Earth Fault Protection / Directional for Earthed Networks Measured Values, Extended, Min/Max/Average
Values
without without 0
without with 1
with without 4
with with 5
7 8 9 10 11 12 13 14 15 16
Numerical Distance
Protection
(Stelle 25 bis 26)
7 S A 5 2 2 – – + N
Additional Specification N, Functions 1 Pos. 25
Only three-pole tripping, without BCD-output fault location 0
Only three-pole tripping, with BCD-output fault location 1
Single/three-pole tripping, without BCD-output fault location 4
Single/three-pole tripping, with BCD-output fault location 5
Additional Information N, Port E; for A) Direct Connection, B) Communication Networks Pos. 26
Optical 820 nm, 2-ST connector, length of optical fibre up to 1.5 km for multimode-fibre (FO5);A) or B) A
Optical 820 nm, 2-ST-connector, length of optical fibre up to 3.5 km for multimode-fibre (FO6) A) B
Optical 1300 nm, 2-LC connector, length of optical fibre up to 24 km for monomode fibre (FO17) A) G
Optical 1300 nm, 2-LC connector, length of optical fibre up to 60 km for monomode fibre (FO18) A) 1) H
Optical 1550 nm, 2-LC connector, length of optical fibre up to 100 km for monomode fibre (FO19) A) 1) J
Optical 820 nm, 2-ST connector, length of optical fibre up to 1.5 km for multimode-fibre (FO30, IEEE
C37.94 interface), A) oder B), 2)
S
1) For direct connection over short distances, a suitable optical attenuator should be used to avoid damage to
the device.
2) This interface is only available in the flush-mounted housing (MLFB position 9).
Ordering Information and AccessoriesOrdering Information
A.1 Ordering Information
SIPROTEC 4, 7SA522, Manual 491
C53000-G1176-C155-9, Edition 05.2016
Accessories
Voltage Transformer Miniature Circuit Breaker
Nominal Values Order Number
Thermal 1.6 A; magnetic 6 A 3RV1611-1AG14
Communication Converter
Converter for the serial connection of the 7SA5227SA522 distance protection to synchronous/asynchronous
communication interfaces X.21, G.703, telecommunications or symmetrical communication cables
Name Order Number
Optical-electrical communication converter CC-X/G
with synchronous interface (X.21 with 512 kbit/s,
G703 with 64 kbit/s)
7XV5662-0AA00
Optical-electrical communication converter CC-X/G
with asynchronous interface (X.21 with 512 kbit/s,
G703 with 64 kbit/s)
7XV5662-0AB01
2MBit optical-electrical communication converter Ku-
G703 for two FO channels and RS232 interface (G703
with 512 kBits/s)
7XV5662-0AD00
Optical–electrical communication converter CC-CC
with synchronous interface
7XV5662-0AC00
Optical–electrical communication converter CC-CC
with asynchronous interface
7XV5662-0AC01
Wide-area fibre optical repeater
Wide-area fibre optical repeater for long-distance transmission of serial signals (up to 170 km / 105.5 miles)
Name Order Number
Wide-area fibre optical repeater (24 km / 15 miles) 7XV5461-0BG00
Wide-area fibre optical repeater (60 km / 37.5 miles)1) 7XV5461-0BH00
Wide-area fibre optical repeater (100 km / 62 miles)1) 7XV5461-0BJ00
Wide-area fibre optical repeater (170 km / 105.5
miles)1)
7XV5461-0BM00
Bidirectional fibre optical repeater (40 km / 25 miles)
The communication is performed via fibre-optic
cables.)2)
7XV5461-0BK00
Bidirectional fibre optical repeater (40 km / 25 miles)
The communication is performed via fibre-optic
cables.)2)
7XV5461-0BL0
1) If wide-area fibre optical repeaters are used over distances that are below 25 km (7XV5461–0BH00) or
below 50 km (7XV5461–0BJ00) or below 100 km (7XV5461–0BM00), you have to reduce the transmitting
power using a set of optical attenuators (order number 7XV5107–0AA00). The two attenuators must be
installed on one side
2) A device with the order variant 7XV5461–0BK00 can only cooperate with a device of the order variant
7XV5461–0BL00.
Optical attenuators/fibre-optic cables
Name Order number
1 set of optical attenuators (2 pcs) 7XV5107-0AA00
Fibre-optic cables1) 6XV8100
A.2
Ordering Information and AccessoriesOrdering Information
A.2 Accessories
492 SIPROTEC 4, 7SA522, Manual
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1) Fibre-optic cables with different connectors, in different lengths and designs. More information will be avail-
able from your local Siemens sales representative.
Isolating Transformers
Isolating transformers are needed on copper lines if the longitudinal voltage induced in the pilot wires can
result in more than 60 % of the test voltage at the communication converter (i.e. 3 kV for CC-CU). They are
connected between the communication converter and the communication line.
Name Order Number
Isolation transformer, test voltage 20 kV 7XR9516
External Converters
Optical interfaces for Profibus and DNP 3.0 are not possible with Aufbau housings. Please order in this case a
device with the appropriate electrical RS485 interface, and the additional OLM converters listed below . Note:
The OLM converter 6GK1502-3CB10 requires an operating voltage of DC 24 V. If the operating voltage is >
DC 24 V the additional power supply 7XV5810-0BA00 is required.
Interface used Order device with additional module/OLM converter
Profibus DP/FMS double ring Profibus DP/FMS RS485/ 6GK1502-3CB01
DNP 3.0 820 nm DNP 3.0 RS485/ 7XV5650-0BA00
Exchangeable Interface Modules
Name Order Number
RS232 C53207-A351-D641-1
RS485 C53207-A351-D642-1
LWL 820 nm C53207-A351-D643-1
Profibus DP RS485 C53207-A351-D611-1
Profibus DP double ring C53207-A351-D613-1
Profibus FMS RS485 C53207-A351-D603-1
Profibus FMS double ring C53207-A351-D606-1
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
FO5 with ST connector; 820 nm; multimode optical fibre - maximum
length: 1.5 km (0.94 miles)1)
C53207-A351-D651-1
FO5 with ST connector; 820 nm; multimode optical fibre - maximum
length: 1.5 km (0.94 miles); for surface mounting housing1)
C53207-A406-D49-1
FO6 with ST-connector; 820 nm; multimode optical fibre - maximum
length: 3.5 km (2.2 miles)
C53207-A351-D652-1
FO6 with ST connector; 820 nm; multimode optical fibre - maximum
length: 3.5 km; for surface mounting housing
C53207-A406-D50-1
FO17 with LC duplex connector; 1300 nm; monomode optical fibre -
maximum length: 24 km (15 miles)
C53207-A351-D655-1
FO18 with LC duplex connector; 1300 nm; monomode optical fibre -
maximum length: 60 km (37.5 miles)
C53207-A351-D656-1
FO19 with LC duplex connector; 1550 nm; monomode optical fibre -
maximum length: 100 km (62.5 miles)
C53207-A351-D657-1
FO30 with ST connector; 820 nm; multimode optical fibre - maximum
length: 1.5 km (0.94 miles) (IEEE C37.94 interface)2)
C53207-A351-D658-1
Ethernet electrical (EN 100) C53207-A351-D675-2
Ethernet optical (EN 100) C53207-A351-D678-1
Ordering Information and AccessoriesOrdering Information
A.2 Accessories
SIPROTEC 4, 7SA522, Manual 493
C53000-G1176-C155-9, Edition 05.2016
1) also used for connection to the optical-electrical communication converter
2) Module FO30 can only be used in a flush mounting housing
Terminal Block Covering Caps
Terminal Block Covering Cap for 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
Short Circuit Links for Purpose/Terminal Type Order No.
Voltage connections (18 terminal or 12 terminal) C73334-A1-C34-1
Current connections (12 terminal or 8 terminal) C73334-A1-C33-1
Plug-in Connector
Plug-in Connector Order No.
2-pin C73334-A1-C35-1
3-pin C73334-A1-C36-1
Mounting Brackets for 19" Racks
Name Order No.
2 mounting brackets C73165-A63-D200-1
Buffer battery
Lithium battery 3 V/1 Ah, type CR 1/2 AA Order No.
VARTA 6127 101 301
Panasonic BR-1/2AA
Interface Cable
An interface cable and the DIGSI operating software are required for the communication between the
SIPROTEC 4 device and a PC or laptop: The PC or laptop must run MS-WINDOWS 95, MS-WINDOWS 98, MS-
WINDOWS NT 4, MS-WINDOWS 2000, MS-WINDOWS ME, MS-WINDOWS XP PRO or MS-WINDOWS VISTA
Name Order No.
Interface cable between PC and SIPROTEC, Cable with
9-pin male/female connectors
7XV5100-4
Ordering Information and AccessoriesOrdering Information
A.2 Accessories
494 SIPROTEC 4, 7SA522, Manual
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Panel Flush Mounting or Cubicle Mounting
7SA522*-*A/J
[schrankeinbau-7sa522-a-j-wlk-261102, 1, en_GB]
Figure B-1 General diagram 7SA522*-*A/J (panel flush mounting or cubicle mounting; size 1/2)
B.1
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
496 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*C/L
[schrankeinbau-7sa522-c-l-wlk-261102, 1, en_GB]
Figure B-2 General diagram 7SA522*-*C/L (panel flush mounting or cubicle mounting; size 1/1)
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
SIPROTEC 4, 7SA522, Manual 497
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*N/S
[schrankeinbau-7sa522-n-s-wlk-261102, 1, en_GB]
Figure B-3 General diagram 7SA522*-*N/S (panel flush mounting or cubicle mounting; size 1/1)
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
498 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*D/M
[schrankeinbau-7sa522-d-m-wlk-261102, 1, en_GB]
Figure B-4 General diagram 7SA522*-*D/M (panel flush mounting or cubicle mounting; size 1/1)
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
SIPROTEC 4, 7SA522, Manual 499
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*P/T
[schrankeinbau-7sa522-p-t-wlk-261102, 1, en_GB]
Figure B-5 General diagram 7SA522*-*P/T (panel flush mounting or cubicle mounting; size 1/1)
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
500 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*U
[schrankeinbau-mit-c-i-o-bausteine-st-140404, 1, en_GB]
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
SIPROTEC 4, 7SA522, Manual 501
C53000-G1176-C155-9, Edition 05.2016
[schrankeinbau-mit-c-i-o-bausteine-seite2-st-140404, 1, en_GB]
Figure B-6 General diagram 7SA522*-*U (panel flush mounting or cubicle mounting; size 1/1)
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
502 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*W
[schrankeinbau-7sa522-w-wlk-040421, 1, en_GB]
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
SIPROTEC 4, 7SA522, Manual 503
C53000-G1176-C155-9, Edition 05.2016
[schrankeinbau-7sa522-w-seite2-wlk-040421, 1, en_GB]
Figure B-7 General diagram 7SA522*-*W (panel flush mounting or cubicle mounting; size 1/1)
Terminal Assignments
B.1 Panel Flush Mounting or Cubicle Mounting
504 SIPROTEC 4, 7SA522, Manual
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Housing for Panel Surface Mounting
7SA522*-*E
[schalttafelaufbau-7sa522-e-wlk-261102, 1, en_GB]
Figure B-8 General diagram 7SA522*-*E (panel surface mounting; size 1/2)
B.2
Terminal Assignments
B.2 Housing for Panel Surface Mounting
SIPROTEC 4, 7SA522, Manual 505
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*E (up to development state /DD)
[schalttafelaufbau-7sa522-e-dd-wlk-261102, 1, en_GB]
Figure B-9 General diagram 7SA522*-*E up to development state /DD (panel surface mounting; size 1/2)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
506 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*E (beginning with development state /EE)
[schalttafelaufbau-7sa522-e-ee-wlk-261102, 1, en_GB]
Figure B-10 General diagram 7SA522*-*E beginning with development state /EE (panel surface mounting;
size 1/2)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
SIPROTEC 4, 7SA522, Manual 507
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*G
[schalttafelaufbau-7sa522-g-wlk-261102, 1, en_GB]
Figure B-11 General diagram 7SA522*-*G (panel surface mounting; size 1/1)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
508 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*Q
[schalttafelaufbau-7sa522-q-wlk-261102, 1, en_GB]
Figure B-12 General diagram 7SA522*-*Q (panel surface mounting; size 1/1)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
SIPROTEC 4, 7SA522, Manual 509
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*H
[schalttafelaufbau-7sa522-h-wlk-261102, 1, en_GB]
Figure B-13 General diagram 7SA522*-*H (panel surface mounting; size 1/1)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
510 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*R
[schalttafelaufbau-7sa522-r-wlk-261102, 1, en_GB]
Figure B-14 General diagram 7SA522*-*R (panel surface mounting; size 1/1)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
SIPROTEC 4, 7SA522, Manual 511
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*G/H/Q/R (up to development state /DD)
[schrankeinbau-7sa522-ghqr-dd-wlk-261102, 1, en_GB]
Figure B-15 General diagram 7SA522*-*G/H/Q/R up to development state /DD (panel surface mounting;
size 1/1)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
512 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
7SA522*-*G/H/Q/R (beginning with development state /EE)
[schrankeinbau-7sa522-ghqr-ee-wlk-261102, 1, en_GB]
Figure B-16 General diagram 7SA522*-*G/H/Q/R beginning at development state /EE (panel surface
mounting; size 1/1)
Terminal Assignments
B.2 Housing for Panel Surface Mounting
SIPROTEC 4, 7SA522, Manual 513
C53000-G1176-C155-9, Edition 05.2016
514 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Current Transformer Examples
[anschl-beisp-3stromwandl-sternpkt-oz-291102, 1, en_GB]
Figure C-1 Current connections to three current transformers and starpoint current (normal circuit layout)
C.1
Connection Examples
C.1 Current Transformer Examples
516 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[anschl-beisp-3stromw-erdstromw1-oz-291102, 1, en_GB]
Figure C-2 Current connections to 3 current transformers with separate earth current transformer
(summation current transformer) prefered for solidly or low-resistive earthed systems.
Important! The cable shield must be grounded on the cable side.
In case of an earthing of the current transformers on the busbar side, the current polarity of the device is
changed via the address 0201. This also reverses the polarity of the current input IE or IEE. Therefore the
connections of S1 and S2 must be exchanged at Q8 and Q7 when using a toroidal current transformer.
Connection Examples
C.1 Current Transformer Examples
SIPROTEC 4, 7SA522, Manual 517
C53000-G1176-C155-9, Edition 05.2016
[anschl-beisp-3stromw-erdstrom-v-sternpkt-2-oz-291102, 1, en_GB]
Figure C-3 Current connections to three current transformers and earth current from the star-point
connection of a parallel line (for parallel line compensation)
Connection Examples
C.1 Current Transformer Examples
518 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[anschl-beisp-3stromw-erdstrom-aus-sternpkt-1-oz-291102, 1, en_GB]
Figure C-4 Current connections to three current transformers and earth current from the star-point
current of an earthed power transformer (for directional earth fault protection)
Connection Examples
C.1 Current Transformer Examples
SIPROTEC 4, 7SA522, Manual 519
C53000-G1176-C155-9, Edition 05.2016
Voltage Transformer Examples
[anschl-beisp-spgw-anschl-normalanschl-oz-291102, 1, en_GB]
Figure C-5 Voltage connections to three wye-connected voltage transformers (normal circuit layout)
C.2
Connection Examples
C.2 Voltage Transformer Examples
520 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
[anschl-beisp-spgw-anschl-mit-e-n-wickl-oz-291102, 1, en_GB]
Figure C-6 Voltage connections to three wye-connected voltage transformers with additional open-delta
windings (e–n–winding)
Connection Examples
C.2 Voltage Transformer Examples
SIPROTEC 4, 7SA522, Manual 521
C53000-G1176-C155-9, Edition 05.2016
[anschl-beisp-spgw-anschl-und-ss-spg-2-oz-291102, 1, en_GB]
Figure C-7 Voltage connections to three wye-connected voltage transformers and additionally to a busbar
voltage (for overvoltage protection or synchronism check)
Connection Examples
C.2 Voltage Transformer Examples
522 SIPROTEC 4, 7SA522, Manual
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Default Settings and Protocol-dependent Functions
When the device leaves the factory, a large number of LED indications, binary inputs and outputs as well as
function keys are already preset. They are summarised in the following table.
D.1 LEDs 524
D.2 Binary Input 525
D.3 Binary Output 526
D.4 Function Keys 527
D.5 Default Display 528
D.6 Pre-defined CFC Charts 529
D.7 Protocol-dependent Functions 530
D
SIPROTEC 4, 7SA522, Manual 523
C53000-G1176-C155-9, Edition 05.2016
LEDs
Table D-1 LED Indication Presettings
LEDs Allocated Function Function No. Description
LED1 Relay PICKUP L1 503 Relay PICKUP Phase L1
LED2 Relay PICKUP L2 504 Relay PICKUP Phase L2
LED3 Relay PICKUP L3 505 Relay PICKUP Phase L3
LED4 Relay PICKUP E 506 Relay PICKUP Earth
LED5 EF reverse 1359 E/F picked up REVERSE
Dis. reverse 3720 Distance Pickup REVERSE
LED6 Relay TRIP 511 Relay GENERAL TRIP command1)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1232)
LED7 Relay TRIP 1pL1 512 Relay TRIP command - Only Phase L12)
Relay TRIP 1pL2 513 Relay TRIP command - Only Phase L22)
Relay TRIP 1pL3 514 Relay TRIP command - Only Phase L32)
LED8 Dis.TripZ1/1p 3811 Distance TRIP single-phase Z12)
DisTRIP3p. Z1sf 3823 DisTRIP 3phase in Z1 with single-ph Flt.
DisTRIP3p. Z1mf 3824 DisTRIP 3phase in Z1 with multi-ph Flt.
LED9 Dis.TripZ1B1p 3813 Distance TRIP single-phase Z1B2)
DisTRIP3p.Z1Bsf 3825 DisTRIP 3phase in Z1B with single-ph Flt
DisTRIP3p Z1Bmf 3826 DisTRIP 3phase in Z1B with multi-ph Flt.
LED10 Dis.TripZ2/1p 3816 Distance TRIP single-phase Z22)
Dis.TripZ2/3p 3817 Distance TRIP 3phase in Z2
LED11 Dis.TripZ3/T3 3818 Distance TRIP 3phase in Z3
Dis.TRIP 3p. Z4 3821 Distance TRIP 3phase in Z4
Dis.TRIP 3p. Z5 3822 Distance TRIP 3phase in Z5
LED12 AR not ready 2784 AR: Auto-reclose is not ready3)
LED13 Emer. mode 2054 Emergency mode
LED14 Alarm Sum Event 160 Alarm Summary Event
1) only devices with three-pole tripping only
2) only devices with single-pole and three-pole tripping
3) only devices with automatic reclosure function
D.1
Default Settings and Protocol-dependent Functions
D.1 LEDs
524 SIPROTEC 4, 7SA522, Manual
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Binary Input
Table D-2 Binary input presettings for all devices and ordering variants
Binary Input Allocated Function Function No. Description
BI1 >Reset LED 5 >Reset LED
BI2 >Manual Close 356 >Manual close signal
BI3 >FAIL:Feeder VT 361 >Failure: Feeder VT (MCB tripped)
>I-STUB ENABLE 7131 >Enable I-STUB-Bus function
BI4 >DisTel Rec.Ch1 4006 >Dis.Tele. Carrier RECEPTION Channel 1
BI5 >1p Trip Perm 381 >Single-phase trip permitted from ext.AR1)
1) only devices with single-pole and three-pole tripping
D.2
Default Settings and Protocol-dependent Functions
D.2 Binary Input
SIPROTEC 4, 7SA522, Manual 525
C53000-G1176-C155-9, Edition 05.2016
Binary Output
Table D-3 Output relay presettings for all devices and ordering variants
Binary Output Allocated Function Function No. Description
BO1 Relay PICKUP 501 Relay PICKUP
BO2 Dis.T.SEND 4056 Dis. Telep. Carrier SEND signal
BO3 nicht vorbelegt - -
BO4 Relay TRIP 511 Relay GENERAL TRIP command1)
Relay TRIP 1pL1 512 Relay TRIP command - Only Phase L13)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1233)
BO5 Relay TRIP 511 Relay GENERAL TRIP command1)
Relay TRIP 1pL2 513 Relay TRIP command - Only Phase L23)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1233)
BO6 Relay TRIP 1pL3 514 Relay TRIP command - Only Phase L33)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1233)
BO7 AR CLOSE Cmd. 2851 AR: Close command2)
BO8 DisTRIP3p. Z1sf 3823 DisTRIP 3phase in Z1 with single-ph Flt.3)
DisTRIP3p.Z1Bsf 3825 DisTRIP 3phase in Z1B with single-ph Flt3)
Dis.TripZ1/1p 3811 Distance TRIP single-phase Z13)
Dis.TripZ1B1p 3813 Distance TRIP single-phase Z1B3)
BO9 DisTRIP3p. Z1sf 3823 DisTRIP 3phase in Z1 with single-ph Flt.3)
DisTRIP3p. Z1mf 3824 DisTRIP 3phase in Z1 with multi-ph Flt.3)
DisTRIP3p.Z1Bsf 3825 DisTRIP 3phase in Z1B with single-ph Flt3)
DisTRIP3p Z1Bmf 3826 DisTRIP 3phase in Z1B with multi-ph Flt.3)
BO10 DisTRIP3p. Z1sf 3823 DisTRIP 3phase in Z1 with single-ph Flt.3)
DisTRIP3p.Z1Bsf 3825 DisTRIP 3phase in Z1B with single-ph Flt3)
BO11 DisTRIP3p. Z1mf 3824 DisTRIP 3phase in Z1 with multi-ph Flt.3)
DisTRIP3p Z1Bmf 3826 DisTRIP 3phase in Z1B with multi-ph Flt.3)
BO12 Alarm Sum Event 160 Alarm Summary Event
BO13 Relay TRIP 511 Relay GENERAL TRIP command3)
Relay TRIP 1pL1 512 Relay TRIP command - Only Phase L13)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1233)
BO14 Relay TRIP 511 Relay GENERAL TRIP command3)
Relay TRIP 1pL2 513 Relay TRIP command - Only Phase L23)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1233)
BO15 Relay TRIP 1pL3 514 Relay TRIP command - Only Phase L33)
Relay TRIP 3ph. 515 Relay TRIP command Phases L1233)
1) only devices with three-pole tripping
2) only devices with single-pole and three-pole tripping
3) only devices with automatic reclosure function
D.3
Default Settings and Protocol-dependent Functions
D.3 Binary Output
526 SIPROTEC 4, 7SA522, Manual
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Function Keys
Table D-4 Applies to all devices and ordered variants
Function Keys Allocated Function
F1 Display of operational indications
F2 Display of the primary operational measured values
F3 An overview of the last eight network faults
F4 Not pre-assigned
D.4
Default Settings and Protocol-dependent Functions
D.4 Function Keys
SIPROTEC 4, 7SA522, Manual 527
C53000-G1176-C155-9, Edition 05.2016
Default Display
4-line Display
Table D-5 This selection is available as start page which may be configured.
Seite 1
Seite 2
Seite 3
Seite 4
Seite 5
Spontaneous Fault Indication of the 4-Line Display
The spontaneous annunciations on devices with 4-line display serve to display the most important data about
a fault. They appear automatically in the display after pick-up of the device, in the sequence shown below.
Relay PICKUP: A message indicating the protective function that picked up first
PU Time=: Elapsed time from pick-up until drop-off
Trip time=: Elapsed time from pick-up until the first trip command of a protection function
Fault locator Fault distance d in km or miles
D.5
Default Settings and Protocol-dependent Functions
D.5 Default Display
528 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Pre-defined CFC Charts
Some CFC charts are already supplied with the SIPROTEC 4 device. Depending on the variant the following
charts may be implemented:
Device and system logic
Some of the event-controlled logical allocations are created with blocks of the slow logic (PLC1_BEARB= slow
PLC processing). This way, the binary input “>Data Stop” is modified from a single point indication (SP) into an
internal single point indication (IntSP) by means of a negator block.
With double point indication “EarthSwit.”CLOSE an indication saying “fdrEARTHED” ON and with “Earth- Swit.”=
OPEN or INT the indication“fdrEARTHED” OFF is generated.
From the output indication “definite TRIP” the internal indication “Brk OPENED” is generated. As indication
“definite TRIP” only queued for 500 ms, also indication “Device Brk OPENED” is reset after this time period.
[verbindg-ein-ausgng-syslogik-wlk080802, 1, en_GB]
Figure D-1 Allocation of input and output with blocks of priority class System Logic
D.6
Default Settings and Protocol-dependent Functions
D.6 Pre-defined CFC Charts
SIPROTEC 4, 7SA522, Manual 529
C53000-G1176-C155-9, Edition 05.2016
Protocol-dependent Functions
Protocoll → IEC 60870-5-103 IEC 61850
Ethernet
(EN-100)
Profibus FMS Profibus DP DNP3.0 Additional
Service Inter-
face
(optional)
Function ↓
Operational meas-
ured values
Yes Yes Yes Yes Yes Yes
Metered values Yes Yes Yes Yes Yes Yes
Fault recording Yes Yes Yes No. Only via
additional
service inter-
face
No. Only via
additional
service inter-
face
Yes
Remote protection
setting
No. Only via addi-
tional service
interface
Yes
with DIGSI via
Ethernet
Yes
with DIGSI via
PROFIBUS
No. Only via
additional
service inter-
face
No. Only via
additional
service inter-
face
Yes
User-defined
annunciations and
switching objects
Yes Yes Yes Predefined
“User-defined
Alarms” in CFC
Predefined
“User-defined
Alarms” in CFC
Yes
Time synchronisa-
tion
Via Protocol;
DCF77/IRIG B;
Interface; Binary
input
Via Protocol
(NTP);
DCF77/IRIG B;
Interface;
Binary input
Via Protocol;
DCF77/IRIG B;
Interface;
Binary input
Via DCF77/
IRIG B;
Interface;
Binary input
Via Protokoll;
DCF77/IRIG B;
Interface;
Binary input
-
Messages with time
stamp
Yes Yes Yes Yes Yes Yes
Commissioning aids
Measured value
indication blocking
Yes Yes Yes No No Yes
Generation of test
indications
Yes Yes Yes No No Yes
Physical mode Asynchronous Synchronous Asynchronous Asynchronous Asynchronous -
Physical mode Cyclical/Event Cyclical/Event Cyclical/Event Cyclical Cyclical/Event -
Baud rate 4800 to 38400 up to
100 MBaud
up to
1.5 MBaud
up to zu
1.5 MBaud
2400 to 19200 2400 to
115200
ype RS 232 RS 485
fibre optic cable
Ethernet TP RS485 fibre
optic cable
Double ring
RS485 fibre
optic cable
Double ring
RS485 fibre
optic cable
RS232 RS485
D.7
Default Settings and Protocol-dependent Functions
D.7 Protocol-dependent Functions
530 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Functional Scope
Addr. Information Setting Options Default Setting Comments
103 Grp Chge OPTION Disabled
Enabled
Disabled Setting Group Change Option
110 Trip mode 3pole only
1-/3pole
3pole only Trip mode
112 Phase Distance Quadrilateral
MHO
Disabled
Quadrilateral Phase Distance
113 Earth Distance Quadrilateral
MHO
Disabled
Quadrilateral Earth Distance
119 Iph>(Z1) Disabled
Enabled
Disabled Additional Threshold Iph>(Z1)
120 Power Swing Disabled
Enabled
Disabled Power Swing detection
121 Teleprot. Dist. PUTT (Z1B)
POTT
UNBLOCKING
BLOCKING
SIGNALv.ProtInt
Disabled
Disabled Teleprotection for Distance prot.
122 DTT Direct Trip Disabled
Enabled
Disabled DTT Direct Transfer Trip
124 SOTF Overcurr. Disabled
Enabled
Disabled Instantaneous HighSpeed SOTF
Overcurrent
125 Weak Infeed Disabled
Enabled
Logic no. 2
Disabled Weak Infeed (Trip and/or Echo)
126 Back-Up O/C Disabled
TOC IEC
TOC ANSI
TOC IEC /w 3ST
TOC IEC Backup overcurrent
131 Earth Fault O/C Disabled
TOC IEC
TOC ANSI
TOC Logarithm.
Definite Time
U0 inverse
Sr inverse
Disabled Earth fault overcurrent
132 Teleprot. E/F Dir.Comp.Pickup
SIGNALv.ProtInt
UNBLOCKING
BLOCKING
Disabled
Disabled Teleprotection for Earth fault over-
curr.
E.1
Functions, Settings, Information
E.1 Functional Scope
532 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Information Setting Options Default Setting Comments
133 Auto Reclose 1 AR-cycle
2 AR-cycles
3 AR-cycles
4 AR-cycles
5 AR-cycles
6 AR-cycles
7 AR-cycles
8 AR-cycles
ADT
Disabled
Disabled Auto-Reclose Function
134 AR control mode Pickup w/ Tact
Pickup w/o Tact
Trip w/ Tact
Trip w/o Tact
Trip w/ Tact Auto-Reclose control mode
135 Synchro-Check Disabled
Enabled
Disabled Synchronism and Voltage Check
136 FREQUENCY Prot. Disabled
Enabled
Disabled Over / Underfrequency Protection
137 U/O VOLTAGE Disabled
Enabled
Enabl. w. comp.
Disabled Under / Overvoltage Protection
138 Fault Locator Enabled
Disabled
with BCD-output
Enabled Fault Locator
139 BREAKER FAILURE Disabled
Enabled
enabled w/ 3I0>
Disabled Breaker Failure Protection
140 Trip Cir. Sup. Disabled
1 trip circuit
2 trip circuits
3 trip circuits
Disabled Trip Circuit Supervision
145 P. INTERFACE 1 Enabled
Disabled
IEEE C37.94
Enabled Protection Interface 1 (Port D)
146 P. INTERFACE 2 Disabled
Enabled
IEEE C37.94
Disabled Protection Interface 2 (Port E)
147 NUMBER OF RELAY 2 relays
3 relays
2 relays Number of relays
Functions, Settings, Information
E.1 Functional Scope
SIPROTEC 4, 7SA522, Manual 533
C53000-G1176-C155-9, Edition 05.2016
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon-
dary nominal current of the current transformer.
Addr. Parameter Function C Setting Options Default Setting Comments
201 CT Starpoint P.System Data 1 towards Line
towards Busbar
towards Line CT Starpoint
203 Unom PRIMARY P.System Data 1 1.0 .. 1200.0 kV 400.0 kV Rated Primary Voltage
204 Unom SECONDARY P.System Data 1 80 .. 125 V 100 V Rated Secondary Voltage
(Ph-Ph)
205 CT PRIMARY P.System Data 1 10 .. 5000 A 1000 A CT Rated Primary Current
206 CT SECONDARY P.System Data 1 1A
5A
1A CT Rated Secondary
Current
207 SystemStarpoint P.System Data 1 Solid Earthed
Peterson-Coil
Isolated
Solid Earthed System Starpoint is
210 U4 transformer P.System Data 1 Not connected
Udelta transf.
Usy2 transf.
Ux transformer
Not connected U4 voltage transformer is
211 Uph / Udelta P.System Data 1 0.10 .. 9.99 1.73 Matching ratio Phase-VT
To Open-Delta-VT
212 Usy2 connection P.System Data 1 L1-E
L2-E
L3-E
L1-L2
L2-L3
L3-L1
L1-L2 VT connection for Usy2
214A φ Usy2-Usy1 P.System Data 1 0 .. 360 ° 0 ° Angle adjustment Usy2-
Usy1
215 Usy1/Usy2 ratio P.System Data 1 0.50 .. 2.00 1.00 Matching ratio Usy1 /
Usy2
220 I4 transformer P.System Data 1 Not connected
In prot. line
In paral. line
IY starpoint
In prot. line I4 current transformer is
221 I4/Iph CT P.System Data 1 0.010 .. 5.000 1.000 Matching ratio I4/Iph for
CT's
230 Rated Frequency P.System Data 1 50 Hz
60 Hz
50 Hz Rated Frequency
235 PHASE SEQ. P.System Data 1 L1 L2 L3
L1 L3 L2
L1 L2 L3 Phase Sequence
236 Distance Unit P.System Data 1 km
Miles
km Distance measurement
unit
237 Format Z0/Z1 P.System Data 1 RE/RL, XE/XL
K0
RE/RL, XE/XL Setting format for zero
seq.comp. format
238A EarthFltO/C 1p P.System Data 1 stages together
stages separat.
stages together Earth Fault O/C: setting
for 1pole AR
E.2
Functions, Settings, Information
E.2 Settings
534 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
239 T-CB close P.System Data 1 0.01 .. 0.60 sec 0.06 sec Closing (operating) time
of CB
240A TMin TRIP CMD P.System Data 1 0.02 .. 30.00 sec 0.10 sec Minimum TRIP Command
Duration
241A TMax CLOSE CMD P.System Data 1 0.01 .. 30.00 sec 0.10 sec Maximum Close
Command Duration
242 T-CBtest-dead P.System Data 1 0.00 .. 30.00 sec 0.10 sec Dead Time for CB test-
autoreclosure
302 CHANGE Change Group Group A
Group B
Group C
Group D
Binary Input
Protocol
Group A Change to Another
Setting Group
402A WAVEFORM-
TRIGGER
Osc. Fault Rec. Save w. Pickup
Save w. TRIP
Start w. TRIP
Save w. Pickup Waveform Capture
403A WAVEFORM DATA Osc. Fault Rec. Fault event
Pow.Sys.Flt.
Fault event Scope of Waveform Data
410 MAX. LENGTH Osc. Fault Rec. 0.30 .. 5.00 sec 2.00 sec Max. length of a Wave-
form Capture Record
411 PRE. TRIG. TIME Osc. Fault Rec. 0.05 .. 0.50 sec 0.25 sec Captured Waveform Prior
to Trigger
412 POST REC. TIME Osc. Fault Rec. 0.05 .. 0.50 sec 0.10 sec Captured Waveform after
Event
415 BinIn CAPT.TIME Osc. Fault Rec. 0.10 .. 5.00 sec; ∞ 0.50 sec Capture Time via Binary
Input
610 FltDisp.LED/LCD Device Target on PU
Target on TRIP
Target on PU Fault Display on LED / LCD
625A T MIN LED HOLD Device 0 .. 60 min; ∞ 0 min Minimum hold time of
latched LEDs
640 Start image DD Device image 1
image 2
image 3
image 4
image 5
image 1 Start image Default
Display
1103 FullScaleVolt. P.System Data 2 1.0 .. 1200.0 kV 400.0 kV Measurement: Full Scale
Voltage (100%)
1104 FullScaleCurr. P.System Data 2 10 .. 5000 A 1000 A Measurement: Full Scale
Current (100%)
1105 Line Angle P.System Data 2 10 .. 89 ° 85 ° Line Angle
1107 P,Q sign P.System Data 2 not reversed
reversed
not reversed P,Q operational measured
values sign
1110 x' P.System Data 2 1A 0.0050 ..
9.5000 Ω/km
0.1500 Ω/km x' - Line Reactance per
length unit
5A 0.0010 ..
1.9000 Ω/km
0.0300 Ω/km
1111 Line Length P.System Data 2 0.1 .. 1000.0 km 100.0 km Line Length
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 535
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1112 x' P.System Data 2 1A 0.0050 ..
15.0000 Ω/mi
0.2420 Ω/mi x' - Line Reactance per
length unit
5A 0.0010 ..
3.0000 Ω/mi
0.0484 Ω/mi
1113 Line Length P.System Data 2 0.1 .. 650.0 Miles 62.1 Miles Line Length
1114 c' P.System Data 2 1A 0.000 ..
100.000 µF/km
0.010 µF/km c' - capacit. per unit line
len. µF/km
5A 0.000 ..
500.000 µF/km
0.050 µF/km
1115 c' P.System Data 2 1A 0.000 ..
160.000 µF/mi
0.016 µF/mi c' - capacit. per unit line
len. µF/mile
5A 0.000 ..
800.000 µF/mi
0.080 µF/mi
1116 RE/RL(Z1) P.System Data 2 -0.33 .. 10.00 1.00 Zero seq. comp. factor
RE/RL for Z1
1117 XE/XL(Z1) P.System Data 2 -0.33 .. 10.00 1.00 Zero seq. comp. factor
XE/XL for Z1
1118 RE/RL(> Z1) P.System Data 2 -0.33 .. 10.00 1.00 Zero seq. comp.factor RE/
RL(> Z1)
1119 XE/XL(> Z1) P.System Data 2 -0.33 .. 10.00 1.00 Zero seq. comp.factor XE/
XL(> Z1)
1120 K0 (Z1) P.System Data 2 0.000 .. 4.000 1.000 Zero seq. comp. factor K0
for zone Z1
1121 Angle K0(Z1) P.System Data 2 -180.00 .. 180.00 ° 0.00 ° Zero seq. comp. angle for
zone Z1
1122 K0 (> Z1) P.System Data 2 0.000 .. 4.000 1.000 Zero seq.comp.factor
K0,higher zones >Z1
1123 Angle K0(> Z1) P.System Data 2 -180.00 .. 180.00 ° 0.00 ° Zero seq. comp. angle,
higher zones >Z1
1126 RM/RL ParalLine P.System Data 2 0.00 .. 8.00 0.00 Mutual Parallel Line
comp. ratio RM/RL
1127 XM/XL ParalLine P.System Data 2 0.00 .. 8.00 0.00 Mutual Parallel Line
comp. ratio XM/XL
1128 RATIO Par. Comp P.System Data 2 50 .. 95 % 85 % Neutral current RATIO
Parallel Line Comp
1130A PoleOpenCurrent P.System Data 2 1A 0.05 .. 1.00 A 0.10 A Pole Open Current
Threshold
5A 0.25 .. 5.00 A 0.50 A
1131A PoleOpenVoltage P.System Data 2 2 .. 70 V 30 V Pole Open Voltage
Threshold
1132A SI Time all Cl. P.System Data 2 0.01 .. 30.00 sec 0.05 sec Seal-in Time after ALL
closures
1133A T DELAY SOTF P.System Data 2 0.05 .. 30.00 sec 0.25 sec minimal time for line
open before SOTF
1134 Line Closure P.System Data 2 only with ManCl
I OR U or ManCl
CB OR I or M/C
I or Man.Close
only with ManCl Recognition of Line
Closures with
1135 Reset Trip CMD P.System Data 2 CurrentOpenPole
Current AND CB
Pickup Reset
CurrentOpenPole RESET of Trip Command
Functions, Settings, Information
E.2 Settings
536 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1136 OpenPoleDetect. P.System Data 2 OFF
Current AND CB
w/ measurement
w/ measurement open pole detector
1140A I-CTsat. Thres. P.System Data 2 1A 0.2 .. 50.0 A; ∞ 20.0 A CT Saturation Threshold
5A 1.0 .. 250.0 A; ∞ 100.0 A
1150A SI Time Man.Cl P.System Data 2 0.01 .. 30.00 sec 0.30 sec Seal-in Time after
MANUAL closures
1151 MAN. CLOSE P.System Data 2 with Sync-check
w/o Sync-check
NO
NO Manual CLOSE
COMMAND generation
1152 Man.Clos. Imp. P.System Data 2 (Einstellmöglich-
keiten anwendung-
sabhängig)
none MANUAL Closure Impulse
after CONTROL
1155 3pole coupling P.System Data 2 with PICKUP
with TRIP
with TRIP 3 pole coupling
1156A Trip2phFlt P.System Data 2 3pole
1pole leading Ø
1pole lagging Ø
3pole Trip type with 2phase
faults
1201 FCT Distance Dis. General ON
OFF
ON Distance protection
1202 Minimum Iph> Dis. General 1A 0.05 .. 4.00 A 0.10 A Phase Current threshold
for dist. meas.
5A 0.25 .. 20.00 A 0.50 A
1203 3I0> Threshold Dis. General 1A 0.05 .. 4.00 A 0.10 A 3I0 threshold for neutral
current pickup
5A 0.25 .. 20.00 A 0.50 A
1204 3U0> Threshold Dis. General 1 .. 100 V; ∞ 5 V 3U0 threshold zero seq.
voltage pickup
1205 3U0> COMP/ISOL. Dis. General 10 .. 200 V; ∞ ∞ V 3U0> pickup (comp/ isol.
star-point)
1206 T3I0 1PHAS Dis. General 0.00 .. 0.50 sec; ∞ 0.04 sec Delay 1ph-faults (comp/
isol. star-point)
1207A 3I0>/ Iphmax Dis. General 0.05 .. 0.30 0.10 3I0>-pickup-stabilisation
(3I0> /Iphmax)
1208 SER-COMP. Dis. General NO
YES
NO Series compensated line
1209A E/F recognition Dis. General 3I0> OR 3U0>
3I0> AND 3U0>
3I0> OR 3U0> criterion of earth fault
recognition
1210 Start Timers Dis. General on Dis. Pickup
on Zone Pickup
on Dis. Pickup Condition for zone timer
start
1211 Distance Angle P.System Data 2
Dis. General
30 .. 90 ° 85 ° Angle of inclination,
distance charact.
1215 Paral.Line Comp Dis. General NO
YES
YES Mutual coupling
parall.line compensation
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 537
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1220 PHASE PREF.2phe Dis. General L3 (L1) ACYCLIC
L1 (L3) ACYCLIC
L2 (L1) ACYCLIC
L1 (L2) ACYCLIC
L3 (L2) ACYCLIC
L2 (L3) ACYCLIC
L3 (L1) CYCLIC
L1 (L3) CYCLIC
All loops
L3 (L1) ACYCLIC Phase preference for 2ph-
e faults
1221A 2Ph-E faults Dis. General Block leading Ø
Block lagging Ø
All loops
Ø-Ø loops only
Ø-E loops only
Block leading Ø Loop selection with 2Ph-E
faults
1223 Uph-ph unbal. Dis. General 5 .. 50 % 25 % Max Uph-ph unbal. for
1ph Flt. detection
1232 SOTF zone Dis. General PICKUP
Zone Z1B
Z1B undirect.
Zone Z1
Z1 undirect.
Inactive
Inactive Instantaneous trip after
SwitchOnToFault
1241 R load (Ø-E) Dis. General 1A 0.100 .. 600.000 Ω;
∞
∞ Ω R load, minimum Load
Impedance (ph-e)
5A 0.020 .. 120.000 Ω;
∞
∞ Ω
1242 φ load (Ø-E) Dis. General 20 .. 60 ° 45 ° PHI load, maximum Load
Angle (ph-e)
1243 R load (Ø-Ø) Dis. General 1A 0.100 .. 600.000 Ω;
∞
∞ Ω R load, minimum Load
Impedance (ph-ph)
5A 0.020 .. 120.000 Ω;
∞
∞ Ω
1244 φ load (Ø-Ø) Dis. General 20 .. 60 ° 45 ° PHI load, maximum Load
Angle (ph-ph)
1301 Op. mode Z1 Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Forward Operating mode Z1
1302 R(Z1) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 1.250 Ω R(Z1), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 0.250 Ω
1303 X(Z1) Dis. Quadril. 1A 0.050 .. 600.000 Ω 2.500 Ω X(Z1), Reactance
5A 0.010 .. 120.000 Ω 0.500 Ω
1304 RE(Z1) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 2.500 Ω RE(Z1), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 0.500 Ω
1305 T1-1phase Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.00 sec T1-1phase, delay for
single phase faults
Functions, Settings, Information
E.2 Settings
538 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1306 T1-multi-phase Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.00 sec T1multi-ph, delay for
multi phase faults
1307 Zone Reduction Dis. Quadril. 0 .. 45 ° 0 ° Zone Reduction Angle
(load compensation)
1308 Iph>(Z1) Dis. Quadril.
Dis. MHO
1A 0.05 .. 20.00 A 0.20 A Minimum current for Z1
only Iph>(Z1)
5A 0.25 .. 100.00 A 1.00 A
1311 Op. mode Z2 Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Forward Operating mode Z2
1312 R(Z2) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 2.500 Ω R(Z2), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 0.500 Ω
1313 X(Z2) Dis. Quadril. 1A 0.050 .. 600.000 Ω 5.000 Ω X(Z2), Reactance
5A 0.010 .. 120.000 Ω 1.000 Ω
1314 RE(Z2) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 5.000 Ω RE(Z2), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 1.000 Ω
1315 T2-1phase Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.30 sec T2-1phase, delay for
single phase faults
1316 T2-multi-phase Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.30 sec T2multi-ph, delay for
multi phase faults
1317A Trip 1pole Z2 Dis. General
Dis. Quadril.
Dis. MHO
NO
YES
NO Single pole trip for faults
in Z2
1321 Op. mode Z3 Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Reverse Operating mode Z3
1322 R(Z3) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 5.000 Ω R(Z3), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 1.000 Ω
1323 X(Z3) Dis. Quadril. 1A 0.050 .. 600.000 Ω 10.000 Ω X(Z3), Reactance
5A 0.010 .. 120.000 Ω 2.000 Ω
1324 RE(Z3) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 10.000 Ω RE(Z3), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 2.000 Ω
1325 T3 DELAY Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.60 sec T3 delay
1331 Op. mode Z4 Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Non-Directional Operating mode Z4
1332 R(Z4) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 12.000 Ω R(Z4), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1333 X(Z4) Dis. Quadril. 1A 0.050 .. 600.000 Ω 12.000 Ω X(Z4), Reactance
5A 0.010 .. 120.000 Ω 2.400 Ω
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 539
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1334 RE(Z4) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 12.000 Ω RE(Z4), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1335 T4 DELAY Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.90 sec T4 delay
1341 Op. mode Z5 Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode Z5
1342 R(Z5) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 12.000 Ω R(Z5), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1343 X(Z5)+ Dis. Quadril. 1A 0.050 .. 600.000 Ω 12.000 Ω X(Z5)+, Reactance for
Forward direction
5A 0.010 .. 120.000 Ω 2.400 Ω
1344 RE(Z5) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 12.000 Ω RE(Z5), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 2.400 Ω
1345 T5 DELAY Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.90 sec T5 delay
1346 X(Z5)- Dis. Quadril. 1A 0.050 .. 600.000 Ω 4.000 Ω X(Z5)-, Reactance for
Reverse direction
5A 0.010 .. 120.000 Ω 0.800 Ω
1351 Op. mode Z1B Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Forward Operating mode Z1B
(overrreach zone)
1352 R(Z1B) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 1.500 Ω R(Z1B), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 0.300 Ω
1353 X(Z1B) Dis. Quadril. 1A 0.050 .. 600.000 Ω 3.000 Ω X(Z1B), Reactance
5A 0.010 .. 120.000 Ω 0.600 Ω
1354 RE(Z1B) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 3.000 Ω RE(Z1B), Resistance for
ph-e faults
5A 0.010 .. 120.000 Ω 0.600 Ω
1355 T1B-1phase Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.00 sec T1B-1phase, delay for
single ph. faults
1356 T1B-multi-phase Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 0.00 sec T1B-multi-ph, delay for
multi ph. faults
1357 1st AR -> Z1B Dis. General
Dis. Quadril.
Dis. MHO
NO
YES
YES Z1B enabled before 1st
AR (int. or ext.)
1361 Op. mode Z6 Dis. Quadril. Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode Z6
1362 R(Z6) Ø-Ø Dis. Quadril. 1A 0.050 .. 600.000 Ω 15.000 Ω R(Z6), Resistance for ph-
ph-faults
5A 0.010 .. 120.000 Ω 3.000 Ω
1363 X(Z6)+ Dis. Quadril. 1A 0.050 .. 600.000 Ω 15.000 Ω X(Z6)+, Reactance for
Forward direction
5A 0.010 .. 120.000 Ω 3.000 Ω
Functions, Settings, Information
E.2 Settings
540 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1364 RE(Z6) Ø-E Dis. Quadril. 1A 0.050 .. 600.000 Ω 15.000 Ω RE(Z6), Resistance for ph-
e faults
5A 0.010 .. 120.000 Ω 3.000 Ω
1365 T6 DELAY Dis. General
Dis. Quadril.
Dis. MHO
0.00 .. 30.00 sec; ∞ 1.50 sec T6 delay
1366 X(Z6)- Dis. Quadril. 1A 0.050 .. 600.000 Ω 4.000 Ω X(Z6)-, Reactance for
Reverse direction
5A 0.010 .. 120.000 Ω 0.800 Ω
1401 Op. mode Z1 Dis. MHO Forward
Reverse
Inactive
Forward Operating mode Z1
1402 ZR(Z1) Dis. MHO 1A 0.050 .. 200.000 Ω 2.500 Ω ZR(Z1), Impedance Reach
5A 0.010 .. 40.000 Ω 0.500 Ω
1411 Op. mode Z2 Dis. MHO Forward
Reverse
Inactive
Forward Operating mode Z2
1412 ZR(Z2) Dis. MHO 1A 0.050 .. 200.000 Ω 5.000 Ω ZR(Z2), Impedance Reach
5A 0.010 .. 40.000 Ω 1.000 Ω
1421 Op. mode Z3 Dis. MHO Forward
Reverse
Inactive
Reverse Operating mode Z3
1422 ZR(Z3) Dis. MHO 1A 0.050 .. 200.000 Ω 5.000 Ω ZR(Z3), Impedance Reach
5A 0.010 .. 40.000 Ω 1.000 Ω
1431 Op. mode Z4 Dis. MHO Forward
Reverse
Inactive
Forward Operating mode Z4
1432 ZR(Z4) Dis. MHO 1A 0.050 .. 200.000 Ω 10.000 Ω ZR(Z4), Impedance Reach
5A 0.010 .. 40.000 Ω 2.000 Ω
1441 Op. mode Z5 Dis. MHO Forward
Reverse
Inactive
Inactive Operating mode Z5
1442 ZR(Z5) Dis. MHO 1A 0.050 .. 200.000 Ω 10.000 Ω ZR(Z5), Impedance Reach
5A 0.010 .. 40.000 Ω 2.000 Ω
1451 Op. mode Z1B Dis. MHO Forward
Reverse
Inactive
Forward Operating mode Z1B
(extended zone)
1452 ZR(Z1B) Dis. MHO 1A 0.050 .. 200.000 Ω 3.000 Ω ZR(Z1B), Impedance
Reach
5A 0.010 .. 40.000 Ω 0.600 Ω
1461 Op. mode Z6 Dis. MHO Forward
Reverse
Inactive
Inactive Operating mode Z6
1462 ZR(Z6) Dis. MHO 1A 0.050 .. 200.000 Ω 15.000 Ω ZR(Z6), Impedance Reach
5A 0.010 .. 40.000 Ω 3.000 Ω
1471A Mem.Polariz.PhE Dis. MHO 0.0 .. 100.0 % 15.0 % Voltage Memory polariza-
tion (phase-e)
1472A CrossPolarizPhE Dis. MHO 0.0 .. 100.0 % 15.0 % Cross polarization (phase-
e)
1473A Mem.Polariz.P-P Dis. MHO 0.0 .. 100.0 % 15.0 % Voltage Memory polariza-
tion (ph-ph)
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 541
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
1474A CrossPolarizP-P Dis. MHO 0.0 .. 100.0 % 15.0 % Cross polarization (phase-
phase)
2002 P/S Op. mode Power Swing All zones block
Z1/Z1B block
>= Z2 block
Z1,Z1B,Z2 block
All zones block Power Swing Operating
mode
2006 PowerSwing trip Power Swing NO
YES
NO Power swing trip
2101 FCT Telep. Dis. Teleprot. Dist. ON
PUTT (Z1B)
POTT
OFF
ON Teleprotection for
Distance protection
2102 Type of Line Teleprot. Dist. Two Terminals
Three terminals
Two Terminals Type of Line
2103A Send Prolong. Teleprot. Dist. 0.00 .. 30.00 sec 0.05 sec Time for send signal
prolongation
2107A Delay for alarm Teleprot. Dist. 0.00 .. 30.00 sec 10.00 sec Time Delay for Alarm
2108 Release Delay Teleprot. Dist. 0.000 .. 30.000 sec 0.000 sec Time Delay for release
after pickup
2109A TrBlk Wait Time Teleprot. Dist. 0.00 .. 30.00 sec; ∞ 0.04 sec Transient Block.: Duration
external flt.
2110A TrBlk BlockTime Teleprot. Dist. 0.00 .. 30.00 sec 0.05 sec Transient Block.: Blk.T.
after ext. flt.
2112A DIS TRANSBLK EF Teleprot. Dist. YES
NO
YES DIS transient block by EF
2113 Mem.rec.sig. Teleprot. Dist. YES
NO
NO Memorize receive signal
2201 FCT Direct Trip DTT Direct Trip ON
OFF
OFF Direct Transfer Trip (DTT)
2202 Trip Time DELAY DTT Direct Trip 0.00 .. 30.00 sec; ∞ 0.01 sec Trip Time Delay
2401 FCT SOTF-O/C SOTF Overcurr. ON
OFF
ON Inst. High Speed SOTF-
O/C is
2404 I>>> SOTF Overcurr. 1A 0.10 .. 25.00 A 2.50 A I>>> Pickup
5A 0.50 .. 125.00 A 12.50 A
2501 FCT Weak Infeed Weak Infeed OFF
ECHO only
ECHO and TRIP
Echo &Trip(I=0)
ECHO only Weak Infeed function
2502A Trip/Echo DELAY Weak Infeed 0.00 .. 30.00 sec 0.04 sec Trip / Echo Delay after
carrier receipt
2503A Trip EXTENSION Weak Infeed 0.00 .. 30.00 sec 0.05 sec Trip Extension / Echo
Impulse time
2504A Echo BLOCK Time Weak Infeed 0.00 .. 30.00 sec 0.05 sec Echo Block Time
2505 UNDERVOLTAGE Weak Infeed 2 .. 175 V 25 V Undervoltage (ph-e)
2509 Echo:1channel Weak Infeed NO
YES
NO Echo logic: Dis and EF on
common channel
2510 Uphe< Factor Weak Infeed 0.10 .. 1.00 0.70 Factor for undervoltage
Uphe<
2511 Time const. τ Weak Infeed 1 .. 60 sec 5 sec Time constant Tau
Functions, Settings, Information
E.2 Settings
542 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
2512A Rec. Ext. Weak Infeed 0.00 .. 30.00 sec 0.65 sec Reception extension
2513A T 3I0> Ext. Weak Infeed 0.00 .. 30.00 sec 0.60 sec 3I0> exceeded extension
2514 3I0> Threshold Weak Infeed 1A 0.05 .. 1.00 A 0.50 A 3I0 threshold for neutral
current pickup
5A 0.25 .. 5.00 A 2.50 A
2515 TM Weak Infeed 0.00 .. 30.00 sec 0.40 sec WI delay single pole
2516 TT Weak Infeed 0.00 .. 30.00 sec 1.00 sec WI delay multi pole
2517 1pol. Trip Weak Infeed ON
OFF
ON Single pole WI trip
allowed
2518 1pol. with 3I0 Weak Infeed ON
OFF
ON Single pole WI trip with
3I0
2519 3pol. Trip Weak Infeed ON
OFF
ON Three pole WI trip
allowed
2520 T 3I0> alarm Weak Infeed 0.00 .. 30.00 sec 10.00 sec 3I0> exceeded delay for
alarm
2530 WI non delayed Weak Infeed ON
OFF
ON WI non delayed
2531 WI delayed Weak Infeed ON
by receive fail
OFF
by receive fail WI delayed
2601 Operating Mode Back-Up O/C ON:with VT loss
ON:always activ
OFF
ON:with VT loss Operating mode
2610 Iph>> Back-Up O/C 1A 0.05 .. 50.00 A; ∞ 2.00 A Iph>> Pickup
5A 0.25 .. 250.00 A; ∞ 10.00 A
2611 T Iph>> Back-Up O/C 0.00 .. 30.00 sec; ∞ 0.30 sec T Iph>> Time delay
2612 3I0>> PICKUP Back-Up O/C 1A 0.05 .. 25.00 A; ∞ 0.50 A 3I0>> Pickup
5A 0.25 .. 125.00 A; ∞ 2.50 A
2613 T 3I0>> Back-Up O/C 0.00 .. 30.00 sec; ∞ 2.00 sec T 3I0>> Time delay
2614 I>> InstTrip BI Back-Up O/C NO
YES
YES Instantaneous trip via BI
2615 I>> SOTF Back-Up O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
2620 Iph> Back-Up O/C 1A 0.05 .. 50.00 A; ∞ 1.50 A Iph> Pickup
5A 0.25 .. 250.00 A; ∞ 7.50 A
2621 T Iph> Back-Up O/C 0.00 .. 30.00 sec; ∞ 0.50 sec T Iph> Time delay
2622 3I0> Back-Up O/C 1A 0.05 .. 25.00 A; ∞ 0.20 A 3I0> Pickup
5A 0.25 .. 125.00 A; ∞ 1.00 A
2623 T 3I0> Back-Up O/C 0.00 .. 30.00 sec; ∞ 2.00 sec T 3I0> Time delay
2624 I> Telep/BI Back-Up O/C NO
YES
NO Instantaneous trip via
Teleprot./BI
2625 I> SOTF Back-Up O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
2630 Iph> STUB Back-Up O/C 1A 0.05 .. 50.00 A; ∞ 1.50 A Iph> STUB Pickup
5A 0.25 .. 250.00 A; ∞ 7.50 A
2631 T Iph STUB Back-Up O/C 0.00 .. 30.00 sec; ∞ 0.30 sec T Iph STUB Time delay
2632 3I0> STUB Back-Up O/C 1A 0.05 .. 25.00 A; ∞ 0.20 A 3I0> STUB Pickup
5A 0.25 .. 125.00 A; ∞ 1.00 A
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 543
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
2633 T 3I0 STUB Back-Up O/C 0.00 .. 30.00 sec; ∞ 2.00 sec T 3I0 STUB Time delay
2634 I-STUB Telep/BI Back-Up O/C NO
YES
NO Instantaneous trip via
Teleprot./BI
2635 I-STUB SOTF Back-Up O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
2640 Ip> Back-Up O/C 1A 0.10 .. 4.00 A; ∞ ∞ A Ip> Pickup
5A 0.50 .. 20.00 A; ∞ ∞ A
2642 T Ip Time Dial Back-Up O/C 0.05 .. 3.00 sec; ∞ 0.50 sec T Ip Time Dial
2643 Time Dial TD Ip Back-Up O/C 0.50 .. 15.00 ; ∞ 5.00 Time Dial TD Ip
2646 T Ip Add Back-Up O/C 0.00 .. 30.00 sec 0.00 sec T Ip Additional Time Delay
2650 3I0p PICKUP Back-Up O/C 1A 0.05 .. 4.00 A; ∞ ∞ A 3I0p Pickup
5A 0.25 .. 20.00 A; ∞ ∞ A
2652 T 3I0p TimeDial Back-Up O/C 0.05 .. 3.00 sec; ∞ 0.50 sec T 3I0p Time Dial
2653 TimeDial TD3I0p Back-Up O/C 0.50 .. 15.00 ; ∞ 5.00 Time Dial TD 3I0p
2656 T 3I0p Add Back-Up O/C 0.00 .. 30.00 sec 0.00 sec T 3I0p Additional Time
Delay
2660 IEC Curve Back-Up O/C Normal Inverse
Very Inverse
Extremely Inv.
LongTimeInverse
Normal Inverse IEC Curve
2661 ANSI Curve Back-Up O/C Inverse
Short Inverse
Long Inverse
Moderately Inv.
Very Inverse
Extremely Inv.
Definite Inv.
Inverse ANSI Curve
2670 I(3I0)p Tele/BI Back-Up O/C NO
YES
NO Instantaneous trip via
Teleprot./BI
2671 I(3I0)p SOTF Back-Up O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
2680 SOTF Time DELAY Back-Up O/C 0.00 .. 30.00 sec 0.00 sec Trip time delay after SOTF
2801 DMD Interval Demand meter 15 Min., 1 Sub
15 Min., 3 Subs
15 Min.,15 Subs
30 Min., 1 Sub
60 Min., 1 Sub
60 Min., 1 Sub Demand Calculation Inter-
vals
2802 DMD Sync.Time Demand meter On The Hour
15 After Hour
30 After Hour
45 After Hour
On The Hour Demand Synchronization
Time
2811 MinMax cycRESET Min/Max meter NO
YES
YES Automatic Cyclic Reset
Function
2812 MiMa RESET TIME Min/Max meter 0 .. 1439 min 0 min MinMax Reset Timer
2813 MiMa RESETCYCLE Min/Max meter 1 .. 365 Days 7 Days MinMax Reset Cycle
Period
2814 MinMaxRES.START Min/Max meter 1 .. 365 Days 1 Days MinMax Start Reset Cycle
in
Functions, Settings, Information
E.2 Settings
544 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
2901 MEASURE. SUPERV Meas-
urem.Superv
ON
OFF
ON Measurement Supervision
2902A BALANCE U-LIMIT Meas-
urem.Superv
10 .. 100 V 50 V Voltage Threshold for
Balance Monitoring
2903A BAL. FACTOR U Meas-
urem.Superv
0.58 .. 0.95 0.75 Balance Factor for
Voltage Monitor
2904A BALANCE I LIMIT Meas-
urem.Superv
1A 0.10 .. 1.00 A 0.50 A Current Balance Monitor
5A 0.50 .. 5.00 A 2.50 A
2905A BAL. FACTOR I Meas-
urem.Superv
0.10 .. 0.95 0.50 Balance Factor for Current
Monitor
2906A ΣI THRESHOLD Meas-
urem.Superv
1A 0.05 .. 2.00 A 0.10 A Summated Current Moni-
toring Threshold
5A 0.25 .. 10.00 A 0.50 A
2907A ΣI FACTOR Meas-
urem.Superv
0.00 .. 0.95 0.10 Summated Current Moni-
toring Factor
2908A T BAL. U LIMIT Meas-
urem.Superv
5 .. 100 sec 5 sec T Balance Factor for
Voltage Monitor
2909A T BAL. I LIMIT Meas-
urem.Superv
5 .. 100 sec 5 sec T Current Balance
Monitor
2910 FUSE FAIL MON. Meas-
urem.Superv
ON
OFF
ON Fuse Failure Monitor
2911A FFM U>(min) Meas-
urem.Superv
10 .. 100 V 30 V Minimum Voltage
Threshold U>
2912A FFM I< (max) Meas-
urem.Superv
1A 0.05 .. 1.00 A 0.10 A Maximum Current
Threshold I<
5A 0.25 .. 5.00 A 0.50 A
2913A FFM U<max (3ph) Meas-
urem.Superv
2 .. 100 V 15 V Maximum Voltage
Threshold U< (3phase)
2914A FFM Idelta (3p) Meas-
urem.Superv
1A 0.05 .. 1.00 A 0.10 A Delta Current Threshold
(3phase)
5A 0.25 .. 5.00 A 0.50 A
2915 V-Supervision Meas-
urem.Superv
w/ CURR.SUP
w/ I> & CBaux
OFF
w/ CURR.SUP Voltage Failure Supervi-
sion
2916A T V-Supervision Meas-
urem.Superv
0.00 .. 30.00 sec 3.00 sec Delay Voltage Failure
Supervision
2921 T mcb Meas-
urem.Superv
0 .. 30 ms 0 ms VT mcb operating time
2941 φA Meas-
urem.Superv
0 .. 359 ° 200 ° Limit setting PhiA
2942 φB Meas-
urem.Superv
0 .. 359 ° 340 ° Limit setting PhiB
2943 I1> Meas-
urem.Superv
1A 0.05 .. 2.00 A 0.05 A Minimum value I1>
5A 0.25 .. 10.00 A 0.25 A
2944 U1> Meas-
urem.Superv
2 .. 70 V 20 V Minimum value U1>
3101 FCT EarthFltO/C Earth Fault O/C ON
OFF
ON Earth Fault overcurrent
function
3102 BLOCK for Dist. Earth Fault O/C every PICKUP
1phase PICKUP
multiph. PICKUP
NO
every PICKUP Block E/F for Distance
protection
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 545
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3103 BLOCK 1pDeadTim Earth Fault O/C YES
NO
YES Block E/F for 1pole Dead
time
3104A Iph-STAB. Slope Earth Fault O/C 0 .. 30 % 10 % Stabilisation Slope with
Iphase
3105 3IoMin Teleprot Earth Fault O/C 1A 0.01 .. 1.00 A 0.50 A 3Io-Min threshold for
Teleprot. schemes
5A 0.05 .. 5.00 A 2.50 A
3105 3IoMin Teleprot Earth Fault O/C 1A 0.003 .. 1.000 A 0.500 A 3Io-Min threshold for
Teleprot. schemes
5A 0.015 .. 5.000 A 2.500 A
3109 Trip 1pole E/F Earth Fault O/C YES
NO
YES Single pole trip with earth
flt.prot.
3110 Op. mode 3I0>>> Earth Fault O/C Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3111 3I0>>> Earth Fault O/C 1A 0.05 .. 25.00 A 4.00 A 3I0>>> Pickup
5A 0.25 .. 125.00 A 20.00 A
3112 T 3I0>>> Earth Fault O/C 0.00 .. 30.00 sec; ∞ 0.30 sec T 3I0>>> Time delay
3113 3I0>>> Telep/BI Earth Fault O/C NO
YES
NO Instantaneous trip via
Teleprot./BI
3114 3I0>>>SOTF-Trip Earth Fault O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
3115 3I0>>>InrushBlk Earth Fault O/C NO
YES
NO Inrush Blocking
3116 BLK /1p 3I0>>> Earth Fault O/C YES
No (non-dir.)
YES Block 3I0>>> during
1pole dead time
3117 Trip 1p 3I0>>> Earth Fault O/C YES
NO
YES Single pole trip with
3I0>>>
3120 Op. mode 3I0>> Earth Fault O/C Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3121 3I0>> Earth Fault O/C 1A 0.05 .. 25.00 A 2.00 A 3I0>> Pickup
5A 0.25 .. 125.00 A 10.00 A
3122 T 3I0>> Earth Fault O/C 0.00 .. 30.00 sec; ∞ 0.60 sec T 3I0>> Time Delay
3123 3I0>> Telep/BI Earth Fault O/C NO
YES
NO Instantaneous trip via
Teleprot./BI
3124 3I0>> SOTF-Trip Earth Fault O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
3125 3I0>> InrushBlk Earth Fault O/C NO
YES
NO Inrush Blocking
3126 BLK /1p 3I0>> Earth Fault O/C YES
No (non-dir.)
YES Block 3I0>> during 1pole
dead time
3127 Trip 1p 3I0>> Earth Fault O/C YES
NO
YES Single pole trip with
3I0>>
3130 Op. mode 3I0> Earth Fault O/C Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
Functions, Settings, Information
E.2 Settings
546 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3131 3I0> Earth Fault O/C 1A 0.05 .. 25.00 A 1.00 A 3I0> Pickup
5A 0.25 .. 125.00 A 5.00 A
3131 3I0> Earth Fault O/C 1A 0.003 .. 25.000 A 1.000 A 3I0> Pickup
5A 0.015 .. 125.000 A 5.000 A
3132 T 3I0> Earth Fault O/C 0.00 .. 30.00 sec; ∞ 0.90 sec T 3I0> Time Delay
3133 3I0> Telep/BI Earth Fault O/C NO
YES
NO Instantaneous trip via
Teleprot./BI
3134 3I0> SOTF-Trip Earth Fault O/C NO
YES
NO Instantaneous trip after
SwitchOnToFault
3135 3I0> InrushBlk Earth Fault O/C NO
YES
NO Inrush Blocking
3136 BLK /1p 3I0> Earth Fault O/C YES
No (non-dir.)
YES Block 3I0> during 1pole
dead time
3137 Trip 1p 3I0> Earth Fault O/C YES
NO
YES Single pole trip with 3I0>
3140 Op. mode 3I0p Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Forward
Reverse
Non-Directional
Inactive
Inactive Operating mode
3141 3I0p PICKUP Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
1A 0.05 .. 25.00 A 1.00 A 3I0p Pickup
5A 0.25 .. 125.00 A 5.00 A
3141 3I0p PICKUP Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
1A 0.003 .. 25.000 A 1.000 A 3I0p Pickup
5A 0.015 .. 125.000 A 5.000 A
3142 3I0p MinT-DELAY Earth Fault O/C 0.00 .. 30.00 sec 1.20 sec 3I0p Minimum Time
Delay
3143 3I0p Time Dial Earth Fault O/C 0.05 .. 3.00 sec; ∞ 0.50 sec 3I0p Time Dial
3144 3I0p Time Dial Earth Fault O/C 0.50 .. 15.00 ; ∞ 5.00 3I0p Time Dial
3145 3I0p Time Dial Earth Fault O/C 0.05 .. 15.00 sec; ∞ 1.35 sec 3I0p Time Dial
3146 3I0p MaxT-DELAY Earth Fault O/C 0.00 .. 30.00 sec 5.80 sec 3I0p Maximum Time
Delay
3147 Add.T-DELAY Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
0.00 .. 30.00 sec; ∞ 1.20 sec Additional Time Delay
3148 3I0p Telep/BI Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
NO
YES
NO Instantaneous trip via
Teleprot./BI
3149 3I0p SOTF-Trip Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
NO
YES
NO Instantaneous trip after
SwitchOnToFault
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 547
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3150 3I0p InrushBlk Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
NO
YES
NO Inrush Blocking
3151 IEC Curve Earth Fault O/C Normal Inverse
Very Inverse
Extremely Inv.
LongTimeInverse
Normal Inverse IEC Curve
3152 ANSI Curve Earth Fault O/C Inverse
Short Inverse
Long Inverse
Moderately Inv.
Very Inverse
Extremely Inv.
Definite Inv.
Inverse ANSI Curve
3153 LOG Curve Earth Fault O/C Log. inverse Log. inverse LOGARITHMIC Curve
3154 3I0p Startpoint Earth Fault O/C 1.0 .. 4.0 1.1 Start point of inverse
characteristic
3155 k Earth Fault O/C 0.00 .. 3.00 sec 0.50 sec k-factor for Sr-character-
istic
3156 S ref Earth Fault O/C 1A 1 .. 100 VA 10 VA S ref for Sr-characteristic
5A 5 .. 500 VA 50 VA
3157 BLK /1p 3I0p Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
YES
No (non-dir.)
YES Block 3I0p during 1pole
dead time
3158 Trip 1p 3I0p Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
Earth Fault O/C
YES
NO
YES Single pole trip with 3I0p
3160 POLARIZATION Earth Fault O/C U0 + IY or U2
U0 + IY
with IY only
with U2 and I2
zero seq. power
U0 + IY or U2 Polarization
3162A Dir. ALPHA Earth Fault O/C 0 .. 360 ° 338 ° ALPHA, lower angle for
forward direction
3163A Dir. BETA Earth Fault O/C 0 .. 360 ° 122 ° BETA, upper angle for
forward direction
3164 3U0> Earth Fault O/C 0.5 .. 10.0 V 0.5 V Min. zero seq.voltage
3U0 for polarizing
3165 IY> Earth Fault O/C 1A 0.05 .. 1.00 A 0.05 A Min. earth current IY for
polarizing
5A 0.25 .. 5.00 A 0.25 A
3166 3U2> Earth Fault O/C 0.5 .. 10.0 V 0.5 V Min. neg. seq. polarizing
voltage 3U2
3167 3I2> Earth Fault O/C 1A 0.05 .. 1.00 A 0.05 A Min. neg. seq. polarizing
current 3I2
5A 0.25 .. 5.00 A 0.25 A
3168 PHI comp Earth Fault O/C 0 .. 360 ° 255 ° Compensation angle PHI
comp. for Sr
Functions, Settings, Information
E.2 Settings
548 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3169 S forward Earth Fault O/C 1A 0.1 .. 10.0 VA 0.3 VA Forward direction power
threshold
5A 0.5 .. 50.0 VA 1.5 VA
3170 2nd InrushRest Earth Fault O/C 10 .. 45 % 15 % 2nd harmonic ratio for
inrush restraint
3171 Imax InrushRest Earth Fault O/C 1A 0.50 .. 25.00 A 7.50 A Max.Current, overriding
inrush restraint
5A 2.50 .. 125.00 A 37.50 A
3172 SOTF Op. Mode Earth Fault O/C PICKUP
PICKUP+DIRECT.
PICKUP+DIRECT. Instantaneous mode after
SwitchOnToFault
3173 SOTF Time DELAY Earth Fault O/C 0.00 .. 30.00 sec 0.00 sec Trip time delay after SOTF
3174 BLK for DisZone Earth Fault O/C in zone Z1
in zone Z1/Z1B
in each zone
in each zone Block E/F for Distance
Protection Pickup
3182 3U0>(U0 inv) Earth Fault O/C 1.0 .. 10.0 V 5.0 V 3U0> setpoint
3183 U0inv. minimum Earth Fault O/C 0.1 .. 5.0 V 0.2 V Minimum voltage U0min
for T->oo
3184 T forw. (U0inv) Earth Fault O/C 0.00 .. 32.00 sec 0.90 sec T-forward Time delay
(U0inv)
3185 T rev. (U0inv) Earth Fault O/C 0.00 .. 32.00 sec 1.20 sec T-reverse Time delay
(U0inv)
3186A 3U0< forward Earth Fault O/C 0.1 .. 10.0 V; 0 0.0 V 3U0 min for forward
direction
3187A XserCap Earth Fault O/C 1A 0.000 .. 600.000 Ω 0.000 Ω Reactance X of series
capacitor
5A 0.000 .. 120.000 Ω 0.000 Ω
3201 FCT Telep. E/F Teleprot. E/F ON
OFF
ON Teleprotection for Earth
Fault O/C
3202 Line Config. Teleprot. E/F Two Terminals
Three terminals
Two Terminals Line Configuration
3203A Send Prolong. Teleprot. E/F 0.00 .. 30.00 sec 0.05 sec Time for send signal
prolongation
3207A Delay for alarm Teleprot. E/F 0.00 .. 30.00 sec 10.00 sec Unblocking: Time Delay
for Alarm
3208 Release Delay Teleprot. E/F 0.000 .. 30.000 sec 0.000 sec Time Delay for release
after pickup
3209A TrBlk Wait Time Teleprot. E/F 0.00 .. 30.00 sec; ∞ 0.04 sec Transient Block.: Duration
external flt.
3210A TrBlk BlockTime Teleprot. E/F 0.00 .. 30.00 sec 0.05 sec Transient Block.: Blk.T.
after ext. flt.
3212A EF TRANSBLK DIS Teleprot. E/F YES
NO
YES EF transient block by DIS
3401 AUTO RECLOSE Autoreclosure OFF
ON
ON Auto-Reclose function
3402 CB? 1.TRIP Autoreclosure YES
NO
NO CB ready interrogation at
1st trip
3403 T-RECLAIM Autoreclosure 0.50 .. 300.00 sec 3.00 sec Reclaim time after
successful AR cycle
3403 T-RECLAIM Autoreclosure 0.50 .. 300.00 sec;
0
3.00 sec Reclaim time after
successful AR cycle
3404 T-BLOCK MC Autoreclosure 0.50 .. 300.00 sec;
0
1.00 sec AR blocking duration after
manual close
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 549
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3406 EV. FLT. RECOG. Autoreclosure with PICKUP
with TRIP
with TRIP Evolving fault recognition
3407 EV. FLT. MODE Autoreclosure blocks AR
starts 3p AR
starts 3p AR Evolving fault (during the
dead time)
3408 T-Start MONITOR Autoreclosure 0.01 .. 300.00 sec 0.20 sec AR start-signal monitoring
time
3409 CB TIME OUT Autoreclosure 0.01 .. 300.00 sec 3.00 sec Circuit Breaker (CB)
Supervision Time
3410 T RemoteClose Autoreclosure 0.00 .. 300.00 sec;
∞
∞ sec Send delay for remote
close command
3411A T-DEAD EXT. Autoreclosure 0.50 .. 300.00 sec;
∞
∞ sec Maximum dead time
extension
3420 AR w/ DIST. Autoreclosure YES
NO
YES AR with distance protec-
tion
3421 AR w/ SOTF-O/C Autoreclosure YES
NO
YES AR with switch-onto-fault
overcurrent
3422 AR w/ W/I Autoreclosure YES
NO
YES AR with weak infeed trip-
ping
3423 AR w/ EF-O/C Autoreclosure YES
NO
YES AR with earth fault over-
current prot.
3424 AR w/ DTT Autoreclosure YES
NO
YES AR with direct transfer
trip
3425 AR w/ BackUpO/C Autoreclosure YES
NO
YES AR with back-up overcur-
rent
3430 AR TRIP 3pole Autoreclosure
Autoreclosure
YES
NO
YES 3pole TRIP by AR
3431 DLC or RDT Autoreclosure WITHOUT
RDT
DLC
WITHOUT Dead Line Check or
Reduced Dead Time
3433 T-ACTION ADT Autoreclosure 0.01 .. 300.00 sec;
∞
0.20 sec Action time
3434 T-MAX ADT Autoreclosure 0.50 .. 3000.00 sec 5.00 sec Maximum dead time
3435 ADT 1p allowed Autoreclosure YES
NO
NO 1pole TRIP allowed
3436 ADT CB? CLOSE Autoreclosure YES
NO
NO CB ready interrogation
before reclosing
3437 ADT SynRequest Autoreclosure YES
NO
NO Request for synchro-
check after 3pole AR
3438 T U-stable Autoreclosure
Autoreclosure
0.10 .. 30.00 sec 0.10 sec Supervision time for
dead/ live voltage
3440 U-live> Autoreclosure
Autoreclosure
30 .. 90 V 48 V Voltage threshold for live
line or bus
3441 U-dead< Autoreclosure
Autoreclosure
2 .. 70 V 30 V Voltage threshold for
dead line or bus
3450 1.AR: START Autoreclosure YES
NO
YES Start of AR allowed in this
cycle
3451 1.AR: T-ACTION Autoreclosure 0.01 .. 300.00 sec;
∞
0.20 sec Action time
Functions, Settings, Information
E.2 Settings
550 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3453 1.AR Tdead 1Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 1phase
faults
3454 1.AR Tdead 2Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 2phase
faults
3455 1.AR Tdead 3Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3phase
faults
3456 1.AR Tdead1Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 1pole trip
3457 1.AR Tdead3Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3pole trip
3458 1.AR: Tdead EV. Autoreclosure 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving
fault
3459 1.AR: CB? CLOSE Autoreclosure YES
NO
NO CB ready interrogation
before reclosing
3460 1.AR SynRequest Autoreclosure YES
NO
NO Request for synchro-
check after 3pole AR
3461 2.AR: START Autoreclosure YES
NO
NO AR start allowed in this
cycle
3462 2.AR: T-ACTION Autoreclosure 0.01 .. 300.00 sec;
∞
0.20 sec Action time
3464 2.AR Tdead 1Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 1phase
faults
3465 2.AR Tdead 2Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 2phase
faults
3466 2.AR Tdead 3Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3phase
faults
3467 2.AR Tdead1Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
∞ sec Dead time after 1pole trip
3468 2.AR Tdead3Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3pole trip
3469 2.AR: Tdead EV. Autoreclosure 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving
fault
3470 2.AR: CB? CLOSE Autoreclosure YES
NO
NO CB ready interrogation
before reclosing
3471 2.AR SynRequest Autoreclosure YES
NO
NO Request for synchro-
check after 3pole AR
3472 3.AR: START Autoreclosure YES
NO
NO AR start allowed in this
cycle
3473 3.AR: T-ACTION Autoreclosure 0.01 .. 300.00 sec;
∞
0.20 sec Action time
3475 3.AR Tdead 1Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 1phase
faults
3476 3.AR Tdead 2Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 2phase
faults
3477 3.AR Tdead 3Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3phase
faults
3478 3.AR Tdead1Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
∞ sec Dead time after 1pole trip
3479 3.AR Tdead3Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3pole trip
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 551
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3480 3.AR: Tdead EV. Autoreclosure 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving
fault
3481 3.AR: CB? CLOSE Autoreclosure YES
NO
NO CB ready interrogation
before reclosing
3482 3.AR SynRequest Autoreclosure YES
NO
NO Request for synchro-
check after 3pole AR
3483 4.AR: START Autoreclosure YES
NO
NO AR start allowed in this
cycle
3484 4.AR: T-ACTION Autoreclosure 0.01 .. 300.00 sec;
∞
0.20 sec Action time
3486 4.AR Tdead 1Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 1phase
faults
3487 4.AR Tdead 2Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
1.20 sec Dead time after 2phase
faults
3488 4.AR Tdead 3Flt Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3phase
faults
3489 4.AR Tdead1Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
∞ sec Dead time after 1pole trip
3490 4.AR Tdead3Trip Autoreclosure 0.01 .. 1800.00 sec;
∞
0.50 sec Dead time after 3pole trip
3491 4.AR: Tdead EV. Autoreclosure 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving
fault
3492 4.AR: CB? CLOSE Autoreclosure YES
NO
NO CB ready interrogation
before reclosing
3493 4.AR SynRequest Autoreclosure YES
NO
NO Request for synchro-
check after 3pole AR
3501 FCT Synchronism Sync. Check ON
OFF
ON:w/o CloseCmd
ON Synchronism and Voltage
Check function
3502 Dead Volt. Thr. Sync. Check 1 .. 100 V 5 V Voltage threshold dead
line / bus
3503 Live Volt. Thr. Sync. Check 20 .. 125 V 90 V Voltage threshold live
line / bus
3504 Umax Sync. Check 20 .. 140 V 110 V Maximum permissible
voltage
3507 T-SYN. DURATION Sync. Check 0.01 .. 600.00 sec;
∞
1.00 sec Maximum duration of
synchronism-check
3508 T SYNC-STAB Sync. Check 0.00 .. 30.00 sec 0.00 sec Synchronous condition
stability timer
3509 SyncCB Sync. Check (Einstellmöglich-
keiten anwendung-
sabhängig)
none Synchronizable circuit
breaker
3510 Op.mode with AR Sync. Check with T-CB close
w/o T-CB close
w/o T-CB close Operating mode with AR
3511 AR maxVolt.Diff Sync. Check 1.0 .. 60.0 V 2.0 V Maximum voltage differ-
ence
3512 AR maxFreq.Diff Sync. Check 0.03 .. 2.00 Hz 0.10 Hz Maximum frequency
difference
3513 AR maxAngleDiff Sync. Check 2 .. 80 ° 10 ° Maximum angle differ-
ence
Functions, Settings, Information
E.2 Settings
552 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3515A AR SYNC-CHECK Sync. Check YES
NO
YES AR at Usy2>, Usy1>, and
Synchr.
3516 AR Usy1<Usy2> Sync. Check YES
NO
NO AR at Usy1< and Usy2>
3517 AR Usy1>Usy2< Sync. Check YES
NO
NO AR at Usy1> and Usy2<
3518 AR Usy1<Usy2< Sync. Check YES
NO
NO AR at Usy1< and Usy2<
3519 AR OVERRIDE Sync. Check YES
NO
NO Override of any check
before AR
3530 Op.mode with MC Sync. Check with T-CB close
w/o T-CB close
w/o T-CB close Operating mode with
Man.Cl
3531 MC maxVolt.Diff Sync. Check 1.0 .. 60.0 V 2.0 V Maximum voltage differ-
ence
3532 MC maxFreq.Diff Sync. Check 0.03 .. 2.00 Hz 0.10 Hz Maximum frequency
difference
3533 MC maxAngleDiff Sync. Check 2 .. 80 ° 10 ° Maximum angle differ-
ence
3535A MC SYNCHR Sync. Check YES
NO
YES Manual Close at Usy2>,
Usy1>, and Synchr
3536 MC Usy1< Usy2> Sync. Check YES
NO
NO Manual Close at Usy1<
and Usy2>
3537 MC Usy1> Usy2< Sync. Check YES
NO
NO Manual Close at Usy1>
and Usy2<
3538 MC Usy1< Usy2< Sync. Check YES
NO
NO Manual Close at Usy1<
and Usy2<
3539 MC OVERRIDE Sync. Check YES
NO
NO Override of any check
before Man.Cl
3601 O/U FREQ. f1 Frequency Prot. ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency
Protection stage f1
3602 f1 PICKUP Frequency Prot. 45.50 .. 54.50 Hz 49.50 Hz f1 Pickup
3603 f1 PICKUP Frequency Prot. 55.50 .. 64.50 Hz 59.50 Hz f1 Pickup
3604 T f1 Frequency Prot. 0.00 .. 600.00 sec 60.00 sec T f1 Time Delay
3611 O/U FREQ. f2 Frequency Prot. ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency
Protection stage f2
3612 f2 PICKUP Frequency Prot. 45.50 .. 54.50 Hz 49.00 Hz f2 Pickup
3613 f2 PICKUP Frequency Prot. 55.50 .. 64.50 Hz 57.00 Hz f2 Pickup
3614 T f2 Frequency Prot. 0.00 .. 600.00 sec 30.00 sec T f2 Time Delay
3621 O/U FREQ. f3 Frequency Prot. ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency
Protection stage f3
3622 f3 PICKUP Frequency Prot. 45.50 .. 54.50 Hz 47.50 Hz f3 Pickup
3623 f3 PICKUP Frequency Prot. 55.50 .. 64.50 Hz 59.50 Hz f3 Pickup
3624 T f3 Frequency Prot. 0.00 .. 600.00 sec 3.00 sec T f3 Time Delay
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 553
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3631 O/U FREQ. f4 Frequency Prot. ON: Alarm only
ON: with Trip
OFF
ON: Alarm only Over/Under Frequency
Protection stage f4
3632 f4 PICKUP Frequency Prot. 45.50 .. 54.50 Hz 51.00 Hz f4 Pickup
3633 f4 PICKUP Frequency Prot. 55.50 .. 64.50 Hz 62.00 Hz f4 Pickup
3634 T f4 Frequency Prot. 0.00 .. 600.00 sec 30.00 sec T f4 Time Delay
3701 Uph-e>(>) Voltage Prot. OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode Uph-e
overvoltage prot.
3702 Uph-e> Voltage Prot. 1.0 .. 170.0 V; ∞ 85.0 V Uph-e> Pickup
3703 T Uph-e> Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T Uph-e> Time Delay
3704 Uph-e>> Voltage Prot. 1.0 .. 170.0 V; ∞ 100.0 V Uph-e>> Pickup
3705 T Uph-e>> Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T Uph-e>> Time Delay
3709A Uph-e>(>) RESET Voltage Prot. 0.30 .. 0.99 0.98 Uph-e>(>) Reset ratio
3711 Uph-ph>(>) Voltage Prot. OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode Uph-ph
overvoltage prot.
3712 Uph-ph> Voltage Prot. 2.0 .. 220.0 V; ∞ 150.0 V Uph-ph> Pickup
3713 T Uph-ph> Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T Uph-ph> Time Delay
3714 Uph-ph>> Voltage Prot. 2.0 .. 220.0 V; ∞ 175.0 V Uph-ph>> Pickup
3715 T Uph-ph>> Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T Uph-ph>> Time Delay
3719A Uphph>(>) RESET Voltage Prot. 0.30 .. 0.99 0.98 Uph-ph>(>) Reset ratio
3721 3U0>(>) (or Ux) Voltage Prot. OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode 3U0 (or
Ux) overvoltage
3722 3U0> Voltage Prot. 1.0 .. 220.0 V; ∞ 30.0 V 3U0> Pickup (or Ux>)
3723 T 3U0> Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T 3U0> Time Delay (or T
Ux>)
3724 3U0>> Voltage Prot. 1.0 .. 220.0 V; ∞ 50.0 V 3U0>> Pickup (or Ux>>)
3725 T 3U0>> Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T 3U0>> Time Delay (or T
Ux>>)
3728A 3U0>(>) Stabil. Voltage Prot. ON
OFF
ON 3U0>(>): Stabilization
3U0-Measurement
3729A 3U0>(>) RESET Voltage Prot. 0.30 .. 0.99 0.95 3U0>(>) Reset ratio (or
Ux)
3731 U1>(>) Voltage Prot. OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode U1 over-
voltage prot.
3732 U1> Voltage Prot. 2.0 .. 220.0 V; ∞ 150.0 V U1> Pickup
3733 T U1> Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T U1> Time Delay
Functions, Settings, Information
E.2 Settings
554 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3734 U1>> Voltage Prot. 2.0 .. 220.0 V; ∞ 175.0 V U1>> Pickup
3735 T U1>> Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T U1>> Time Delay
3736 U1> Compound Voltage Prot. OFF
ON
OFF U1> with Compounding
3737 U1>> Compound Voltage Prot. OFF
ON
OFF U1>> with Compounding
3739A U1>(>) RESET Voltage Prot. 0.30 .. 0.99 0.98 U1>(>) Reset ratio
3741 U2>(>) Voltage Prot. OFF
Alarm Only
ON
U>Alarm U>>Trip
OFF Operating mode U2 over-
voltage prot.
3742 U2> Voltage Prot. 2.0 .. 220.0 V; ∞ 30.0 V U2> Pickup
3743 T U2> Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T U2> Time Delay
3744 U2>> Voltage Prot. 2.0 .. 220.0 V; ∞ 50.0 V U2>> Pickup
3745 T U2>> Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T U2>> Time Delay
3749A U2>(>) RESET Voltage Prot. 0.30 .. 0.99 0.98 U2>(>) Reset ratio
3751 Uph-e<(<) Voltage Prot. OFF
Alarm Only
ON
U<Alarm U<<Trip
OFF Operating mode Uph-e
undervoltage prot.
3752 Uph-e< Voltage Prot. 1.0 .. 100.0 V; 0 30.0 V Uph-e< Pickup
3753 T Uph-e< Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T Uph-e< Time Delay
3754 Uph-e<< Voltage Prot. 1.0 .. 100.0 V; 0 10.0 V Uph-e<< Pickup
3755 T Uph-e<< Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T Uph-e<< Time Delay
3758 CURR.SUP. Uphe< Voltage Prot. ON
OFF
ON Current supervision (Uph-
e)
3759A Uph-e<(<) RESET Voltage Prot. 1.01 .. 1.20 1.05 Uph-e<(<) Reset ratio
3761 Uph-ph<(<) Voltage Prot. OFF
Alarm Only
ON
U<Alarm U<<Trip
OFF Operating mode Uph-ph
undervoltage prot.
3762 Uph-ph< Voltage Prot. 1.0 .. 175.0 V; 0 50.0 V Uph-ph< Pickup
3763 T Uph-ph< Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T Uph-ph< Time Delay
3764 Uph-ph<< Voltage Prot. 1.0 .. 175.0 V; 0 17.0 V Uph-ph<< Pickup
3765 T Uphph<< Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T Uph-ph<< Time Delay
3768 CURR.SUP.Uphph< Voltage Prot. ON
OFF
ON Current supervision (Uph-
ph)
3769A Uphph<(<) RESET Voltage Prot. 1.01 .. 1.20 1.05 Uph-ph<(<) Reset ratio
3771 U1<(<) Voltage Prot. OFF
Alarm Only
ON
U<Alarm U<<Trip
OFF Operating mode U1
undervoltage prot.
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 555
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
3772 U1< Voltage Prot. 1.0 .. 100.0 V; 0 30.0 V U1< Pickup
3773 T U1< Voltage Prot. 0.00 .. 100.00 sec;
∞
2.00 sec T U1< Time Delay
3774 U1<< Voltage Prot. 1.0 .. 100.0 V; 0 10.0 V U1<< Pickup
3775 T U1<< Voltage Prot. 0.00 .. 100.00 sec;
∞
1.00 sec T U1<< Time Delay
3778 CURR.SUP.U1< Voltage Prot. ON
OFF
ON Current supervision (U1)
3779A U1<(<) RESET Voltage Prot. 1.01 .. 1.20 1.05 U1<(<) Reset ratio
3802 START Fault Locator Pickup
TRIP
Pickup Start fault locator with
3805 Paral.Line Comp Fault Locator NO
YES
YES Mutual coupling
parall.line compensation
3806 Load Compensat. Fault Locator NO
YES
NO Load Compensation
3811 Tmax OUTPUT BCD Fault Locator 0.10 .. 180.00 sec 0.30 sec Maximum output time via
BCD
3901 FCT BreakerFail Breaker Failure ON
OFF
ON Breaker Failure Protection
3902 I> BF Breaker Failure 1A 0.05 .. 20.00 A 0.10 A Pick-up threshold I>
5A 0.25 .. 100.00 A 0.50 A
3903 1p-RETRIP (T1) Breaker Failure NO
YES
YES 1pole retrip with stage T1
(local trip)
3904 T1-1pole Breaker Failure 0.00 .. 30.00 sec; ∞ 0.00 sec T1, Delay after 1pole start
(local trip)
3905 T1-3pole Breaker Failure 0.00 .. 30.00 sec; ∞ 0.00 sec T1, Delay after 3pole start
(local trip)
3906 T2 Breaker Failure 0.00 .. 30.00 sec; ∞ 0.15 sec T2, Delay of 2nd stage
(busbar trip)
3907 T3-BkrDefective Breaker Failure 0.00 .. 30.00 sec; ∞ 0.00 sec T3, Delay for start with
defective bkr.
3908 Trip BkrDefect. Breaker Failure NO
with T1-trip
with T2-trip
w/ T1/T2-trip
NO Trip output selection with
defective bkr
3909 Chk BRK CONTACT Breaker Failure NO
YES
YES Check Breaker contacts
3912 3I0> BF Breaker Failure 1A 0.05 .. 20.00 A 0.10 A Pick-up threshold 3I0>
5A 0.25 .. 100.00 A 0.50 A
3913 T2StartCriteria Breaker Failure With exp. of T1
Parallel withT1
Parallel withT1 T2 Start Criteria
3921 End Flt. stage Breaker Failure ON
OFF
OFF End fault protection
3922 T-EndFault Breaker Failure 0.00 .. 30.00 sec; ∞ 2.00 sec Trip delay of end fault
protection
3931 PoleDiscrepancy Breaker Failure ON
OFF
OFF Pole Discrepancy supervi-
sion
3932 T-PoleDiscrep. Breaker Failure 0.00 .. 30.00 sec; ∞ 2.00 sec Trip delay with pole
discrepancy
Functions, Settings, Information
E.2 Settings
556 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Addr. Parameter Function C Setting Options Default Setting Comments
4001 FCT TripSuperv. TripCirc.Superv ON
OFF
OFF TRIP Circuit Supervision is
4002 No. of BI TripCirc.Superv 1 .. 2 2 Number of Binary Inputs
per trip circuit
4003 Alarm Delay TripCirc.Superv 1 .. 30 sec 2 sec Delay Time for alarm
4501 STATE PROT I 1 Prot. Interface ON
OFF
ON State of protection inter-
face 1
4502 CONNEC. 1 OVER Prot. Interface F.optic direct
Com c 64 kBit/s
Com c 128kBit/s
Com c 512kBit/s
C37.94 1 slot
C37.94 2 slots
C37.94 4 slots
C37.94 8 slots
F.optic direct Connection 1 over
4505A PROT 1 T-DELAY Prot. Interface 0.1 .. 30.0 ms 30.0 ms Prot 1: Maximal permis-
sible delay time
4509 T-DATA DISTURB Prot. Interface 0.05 .. 2.00 sec 0.10 sec Time delay for data
disturbance alarm
4510 T-DATAFAIL Prot. Interface 0.0 .. 60.0 sec 6.0 sec Time del for transmission
failure alarm
4511 Td ResetRemote Prot. Interface 0.00 .. 300.00 sec;
∞
0.00 sec Remote signal RESET
DELAY for comm.fail
4601 STATE PROT I 2 Prot. Interface ON
OFF
ON State of protection inter-
face 2
4602 CONNEC. 2 OVER Prot. Interface F.optic direct
Com c 64 kBit/s
Com c 128kBit/s
Com c 512kBit/s
C37.94 1 slot
C37.94 2 slots
C37.94 4 slots
C37.94 8 slots
F.optic direct Connection 2 over
4605A PROT 2 T-DELAY Prot. Interface 0.1 .. 30.0 ms 30.0 ms Prot 2: Maximal permis-
sible delay time
4701 ID OF RELAY 1 Prot. Interface 1 .. 65534 1 Identification number of
relay 1
4702 ID OF RELAY 2 Prot. Interface 1 .. 65534 2 Identification number of
relay 2
4703 ID OF RELAY 3 Prot. Interface 1 .. 65534 3 Identification number of
relay 3
4710 LOCAL RELAY Prot. Interface relay 1
relay 2
relay 3
relay 1 Local relay is
Functions, Settings, Information
E.2 Settings
SIPROTEC 4, 7SA522, Manual 557
C53000-G1176-C155-9, Edition 05.2016
Information List
Indications for IEC 60 870-5-103 are always reported ON / OFF if they are subject to general interrogation for
IEC 60 870-5-103. If not, they are reported only as ON.
New user-defined indications or such newly allocated to IEC 60 870-5-103 are set to ON / OFF and subjected
to general interrogation if the information type is not a spontaneous event (“.._Ev”“). Further information on
indications can be found in detail in the SIPROTEC 4 System Description, Order No. E50417-H1176-C151.
In columns “Event Log”, “Trip Log” and “Ground Fault Log” the following applies:
UPPER CASE NOTATION “ON/OFF”: definitely set, not allocatable
lower case notation “on/off”: preset, allocatable
*: not preset, allocatable
<blank>: neither preset nor allocatable
In the column “Marked in Oscill. Record” the following applies:
UPPER CASE NOTATION “M”: definitely set, not allocatable
lower case notation “m”: preset, allocatable
*: not preset, allocatable
<blank>: neither preset nor allocatable
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
- Test mode (Test mode) Device IntS
P
O
N
OF
F
* * LED BO 12
8
21 1 Yes
- Stop data transmission
(DataStop)
Device IntS
P
O
N
OF
F
* * LED BO 12
8
20 1 Yes
- Reset LED (Reset LED) Device IntS
P
O
N
* * LED BO 12
8
19 1 No
- Clock Synchronization
(SynchClock)
Device IntS
P_E
v
* * * LED BO
- >Back Light on (>Light
on)
Device SP O
N
OF
F
* * BI
- Hardware Test Mode
(HWTestMod)
Device IntS
P
O
N
OF
F
* * LED BO
- Error FMS FO 1 (Error
FMS1)
Device OUT O
N
OF
F
* * * LED BO
E.3
Functions, Settings, Information
E.3 Information List
558 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
- Error FMS FO 2 (Error
FMS2)
Device OUT O
N
OF
F
* * * LED BO
- Disturbance CFC
(Distur.CFC)
Device OUT On
Of
f
* LED BO
- Breaker OPENED (Brk
OPENED)
Device IntS
P
* * * LED BO
- Feeder EARTHED
(FdrEARTHED)
Device IntS
P
* * * LED BO
- Setting Group A is active
(P-GrpA act)
Change
Group
IntS
P
O
N
OF
F
* * LED BO 12
8
23 1 Yes
- Setting Group B is active
(P-GrpB act)
Change
Group
IntS
P
O
N
OF
F
* * LED BO 12
8
24 1 Yes
- Setting Group C is active
(P-GrpC act)
Change
Group
IntS
P
O
N
OF
F
* * LED BO 12
8
25 1 Yes
- Setting Group D is active
(P-GrpD act)
Change
Group
IntS
P
O
N
OF
F
* * LED BO 12
8
26 1 Yes
- Fault Recording Start
(FltRecSta)
Osc. Fault
Rec.
IntS
P
On
Of
f
* m LED BO
- Reset Minimum and
Maximum counter
(ResMinMax)
Min/Max
meter
IntS
P_E
v
O
N
*
- CB1-TEST trip/close - Only
L1 (CB1tst L1)
Testing - * *
- CB1-TEST trip/close - Only
L2 (CB1tst L2)
Testing - * *
- CB1-TEST trip/close - Only
L3 (CB1tst L3)
Testing - * *
- CB1-TEST trip/close
Phases L123 (CB1tst 123)
Testing - * *
- Controlmode REMOTE
(ModeREMOTE)
Cntrl
Authority
IntS
P
On
Of
f
* LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 559
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
- Control Authority (Cntrl
Auth)
Cntrl
Authority
IntS
P
On
Of
f
* LED BO 10
1
85 1 Yes
- Controlmode LOCAL
(ModeLOCAL)
Cntrl
Authority
IntS
P
On
Of
f
* LED BO 10
1
86 1 Yes
- Breaker (Breaker) Control
Device
CF_
D12
On
Of
f
* BO 24
0
16
0
20
- Breaker (Breaker) Control
Device
DP On
Of
f
* BI CB 24
0
16
0
1 Yes
- Disconnect Switch
(Disc.Swit.)
Control
Device
CF_
D2
On
Of
f
* BO 24
0
16
1
20
- Disconnect Switch
(Disc.Swit.)
Control
Device
DP On
Of
f
* BI CB 24
0
16
1
1 Yes
- Earth Switch (EarthSwit) Control
Device
CF_
D2
On
Of
f
* BO 24
0
16
4
20
- Earth Switch (EarthSwit) Control
Device
DP On
Of
f
* BI CB 24
0
16
4
1 Yes
- Interlocking: Breaker
Open (Brk Open)
Control
Device
IntS
P
* * *
- Interlocking: Breaker
Close (Brk Close)
Control
Device
IntS
P
* * *
- Interlocking: Disconnect
switch Open (Disc.Open)
Control
Device
IntS
P
* * *
- Interlocking: Disconnect
switch Close (Disc.Close)
Control
Device
IntS
P
* * *
- Interlocking: Earth switch
Open (E Sw Open)
Control
Device
IntS
P
* * *
- Interlocking: Earth switch
Close (E Sw Cl.)
Control
Device
IntS
P
* * *
- Q2 Open/Close (Q2 Op/Cl) Control
Device
CF_
D2
On
Of
f
* BO 24
0
16
2
20
- Q2 Open/Close (Q2 Op/Cl) Control
Device
DP On
Of
f
* BI CB 24
0
16
2
1 Yes
Functions, Settings, Information
E.3 Information List
560 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
- Q9 Open/Close (Q9 Op/Cl) Control
Device
CF_
D2
On
Of
f
* BO 24
0
16
3
20
- Q9 Open/Close (Q9 Op/Cl) Control
Device
DP On
Of
f
* BI CB 24
0
16
3
1 Yes
- Fan ON/OFF (Fan ON/
OFF)
Control
Device
CF_
D2
On
Of
f
* BO 24
0
17
5
20
- Fan ON/OFF (Fan ON/
OFF)
Control
Device
DP On
Of
f
* BI CB 24
0
17
5
1 Yes
- Unlock data transmission
via BI (UnlockDT)
Control
Device
IntS
P
* * *
- >Cabinet door open
(>Door open)
Process
Data
SP On
Of
f
* * LED BI BO CB 10
1
1 1 Yes
- >CB waiting for Spring
charged (>CB wait)
Process
Data
SP On
Of
f
* * LED BI BO CB 10
1
2 1 Yes
- >Error Motor Voltage
(>Err Mot U)
Process
Data
SP On
Of
f
* * LED BI BO CB 24
0
18
1
1 Yes
- >Error Control Voltage
(>ErrCntrlU)
Process
Data
SP On
Of
f
* * LED BI BO CB 24
0
18
2
1 Yes
- >SF6-Loss (>SF6-Loss) Process
Data
SP On
Of
f
* * LED BI BO CB 24
0
18
3
1 Yes
- >Error Meter (>Err Meter) Process
Data
SP On
Of
f
* * LED BI BO CB 24
0
18
4
1 Yes
- >Transformer Tempera-
ture (>Tx Temp.)
Process
Data
SP On
Of
f
* * LED BI BO CB 24
0
18
5
1 Yes
- >Transformer Danger
(>Tx Danger)
Process
Data
SP On
Of
f
* * LED BI BO CB 24
0
18
6
1 Yes
- Reset meter (Meter res) Energy IntS
P_E
v
O
N
*
- Error Systeminterface
(SysIntErr.)
Protocol IntS
P
On
Of
f
* LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 561
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
- Threshold Value 1
(ThreshVal1)
Thresh.-
Switch
IntS
P
O
N
OF
F
* * LED BI FK
TO
NL
IN
E
BO CB
1 No Function configured
(Not configured)
Device SP
2 Function Not Available
(Non Existent)
Device SP
3 >Synchronize Internal
Real Time Clock (>Time
Synch)
Device SP * * * LED BI BO
4 >Trigger Waveform
Capture
(>Trig.Wave.Cap.)
Osc. Fault
Rec.
SP On * m LED BI BO
5 >Reset LED (>Reset LED) Device SP * * * LED BI BO
7 >Setting Group Select Bit
0 (>Set Group Bit0)
Change
Group
SP * * * LED BI BO
8 >Setting Group Select Bit
1 (>Set Group Bit1)
Change
Group
SP * * * LED BI BO
009.01
00
Failure EN100 Modul
(Failure Modul)
EN100-
Modul 1
IntS
P
On
Of
f
* LED BO
009.01
01
Failure EN100 Link
Channel 1 (Ch1) (Fail
Ch1)
EN100-
Modul 1
IntS
P
On
Of
f
* LED BO
009.01
02
Failure EN100 Link
Channel 2 (Ch2) (Fail
Ch2)
EN100-
Modul 1
IntS
P
On
Of
f
* LED BO
11 >User defined annuncia-
tion 1 (>Annunc. 1)
Device SP * * * * LED BI BO 12
8
27 1 Yes
12 >User defined annuncia-
tion 2 (>Annunc. 2)
Device SP * * * * LED BI BO 12
8
28 1 Yes
13 >User defined annuncia-
tion 3 (>Annunc. 3)
Device SP * * * * LED BI BO 12
8
29 1 Yes
14 >User defined annuncia-
tion 4 (>Annunc. 4)
Device SP * * * * LED BI BO 12
8
30 1 Yes
15 >Test mode (>Test mode) Device SP O
N
OF
F
* * LED BI BO 13
5
53 1 Yes
16 >Stop data transmission
(>DataStop)
Device SP * * * LED BI BO 13
5
54 1 Yes
Functions, Settings, Information
E.3 Information List
562 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
51 Device is Operational and
Protecting (Device OK)
Device OUT O
N
OF
F
* * LED BO 13
5
81 1 Yes
52 At Least 1 Protection
Funct. is Active (ProtAc-
tive)
Device IntS
P
O
N
OF
F
* * LED BO 12
8
18 1 Yes
55 Reset Device (Reset
Device)
Device OUT * * * LED BO 12
8
4 1 No
56 Initial Start of Device
(Initial Start)
Device OUT O
N
* * LED BO 12
8
5 1 No
67 Resume (Resume) Device OUT O
N
* * LED BO 13
5
97 1 No
68 Clock Synchronization
Error (Clock SyncError)
Device OUT On
Of
f
* * LED BO
69 Daylight Saving Time
(DayLightSavTime)
Device OUT O
N
OF
F
* * LED BO
70 Setting calculation is
running (Settings Calc.)
Device OUT O
N
OF
F
* * LED BO 12
8
22 1 Yes
71 Settings Check (Settings
Check)
Device OUT * * * LED BO
72 Level-2 change (Level-2
change)
Device OUT O
N
OF
F
* * LED BO
73 Local setting change
(Local change)
Device OUT * * *
110 Event lost (Event Lost) Device OUT
_Ev
O
N
* * LED BO 13
5
13
0
1 No
113 Flag Lost (Flag Lost) Device OUT O
N
* m LED BO 13
5
13
6
1 Yes
125 Chatter ON (Chatter ON) Device OUT O
N
OF
F
* * LED BO 13
5
14
5
1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 563
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
126 Protection ON/OFF (via
system port) (ProtON/
OFF)
Device IntS
P
O
N
OF
F
* * LED BO
127 Auto Reclose ON/OFF (via
system port) (AR ON/OFF)
Device IntS
P
O
N
OF
F
* * LED BO
128 Teleprot. ON/OFF (via
system port) (Tele-
pONoff)
Device IntS
P
O
N
OF
F
* * LED BO
130 Load angle Phi(PQ Posi-
tive sequence) (φ(PQ Pos.
Seq.))
Meas-
urem.Super
v
OUT * * * LED BO
131 Load angle Phi(PQ)
blocked (φ(PQ Pos) block)
Meas-
urem.Super
v
OUT * * * LED BO
132 Setting error: |PhiA - PhiB|
< 3° (φ Set wrong)
Meas-
urem.Super
v
OUT * * * LED BO
140 Error with a summary
alarm (Error Sum Alarm)
Device OUT O
N
OF
F
* * LED BO 12
8
47 1 Yes
144 Error 5V (Error 5V) Device OUT O
N
OF
F
* * LED BO 13
5
16
4
1 Yes
160 Alarm Summary Event
(Alarm Sum Event)
Device OUT * * * LED BO 12
8
46 1 Yes
161 Failure: General Current
Supervision (Fail I
Superv.)
Meas-
urem.Super
v
OUT * * * LED BO 12
8
32 1 Yes
162 Failure: Current Summa-
tion (Failure Σ I)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
18
2
1 Yes
163 Failure: Current Balance
(Fail I balance)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
18
3
1 Yes
164 Failure: General Voltage
Supervision (Fail U
Superv.)
Meas-
urem.Super
v
OUT * * * LED BO 12
8
33 1 Yes
Functions, Settings, Information
E.3 Information List
564 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
165 Failure: Voltage summa-
tion Phase-Earth (Fail Σ U
Ph-E)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
18
4
1 Yes
167 Failure: Voltage Balance
(Fail U balance)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
18
6
1 Yes
168 Failure: Voltage absent
(Fail U absent)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
18
7
1 Yes
169 VT Fuse Failure (alarm
>10s) (VT FuseFail>10s)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
18
8
1 Yes
170 VT Fuse Failure (alarm
instantaneous) (VT Fuse-
Fail)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO
171 Failure: Phase Sequence
(Fail Ph. Seq.)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 12
8
35 1 Yes
177 Failure: Battery empty
(Fail Battery)
Device OUT O
N
OF
F
* * LED BO 13
5
19
3
1 Yes
181 Error: A/D converter (Error
A/D-conv.)
Device OUT O
N
OF
F
* * LED BO 13
5
17
8
1 Yes
183 Error Board 1 (Error Board
1)
Device OUT O
N
OF
F
* * LED BO 13
5
17
1
1 Yes
184 Error Board 2 (Error Board
2)
Device OUT O
N
OF
F
* * LED BO 13
5
17
2
1 Yes
185 Error Board 3 (Error Board
3)
Device OUT O
N
OF
F
* * LED BO 13
5
17
3
1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 565
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
186 Error Board 4 (Error Board
4)
Device OUT O
N
OF
F
* * LED BO 13
5
17
4
1 Yes
187 Error Board 5 (Error Board
5)
Device OUT O
N
OF
F
* * LED BO 13
5
17
5
1 Yes
188 Error Board 6 (Error Board
6)
Device OUT O
N
OF
F
* * LED BO 13
5
17
6
1 Yes
189 Error Board 7 (Error Board
7)
Device OUT O
N
OF
F
* * LED BO 13
5
17
7
1 Yes
190 Error Board 0 (Error Board
0)
Device OUT O
N
OF
F
* * LED BO 13
5
21
0
1 Yes
191 Error: Offset (Error Offset) Device OUT O
N
OF
F
* * LED BO 13
5
21
1
1 Yes
192 Error:1A/5Ajumper
different from setting
(Error1A/5Awrong)
Device OUT O
N
OF
F
* * LED BO 13
5
16
9
1 Yes
193 Alarm: Analog input
adjustment invalid (Alarm
adjustm.)
Device OUT O
N
OF
F
* * LED BO 13
5
18
1
1 Yes
194 Error: Neutral CT different
from MLFB (Error
neutralCT)
Device OUT O
N
OF
F
* * LED BO 13
5
18
0
1 Yes
195 Failure: Broken Conductor
(Fail Conductor)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
19
5
1 Yes
196 Fuse Fail Monitor is
switched OFF (Fuse Fail
M.OFF)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
19
6
1 Yes
Functions, Settings, Information
E.3 Information List
566 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
197 Measurement Supervision
is switched OFF (MeasSup
OFF)
Meas-
urem.Super
v
OUT O
N
OF
F
* * LED BO 13
5
19
7
1 Yes
234.21
00
U<, U> blocked via opera-
tion (U<, U> blk)
Voltage
Prot.
IntS
P
On
Of
f
* * LED BO
273 Set Point Phase L1 dmd>
(SP. IL1 dmd>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
0
1 Yes
274 Set Point Phase L2 dmd>
(SP. IL2 dmd>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
4
1 Yes
275 Set Point Phase L3 dmd>
(SP. IL3 dmd>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
5
1 Yes
276 Set Point positive
sequence I1dmd> (SP.
I1dmd>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
6
1 Yes
277 Set Point |Pdmd|> (SP. |
Pdmd|>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
7
1 Yes
278 Set Point |Qdmd|> (SP. |
Qdmd|>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
8
1 Yes
279 Set Point |Sdmd|> (SP. |
Sdmd|>)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
23
9
1 Yes
285 Power factor alarm (cosφ
alarm)
Set
Points(MV)
OUT On
Of
f
* * LED BO 13
5
24
5
1 Yes
301 Power System fault
(Pow.Sys.Flt.)
P.System
Data 2
OUT O
N
OF
F
ON * 13
5
23
1
2 Yes
302 Fault Event (Fault Event) P.System
Data 2
OUT * ON * 13
5
23
2
2 No
303 E/Flt.det. in isol/
comp.netw. (E/F Det.)
P.System
Data 2
OUT O
N
OF
F
* ON * 13
5
23
3
1 No
320 Warn: Limit of Memory
Data exceeded (Warn
Mem. Data)
Device OUT On
Of
f
* * LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 567
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
321 Warn: Limit of Memory
Parameter exceeded
(Warn Mem. Para.)
Device OUT On
Of
f
* * LED BO
322 Warn: Limit of Memory
Operation exceeded
(Warn Mem. Oper.)
Device OUT On
Of
f
* * LED BO
323 Warn: Limit of Memory
New exceeded (Warn
Mem. New)
Device OUT On
Of
f
* * LED BO
351 >Circuit breaker aux.
contact: Pole L1 (>CB
Aux. L1)
P.System
Data 2
SP * * * LED BI BO 15
0
1 1 Yes
352 >Circuit breaker aux.
contact: Pole L2 (>CB
Aux. L2)
P.System
Data 2
SP * * * LED BI BO 15
0
2 1 Yes
353 >Circuit breaker aux.
contact: Pole L3 (>CB
Aux. L3)
P.System
Data 2
SP * * * LED BI BO 15
0
3 1 Yes
356 >Manual close signal
(>Manual Close)
P.System
Data 2
SP * * * LED BI BO 15
0
6 1 Yes
357 >Block manual close cmd.
from external (>Blk Man.
Close)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO 15
0
7 1 Yes
361 >Failure: Feeder VT (MCB
tripped) (>FAIL:Feeder
VT)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO 12
8
38 1 Yes
362 >Failure: Usy4 VT (MCB
tripped) (>FAIL:U4 VT)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO 15
0
12 1 Yes
366 >CB1 Pole L1 (for AR,CB-
Test) (>CB1 Pole L1)
P.System
Data 2
SP * * * LED BI BO 15
0
66 1 Yes
367 >CB1 Pole L2 (for AR,CB-
Test) (>CB1 Pole L2)
P.System
Data 2
SP * * * LED BI BO 15
0
67 1 Yes
368 >CB1 Pole L3 (for AR,CB-
Test) (>CB1 Pole L3)
P.System
Data 2
SP * * * LED BI BO 15
0
68 1 Yes
371 >CB1 READY (for AR,CB-
Test) (>CB1 Ready)
P.System
Data 2
SP * * * LED BI BO 15
0
71 1 Yes
378 >CB faulty (>CB faulty) P.System
Data 2
SP * * * LED BI BO
379 >CB aux. contact 3pole
Closed (>CB 3p Closed)
P.System
Data 2
SP * * * LED BI BO 15
0
78 1 Yes
Functions, Settings, Information
E.3 Information List
568 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
380 >CB aux. contact 3pole
Open (>CB 3p Open)
P.System
Data 2
SP * * * LED BI BO 15
0
79 1 Yes
381 >Single-phase trip
permitted from ext.AR
(>1p Trip Perm)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO
382 >External AR
programmed for 1phase
only (>Only 1ph AR)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO
383 >Enable all AR Zones /
Stages (>Enable ARzones)
P.System
Data 2
SP O
N
OF
F
ON
OFF
* LED BI BO
385 >Lockout SET (>Lockout
SET)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO 15
0
35 1 Yes
386 >Lockout RESET
(>Lockout RESET)
P.System
Data 2
SP O
N
OF
F
* * LED BI BO 15
0
36 1 Yes
395 >I MIN/MAX Buffer Reset
(>I MinMax Reset)
Min/Max
meter
SP O
N
* * LED BI BO
396 >I1 MIN/MAX Buffer Reset
(>I1 MiMaReset)
Min/Max
meter
SP O
N
* * LED BI BO
397 >U MIN/MAX Buffer Reset
(>U MiMaReset)
Min/Max
meter
SP O
N
* * LED BI BO
398 >Uphph MIN/MAX Buffer
Reset (>UphphMiMaRes)
Min/Max
meter
SP O
N
* * LED BI BO
399 >U1 MIN/MAX Buffer
Reset (>U1 MiMa Reset)
Min/Max
meter
SP O
N
* * LED BI BO
400 >P MIN/MAX Buffer Reset
(>P MiMa Reset)
Min/Max
meter
SP O
N
* * LED BI BO
401 >S MIN/MAX Buffer Reset
(>S MiMa Reset)
Min/Max
meter
SP O
N
* * LED BI BO
402 >Q MIN/MAX Buffer Reset
(>Q MiMa Reset)
Min/Max
meter
SP O
N
* * LED BI BO
403 >Idmd MIN/MAX Buffer
Reset (>Idmd MiMaReset)
Min/Max
meter
SP O
N
* * LED BI BO
404 >Pdmd MIN/MAX Buffer
Reset (>Pdmd MiMaR-
eset)
Min/Max
meter
SP O
N
* * LED BI BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 569
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
405 >Qdmd MIN/MAX Buffer
Reset (>Qdmd MiMaR-
eset)
Min/Max
meter
SP O
N
* * LED BI BO
406 >Sdmd MIN/MAX Buffer
Reset (>Sdmd MiMaR-
eset)
Min/Max
meter
SP O
N
* * LED BI BO
407 >Frq. MIN/MAX Buffer
Reset (>Frq MiMa Reset)
Min/Max
meter
SP O
N
* * LED BI BO
408 >Power Factor MIN/MAX
Buffer Reset (>PF MiMaR-
eset)
Min/Max
meter
SP O
N
* * LED BI BO
410 >CB1 aux. 3p Closed (for
AR, CB-Test) (>CB1 3p
Closed)
P.System
Data 2
SP * * * LED BI BO 15
0
80 1 Yes
411 >CB1 aux. 3p Open (for
AR, CB-Test) (>CB1 3p
Open)
P.System
Data 2
SP * * * LED BI BO 15
0
81 1 Yes
501 Relay PICKUP (Relay
PICKUP)
P.System
Data 2
OUT * * m LED BO 12
8
84 2 Yes
503 Relay PICKUP Phase L1
(Relay PICKUP L1)
P.System
Data 2
OUT * * m LED BO 12
8
64 2 Yes
504 Relay PICKUP Phase L2
(Relay PICKUP L2)
P.System
Data 2
OUT * * m LED BO 12
8
65 2 Yes
505 Relay PICKUP Phase L3
(Relay PICKUP L3)
P.System
Data 2
OUT * * m LED BO 12
8
66 2 Yes
506 Relay PICKUP Earth (Relay
PICKUP E)
P.System
Data 2
OUT * * m LED BO 12
8
67 2 Yes
507 Relay TRIP command
Phase L1 (Relay TRIP L1)
P.System
Data 2
OUT * * m LED BO 12
8
69 2 No
508 Relay TRIP command
Phase L2 (Relay TRIP L2)
P.System
Data 2
OUT * * m LED BO 12
8
70 2 No
509 Relay TRIP command
Phase L3 (Relay TRIP L3)
P.System
Data 2
OUT * * m LED BO 12
8
71 2 No
510 Relay GENERAL CLOSE
command (Relay CLOSE)
P.System
Data 2
OUT * * * * LED BO
511 Relay GENERAL TRIP
command (Relay TRIP)
P.System
Data 2
OUT * OFF m LED BO 12
8
68 2 No
512 Relay TRIP command -
Only Phase L1 (Relay TRIP
1pL1)
P.System
Data 2
OUT * * * LED BO
513 Relay TRIP command -
Only Phase L2 (Relay TRIP
1pL2)
P.System
Data 2
OUT * * * LED BO
Functions, Settings, Information
E.3 Information List
570 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
514 Relay TRIP command -
Only Phase L3 (Relay TRIP
1pL3)
P.System
Data 2
OUT * * * LED BO
515 Relay TRIP command
Phases L123 (Relay TRIP
3ph.)
P.System
Data 2
OUT * * * LED BO
530 LOCKOUT is active
(LOCKOUT)
P.System
Data 2
IntS
P
O
N
OF
F
ON
OFF
* LED BO 15
0
17
0
1 Yes
533 Primary fault current IL1
(IL1 =)
P.System
Data 2
VI * ON
OFF
15
0
17
7
4 No
534 Primary fault current IL2
(IL2 =)
P.System
Data 2
VI * ON
OFF
15
0
17
8
4 No
535 Primary fault current IL3
(IL3 =)
P.System
Data 2
VI * ON
OFF
15
0
17
9
4 No
536 Relay Definitive TRIP
(Definitive TRIP)
P.System
Data 2
OUT O
N
ON * * LED BO 15
0
18
0
2 No
545 Time from Pickup to drop
out (PU Time)
P.System
Data 2
VI
546 Time from Pickup to TRIP
(TRIP Time)
P.System
Data 2
VI
560 Single-phase trip was
coupled 3phase (Trip
Coupled 3p)
P.System
Data 2
OUT * ON * LED BO 15
0
21
0
2 No
561 Manual close signal
detected
(Man.Clos.Detect)
P.System
Data 2
OUT O
N
* * LED BO 15
0
21
1
1 No
562 CB CLOSE command for
manual closing
(Man.Close Cmd)
P.System
Data 2
OUT * * * LED BO 15
0
21
2
1 No
563 CB alarm suppressed (CB
Alarm Supp)
P.System
Data 2
OUT * * * LED BO
590 Line closure detected
(Line closure)
P.System
Data 2
OUT O
N
OF
F
ON
OFF
m LED BO
591 Single pole open detected
in L1 (1pole open L1)
P.System
Data 2
OUT O
N
OF
F
ON
OFF
m LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 571
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
592 Single pole open detected
in L2 (1pole open L2)
P.System
Data 2
OUT O
N
OF
F
ON
OFF
m LED BO
593 Single pole open detected
in L3 (1pole open L3)
P.System
Data 2
OUT O
N
OF
F
ON
OFF
m LED BO
1000 Number of breaker TRIP
commands (# TRIPs=)
Statistics VI
1001 Number of breaker TRIP
commands L1 (TripNo
L1=)
Statistics VI
1002 Number of breaker TRIP
commands L2 (TripNo
L2=)
Statistics VI
1003 Number of breaker TRIP
commands L3 (TripNo
L3=)
Statistics VI
1027 Accumulation of inter-
rupted current L1 (Σ IL1
=)
Statistics VI
1028 Accumulation of inter-
rupted current L2 (Σ IL2
=)
Statistics VI
1029 Accumulation of inter-
rupted current L3 (Σ IL3
=)
Statistics VI
1030 Max. fault current Phase
L1 (Max IL1 =)
Statistics VI
1031 Max. fault current Phase
L2 (Max IL2 =)
Statistics VI
1032 Max. fault current Phase
L3 (Max IL3 =)
Statistics VI
1114 Flt Locator: primary
RESISTANCE (Rpri =)
Fault
Locator
VI ON
OFF
15
1
14 4 No
1115 Flt Locator: primary REAC-
TANCE (Xpri =)
Fault
Locator
VI ON
OFF
12
8
73 4 No
1117 Flt Locator: secondary
RESISTANCE (Rsec =)
Fault
Locator
VI ON
OFF
15
1
17 4 No
1118 Flt Locator: secondary
REACTANCE (Xsec =)
Fault
Locator
VI ON
OFF
15
1
18 4 No
1119 Flt Locator: Distance to
fault (dist =)
Fault
Locator
VI ON
OFF
15
1
19 4 No
Functions, Settings, Information
E.3 Information List
572 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1120 Flt Locator: Distance [%]
to fault (d[%] =)
Fault
Locator
VI ON
OFF
15
1
20 4 No
1122 Flt Locator: Distance to
fault (dist =)
Fault
Locator
VI ON
OFF
15
1
22 4 No
1123 Fault Locator Loop L1E
(FL Loop L1E)
Fault
Locator
OUT
_Ev
ON
1124 Fault Locator Loop L2E
(FL Loop L2E)
Fault
Locator
OUT
_Ev
ON
1125 Fault Locator Loop L3E
(FL Loop L3E)
Fault
Locator
OUT
_Ev
ON
1126 Fault Locator Loop L1L2
(FL Loop L1L2)
Fault
Locator
OUT
_Ev
ON
1127 Fault Locator Loop L2L3
(FL Loop L2L3)
Fault
Locator
OUT
_Ev
ON
1128 Fault Locator Loop L3L1
(FL Loop L3L1)
Fault
Locator
OUT
_Ev
ON
1132 Fault location invalid
(Flt.Loc.invalid)
Fault
Locator
OUT * ON * LED BO
1133 Fault locator setting error
K0,angle(K0)
(Flt.Loc.ErrorK0)
Fault
Locator
OUT * ON * LED BO
1143 BCD Fault location [1%]
(BCD d[1%])
Fault
Locator
OUT * * * LED BO
1144 BCD Fault location [2%]
(BCD d[2%])
Fault
Locator
OUT * * * LED BO
1145 BCD Fault location [4%]
(BCD d[4%])
Fault
Locator
OUT * * * LED BO
1146 BCD Fault location [8%]
(BCD d[8%])
Fault
Locator
OUT * * * LED BO
1147 BCD Fault location [10%]
(BCD d[10%])
Fault
Locator
OUT * * * LED BO
1148 BCD Fault location [20%]
(BCD d[20%])
Fault
Locator
OUT * * * LED BO
1149 BCD Fault location [40%]
(BCD d[40%])
Fault
Locator
OUT * * * LED BO
1150 BCD Fault location [80%]
(BCD d[80%])
Fault
Locator
OUT * * * LED BO
1151 BCD Fault location [100%]
(BCD d[100%])
Fault
Locator
OUT * * * LED BO
1152 BCD Fault location valid
(BCD dist. VALID)
Fault
Locator
OUT * * * LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 573
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1305 >Earth Fault O/C Block
3I0>>> (>EF BLK 3I0>>>)
Earth Fault
O/C
SP O
N
OF
F
* * LED BI BO 16
6
5 1 Yes
1307 >Earth Fault O/C Block
3I0>> (>EF BLOCK 3I0>>)
Earth Fault
O/C
SP O
N
OF
F
* * LED BI BO 16
6
7 1 Yes
1308 >Earth Fault O/C Block
3I0> (>EF BLOCK 3I0>)
Earth Fault
O/C
SP O
N
OF
F
* * LED BI BO 16
6
8 1 Yes
1309 >Earth Fault O/C Block
3I0p (>EF BLOCK 3I0p)
Earth Fault
O/C
SP O
N
OF
F
* * LED BI BO 16
6
9 1 Yes
1310 >Earth Fault O/C Instanta-
neous trip (>EF InstTRIP)
Earth Fault
O/C
SP O
N
OF
F
ON
OFF
* LED BI BO 16
6
10 1 Yes
1311 >E/F Teleprotection ON
(>EF Teleprot.ON)
Teleprot. E/F SP * * * LED BI BO
1312 >E/F Teleprotection OFF
(>EF TeleprotOFF)
Teleprot. E/F SP * * * LED BI BO
1313 >E/F Teleprotection
BLOCK (>EF TeleprotBLK)
Teleprot. E/F SP O
N
OF
F
* * LED BI BO 16
6
13 1 Yes
1318 >E/F Carrier RECEPTION,
Channel 1 (>EF Rec.Ch1)
Teleprot. E/F SP On
Of
f
On * LED BI BO 16
6
18 1 Yes
1319 >E/F Carrier RECEPTION,
Channel 2 (>EF Rec.Ch2)
Teleprot. E/F SP On
Of
f
On * LED BI BO 16
6
19 1 Yes
1320 >E/F Unblocking:
UNBLOCK, Channel 1
(>EF UB ub 1)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
20 1 Yes
1321 >E/F Unblocking: BLOCK,
Channel 1 (>EF UB bl 1)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
21 1 Yes
Functions, Settings, Information
E.3 Information List
574 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1322 >E/F Unblocking:
UNBLOCK, Channel 2
(>EF UB ub 2)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
22 1 Yes
1323 >E/F Unblocking: BLOCK,
Channel 2 (>EF UB bl 2)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
23 1 Yes
1324 >E/F BLOCK Echo Signal
(>EF BlkEcho)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
24 1 Yes
1325 >E/F Carrier RECEPTION,
Channel 1, Ph.L1 (>EF
Rec.Ch1 L1)
Teleprot. E/F SP On
Of
f
On * LED BI BO 16
6
25 1 Yes
1326 >E/F Carrier RECEPTION,
Channel 1, Ph.L2 (>EF
Rec.Ch1 L2)
Teleprot. E/F SP On
Of
f
On * LED BI BO 16
6
26 1 Yes
1327 >E/F Carrier RECEPTION,
Channel 1, Ph.L3 (>EF
Rec.Ch1 L3)
Teleprot. E/F SP On
Of
f
On * LED BI BO 16
6
27 1 Yes
1328 >E/F Unblocking:
UNBLOCK Chan. 1, Ph.L1
(>EF UB ub 1-L1)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
28 1 Yes
1329 >E/F Unblocking:
UNBLOCK Chan. 1, Ph.L2
(>EF UB ub 1-L2)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
29 1 Yes
1330 >E/F Unblocking:
UNBLOCK Chan. 1, Ph.L3
(>EF UB ub 1-L3)
Teleprot. E/F SP O
N
OF
F
ON * LED BI BO 16
6
30 1 Yes
1331 Earth fault protection is
switched OFF (E/F Prot.
OFF)
Earth Fault
O/C
OUT O
N
OF
F
* * LED BO 16
6
31 1 Yes
1332 Earth fault protection is
BLOCKED (E/F BLOCK)
Earth Fault
O/C
OUT O
N
OF
F
ON
OFF
* LED BO 16
6
32 1 Yes
1333 Earth fault protection is
ACTIVE (E/F ACTIVE)
Earth Fault
O/C
OUT * * * LED BO 16
6
33 1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 575
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1335 Earth fault protection Trip
is blocked (EF TRIP
BLOCK)
Earth Fault
O/C
OUT O
N
OF
F
ON
OFF
* LED BO
1336 E/F phase selector L1
selected (E/F L1 selec.)
Earth Fault
O/C
OUT * ON
OFF
* LED BO
1337 E/F phase selector L2
selected (E/F L2 selec.)
Earth Fault
O/C
OUT * ON
OFF
* LED BO
1338 E/F phase selector L3
selected (E/F L3 selec.)
Earth Fault
O/C
OUT * ON
OFF
* LED BO
1345 Earth fault protection
PICKED UP (EF Pickup)
Earth Fault
O/C
OUT * Off m LED BO 16
6
45 2 Yes
1354 E/F 3I0>>> PICKED UP (EF
3I0>>>Pickup)
Earth Fault
O/C
OUT * ON * LED BO
1355 E/F 3I0>> PICKED UP (EF
3I0>> Pickup)
Earth Fault
O/C
OUT * ON * LED BO
1356 E/F 3I0> PICKED UP (EF
3I0> Pickup)
Earth Fault
O/C
OUT * ON * LED BO
1357 E/F 3I0p PICKED UP (EF
3I0p Pickup)
Earth Fault
O/C
OUT * ON * LED BO
1358 E/F picked up FORWARD
(EF forward)
Earth Fault
O/C
OUT * ON * LED BO 16
6
58 2 No
1359 E/F picked up REVERSE (EF
reverse)
Earth Fault
O/C
OUT * ON * LED BO 16
6
59 2 No
1361 E/F General TRIP
command (EF Trip)
Earth Fault
O/C
OUT * * * LED BO 16
6
61 2 No
1362 Earth fault protection:
Trip 1pole L1 (E/F Trip L1)
Earth Fault
O/C
OUT * ON m LED BO 16
6
62 2 Yes
1363 Earth fault protection:
Trip 1pole L2 (E/F Trip L2)
Earth Fault
O/C
OUT * ON m LED BO 16
6
63 2 Yes
1364 Earth fault protection:
Trip 1pole L3 (E/F Trip L3)
Earth Fault
O/C
OUT * ON m LED BO 16
6
64 2 Yes
1365 Earth fault protection:
Trip 3pole (E/F Trip 3p)
Earth Fault
O/C
OUT * ON m LED BO 16
6
65 2 Yes
1366 E/F 3I0>>> TRIP (EF
3I0>>> TRIP)
Earth Fault
O/C
OUT * ON * LED BO 16
6
66 2 No
1367 E/F 3I0>> TRIP (EF 3I0>>
TRIP)
Earth Fault
O/C
OUT * ON * LED BO 16
6
67 2 No
1368 E/F 3I0> TRIP (EF 3I0>
TRIP)
Earth Fault
O/C
OUT * ON * LED BO 16
6
68 2 No
1369 E/F 3I0p TRIP (EF 3I0p
TRIP)
Earth Fault
O/C
OUT * ON * LED BO 16
6
69 2 No
Functions, Settings, Information
E.3 Information List
576 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1370 E/F Inrush picked up (EF
InrushPU)
Earth Fault
O/C
OUT * ON
OFF
* LED BO 16
6
70 2 No
1371 E/F Telep. Carrier SEND
signal, Phase L1 (EF Tele
SEND L1)
Teleprot. E/F OUT On On * LED BO 16
6
71 1 No
1372 E/F Telep. Carrier SEND
signal, Phase L2 (EF Tele
SEND L2)
Teleprot. E/F OUT On On * LED BO 16
6
72 1 No
1373 E/F Telep. Carrier SEND
signal, Phase L3 (EF Tele
SEND L3)
Teleprot. E/F OUT On On * LED BO 16
6
73 1 No
1374 E/F Telep. Block: carrier
STOP signal L1 (EF Tele
STOP L1)
Teleprot. E/F OUT * On * LED BO 16
6
74 2 No
1375 E/F Telep. Block: carrier
STOP signal L2 (EF Tele
STOP L2)
Teleprot. E/F OUT * On * LED BO 16
6
75 2 No
1376 E/F Telep. Block: carrier
STOP signal L3 (EF Tele
STOP L3)
Teleprot. E/F OUT * On * LED BO 16
6
76 2 No
1380 E/F Teleprot. ON/OFF via
BI (EF TeleON/offBI)
Teleprot. E/F IntS
P
O
N
OF
F
* * LED BO
1381 E/F Teleprotection is
switched OFF (EF Telep.
OFF)
Teleprot. E/F OUT O
N
OF
F
* * LED BO 16
6
81 1 Yes
1384 E/F Telep. Carrier SEND
signal (EF Tele SEND)
Teleprot. E/F OUT On On * LED BO 16
6
84 2 No
1386 E/F Telep. Transient
Blocking (EF TeleTransBlk)
Teleprot. E/F OUT * ON * LED BO 16
6
86 2 No
1387 E/F Telep. Unblocking:
FAILURE Channel 1 (EF
TeleUB Fail1)
Teleprot. E/F OUT O
N
OF
F
* * LED BO 16
6
87 1 Yes
1388 E/F Telep. Unblocking:
FAILURE Channel 2 (EF
TeleUB Fail2)
Teleprot. E/F OUT O
N
OF
F
* * LED BO 16
6
88 1 Yes
1389 E/F Telep. Blocking:
carrier STOP signal (EF
Tele BL STOP)
Teleprot. E/F OUT * On * LED BO 16
6
89 2 No
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 577
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1390 E/F Tele.Blocking: Send
signal with jump (EF Tele
BL Jump)
Teleprot. E/F OUT * * * LED BO 16
6
90 2 No
1391 EF Tele.Carrier RECEP-
TION, L1, Device1 (EF
Rec.L1 Dev1)
Teleprot. E/F OUT On
Of
f
On * LED BO
1392 EF Tele.Carrier RECEP-
TION, L2, Device1 (EF
Rec.L2 Dev1)
Teleprot. E/F OUT On
Of
f
On * LED BO
1393 EF Tele.Carrier RECEP-
TION, L3, Device1 (EF
Rec.L3 Dev1)
Teleprot. E/F OUT On
Of
f
On * LED BO
1394 EF Tele.Carrier RECEP-
TION, L1, Device2 (EF
Rec.L1 Dev2)
Teleprot. E/F OUT On
Of
f
On * LED BO
1395 EF Tele.Carrier RECEP-
TION, L2, Device2 (EF
Rec.L2 Dev2)
Teleprot. E/F OUT On
Of
f
On * LED BO
1396 EF Tele.Carrier RECEP-
TION, L3, Device2 (EF
Rec.L3 Dev2)
Teleprot. E/F OUT On
Of
f
On * LED BO
1397 EF Tele.Carrier RECEP-
TION, L1, Device3 (EF
Rec.L1 Dev3)
Teleprot. E/F OUT On
Of
f
On * LED BO
1398 EF Tele.Carrier RECEP-
TION, L2, Device3 (EF
Rec.L2 Dev3)
Teleprot. E/F OUT On
Of
f
On * LED BO
1399 EF Tele.Carrier RECEP-
TION, L3, Device3 (EF
Rec.L3 Dev3)
Teleprot. E/F OUT On
Of
f
On * LED BO
1401 >BF: Switch on breaker
fail protection (>BF on)
Breaker
Failure
SP * * * LED BI BO
1402 >BF: Switch off breaker
fail protection (>BF off)
Breaker
Failure
SP * * * LED BI BO
1403 >BLOCK Breaker failure
(>BLOCK BkrFail)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO 16
6
10
3
1 Yes
1404 >BF Activate 3I0>
threshold (>BFacti-
vate3I0>)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
Functions, Settings, Information
E.3 Information List
578 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1415 >BF: External start 3pole
(>BF Start 3pole)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
1424 >BF: Start only delay time
T2 (>BF STARTonlyT2)
Breaker
Failure
SP O
N
OF
F
ON
OFF
* LED BI BO
1432 >BF: External release (>BF
release)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
1435 >BF: External start L1
(>BF Start L1)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
1436 >BF: External start L2
(>BF Start L2)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
1437 >BF: External start L3
(>BF Start L3)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
1439 >BF: External start 3pole
(w/o current) (>BF Start
w/o I)
Breaker
Failure
SP O
N
OF
F
* * LED BI BO
1440 Breaker failure prot.
ON/OFF via BI (BkrFailON/
offBI)
Breaker
Failure
IntS
P
O
N
OF
F
* * LED BO
1451 Breaker failure is switched
OFF (BkrFail OFF)
Breaker
Failure
OUT O
N
OF
F
* * LED BO 16
6
15
1
1 Yes
1452 Breaker failure is
BLOCKED (BkrFail BLOCK)
Breaker
Failure
OUT O
N
OF
F
ON
OFF
* LED BO 16
6
15
2
1 Yes
1453 Breaker failure is ACTIVE
(BkrFail ACTIVE)
Breaker
Failure
OUT * * * LED BO 16
6
15
3
1 Yes
1461 Breaker failure protection
started (BF Start)
Breaker
Failure
OUT * ON
OFF
* LED BO 16
6
16
1
2 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 579
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
1472 BF Trip T1 (local trip) -
only phase L1 (BF T1-TRIP
1pL1)
Breaker
Failure
OUT * ON * LED BO
1473 BF Trip T1 (local trip) -
only phase L2 (BF T1-TRIP
1pL2)
Breaker
Failure
OUT * ON * LED BO
1474 BF Trip T1 (local trip) -
only phase L3 (BF T1-TRIP
1pL3)
Breaker
Failure
OUT * ON * LED BO
1476 BF Trip T1 (local trip) -
3pole (BF T1-TRIP L123)
Breaker
Failure
OUT * ON * LED BO
1493 BF Trip in case of defec-
tive CB (BF TRIP CBdefec)
Breaker
Failure
OUT * ON * LED BO
1494 BF Trip T2 (busbar trip)
(BF T2-TRIP(bus))
Breaker
Failure
OUT * ON * LED BO 12
8
85 2 No
1495 BF Trip End fault stage (BF
EndFlt TRIP)
Breaker
Failure
OUT * ON * LED BO
1496 BF Pole discrepancy
pickup (BF CBdiscrSTART)
Breaker
Failure
OUT * ON
OFF
* LED BO
1497 BF Pole discrepancy
pickup L1 (BF CBdiscr L1)
Breaker
Failure
OUT * ON
OFF
* LED BO
1498 BF Pole discrepancy
pickup L2 (BF CBdiscr L2)
Breaker
Failure
OUT * ON
OFF
* LED BO
1499 BF Pole discrepancy
pickup L3 (BF CBdiscr L3)
Breaker
Failure
OUT * ON
OFF
* LED BO
1500 BF Pole discrepancy Trip
(BF CBdiscr TRIP)
Breaker
Failure
OUT * ON * LED BO
2054 Emergency mode (Emer.
mode)
Back-Up O/C OUT O
N
OF
F
ON
OFF
* LED BO 12
8
37 1 Yes
2701 >AR: Switch on auto-
reclose function (>AR on)
Autoreclo-
sure
SP * * * LED BI BO 40 1 1 No
2702 >AR: Switch off auto-
reclose function (>AR off)
Autoreclo-
sure
SP * * * LED BI BO 40 2 1 No
2703 >AR: Block auto-reclose
function (>AR block)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 3 1 Yes
2711 >External start of internal
Auto reclose (>AR Start)
Autoreclo-
sure
SP * ON * LED BI BO 40 11 2 Yes
2712 >AR: External trip L1 for
AR start (>Trip L1 AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 12 2 Yes
Functions, Settings, Information
E.3 Information List
580 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2713 >AR: External trip L2 for
AR start (>Trip L2 AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 13 2 Yes
2714 >AR: External trip L3 for
AR start (>Trip L3 AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 14 2 Yes
2715 >AR: External 1pole trip
for AR start (>Trip 1pole
AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 15 2 Yes
2716 >AR: External 3pole trip
for AR start (>Trip 3pole
AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 16 2 Yes
2727 >AR: Remote Close signal
(>AR RemoteClose)
Autoreclo-
sure
SP * ON * LED BI BO 40 22 2 Yes
2731 >AR: Sync. release from
ext. sync.-check
(>Sync.release)
Autoreclo-
sure
SP * * * LED BI BO 40 31 2 Yes
2737 >AR: Block 1pole AR-cycle
(>BLOCK 1pole AR)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 32 1 Yes
2738 >AR: Block 3pole AR-cycle
(>BLOCK 3pole AR)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 33 1 Yes
2739 >AR: Block 1phase-fault
AR-cycle (>BLK 1phase
AR)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 34 1 Yes
2740 >AR: Block 2phase-fault
AR-cycle (>BLK 2phase
AR)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 35 1 Yes
2741 >AR: Block 3phase-fault
AR-cycle (>BLK 3phase
AR)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 36 1 Yes
2742 >AR: Block 1st AR-cycle
(>BLK 1.AR-cycle)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 37 1 Yes
2743 >AR: Block 2nd AR-cycle
(>BLK 2.AR-cycle)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 38 1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 581
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2744 >AR: Block 3rd AR-cycle
(>BLK 3.AR-cycle)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 39 1 Yes
2745 >AR: Block 4th and higher
AR-cycles (>BLK 4.-n. AR)
Autoreclo-
sure
SP O
N
OF
F
* * LED BI BO 40 40 1 Yes
2746 >AR: External Trip for AR
start (>Trip for AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 41 2 Yes
2747 >AR: External pickup L1
for AR start (>Pickup L1
AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 42 2 Yes
2748 >AR: External pickup L2
for AR start (>Pickup L2
AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 43 2 Yes
2749 >AR: External pickup L3
for AR start (>Pickup L3
AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 44 2 Yes
2750 >AR: External pickup
1phase for AR start
(>Pickup 1ph AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 45 2 Yes
2751 >AR: External pickup
2phase for AR start
(>Pickup 2ph AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 46 2 Yes
2752 >AR: External pickup
3phase for AR start
(>Pickup 3ph AR)
Autoreclo-
sure
SP * ON * LED BI BO 40 47 2 Yes
2781 AR: Auto-reclose is
switched off (AR off)
Autoreclo-
sure
OUT O
N
OF
F
* * LED BO 40 81 1 Yes
2782 AR: Auto-reclose is
switched on (AR on)
Autoreclo-
sure
IntS
P
* * * LED BO 12
8
16 1 Yes
2783 AR: Auto-reclose is
blocked (AR is blocked)
Autoreclo-
sure
OUT O
N
OF
F
* * LED BO 40 83 1 Yes
2784 AR: Auto-reclose is not
ready (AR not ready)
Autoreclo-
sure
OUT * ON * LED BO 12
8
13
0
1 Yes
2787 AR: Circuit breaker not
ready (CB not ready)
Autoreclo-
sure
OUT * * * LED BO 40 87 1 No
Functions, Settings, Information
E.3 Information List
582 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2788 AR: CB ready monitoring
window expired (AR T-
CBreadyExp)
Autoreclo-
sure
OUT * ON * LED BO 40 88 2 No
2796 AR: Auto-reclose ON/OFF
via BI (AR on/off BI)
Autoreclo-
sure
IntS
P
* * * LED BO
2801 AR: Auto-reclose in
progress (AR in progress)
Autoreclo-
sure
OUT * ON * LED BO 40 10
1
2 Yes
2809 AR: Start-signal moni-
toring time expired (AR T-
Start Exp)
Autoreclo-
sure
OUT * ON * LED BO 40 17
4
2 No
2810 AR: Maximum dead time
expired (AR TdeadMax
Exp)
Autoreclo-
sure
OUT * ON * LED BO 40 17
5
2 No
2818 AR: Evolving fault recog-
nition (AR evolving Flt)
Autoreclo-
sure
OUT * ON * LED BO 40 11
8
2 Yes
2820 AR is set to operate after
1p trip only (AR
Program1pole)
Autoreclo-
sure
OUT * * * LED BO 40 14
3
1 No
2821 AR dead time after
evolving fault (AR Td.
evol.Flt)
Autoreclo-
sure
OUT * ON * LED BO 40 19
7
2 No
2839 AR dead time after 1pole
trip running (AR Tdead
1pTrip)
Autoreclo-
sure
OUT * ON * LED BO 40 14
8
2 Yes
2840 AR dead time after 3pole
trip running (AR Tdead
3pTrip)
Autoreclo-
sure
OUT * ON * LED BO 40 14
9
2 Yes
2841 AR dead time after
1phase fault running (AR
Tdead 1pFlt)
Autoreclo-
sure
OUT * ON * LED BO 40 15
0
2 Yes
2842 AR dead time after
2phase fault running (AR
Tdead 2pFlt)
Autoreclo-
sure
OUT * ON * LED BO 40 15
1
2 Yes
2843 AR dead time after
3phase fault running (AR
Tdead 3pFlt)
Autoreclo-
sure
OUT * ON * LED BO 40 15
4
2 Yes
2844 AR 1st cycle running (AR
1stCyc. run.)
Autoreclo-
sure
OUT * ON * LED BO 40 15
5
2 Yes
2845 AR 2nd cycle running (AR
2ndCyc. run.)
Autoreclo-
sure
OUT * ON * LED BO 40 15
7
2 Yes
2846 AR 3rd cycle running (AR
3rdCyc. run.)
Autoreclo-
sure
OUT * ON * LED BO 40 15
8
2 Yes
2847 AR 4th or higher cycle
running (AR 4thCyc. run.)
Autoreclo-
sure
OUT * ON * LED BO 40 15
9
2 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 583
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2848 AR cycle is running in ADT
mode (AR ADT run.)
Autoreclo-
sure
OUT * ON * LED BO 40 13
0
2 Yes
2851 AR: Close command (AR
CLOSE Cmd.)
Autoreclo-
sure
OUT * ON m LED BO 12
8
12
8
2 No
2852 AR: Close command after
1pole, 1st cycle (AR
Close1.Cyc1p)
Autoreclo-
sure
OUT * * * LED BO 40 15
2
1 No
2853 AR: Close command after
3pole, 1st cycle (AR
Close1.Cyc3p)
Autoreclo-
sure
OUT * * * LED BO 40 15
3
1 No
2854 AR: Close command 2nd
cycle (and higher) (AR
Close 2.Cyc)
Autoreclo-
sure
OUT * * * LED BO 12
8
12
9
1 No
2857 AR: RDT Close command
after TDEADxTRIP (AR
CLOSE RDT TD)
Autoreclo-
sure
OUT * * * LED BO
2861 AR: Reclaim time is
running (AR T-Recl. run.)
Autoreclo-
sure
OUT * * * LED BO 40 16
1
1 No
2862 AR successful (AR
successful)
Autoreclo-
sure
OUT * * * LED BO 40 16
2
1 No
2864 AR: 1pole trip permitted
by internal AR (AR 1p Trip
Perm)
Autoreclo-
sure
OUT * * * LED BO 40 16
4
1 Yes
2865 AR: Synchro-check
request (AR
Sync.Request)
Autoreclo-
sure
OUT * * * LED BO 40 16
5
2 Yes
2871 AR: TRIP command 3pole
(AR TRIP 3pole)
Autoreclo-
sure
OUT * ON * LED BO 40 17
1
2 Yes
2889 AR 1st cycle zone exten-
sion release (AR 1.CycZo-
neRel)
Autoreclo-
sure
OUT * * * LED BO 40 16
0
1 No
2890 AR 2nd cycle zone exten-
sion release (AR 2.CycZo-
neRel)
Autoreclo-
sure
OUT * * * LED BO 40 16
9
1 No
2891 AR 3rd cycle zone exten-
sion release (AR 3.CycZo-
neRel)
Autoreclo-
sure
OUT * * * LED BO 40 17
0
1 No
2892 AR 4th cycle zone exten-
sion release (AR 4.CycZo-
neRel)
Autoreclo-
sure
OUT * * * LED BO 40 17
2
1 No
2893 AR zone extension
(general) (AR Zone
Release)
Autoreclo-
sure
OUT * * * LED BO 40 17
3
1 Yes
Functions, Settings, Information
E.3 Information List
584 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2894 AR Remote close signal
send (AR Remote Close)
Autoreclo-
sure
OUT * ON * LED BO 40 12
9
2 No
2895 No. of 1st AR-cycle CLOSE
commands,1pole (AR
#Close1./1p=)
Statistics VI
2896 No. of 1st AR-cycle CLOSE
commands,3pole (AR
#Close1./3p=)
Statistics VI
2897 No. of higher AR-cycle
CLOSE commands,1p (AR
#Close2./1p=)
Statistics VI
2898 No. of higher AR-cycle
CLOSE commands,3p (AR
#Close2./3p=)
Statistics VI
2901 >Switch on synchro-check
function (>Sync. on)
Sync. Check SP * * * LED BI BO
2902 >Switch off synchro-
check function (>Sync.
off)
Sync. Check SP * * * LED BI BO
2903 >BLOCK synchro-check
function (>BLOCK Sync.)
Sync. Check SP * * * LED BI BO
2905 >Start synchro-check for
Manual Close (>Sync.
Start MC)
Sync. Check SP On
Of
f
* * LED BI BO
2906 >Start synchro-check for
AR (>Sync. Start AR)
Sync. Check SP On
Of
f
* * LED BI BO
2907 >Sync-Prog. Live bus / live
line / Sync (>Sync. synch)
Sync. Check SP * * * LED BI BO
2908 >Sync-Prog. Usy1>Usy2<
(>Usy1>Usy2<)
Sync. Check SP * * * LED BI BO
2909 >Sync-Prog. Usy1<Usy2>
(>Usy1<Usy2>)
Sync. Check SP * * * LED BI BO
2910 >Sync-Prog. Usy1<Usy2<
(>Usy1<Usy2<)
Sync. Check SP * * * LED BI BO
2911 >Sync-Prog. Override
( bypass ) (>Sync. o/ride)
Sync. Check SP * * * LED BI BO
2930 Synchro-check ON/OFF
via BI (Sync. on/off BI)
Sync. Check IntS
P
O
N
OF
F
* * LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 585
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2931 Synchro-check is
switched OFF (Sync. OFF)
Sync. Check OUT O
N
OF
F
* * LED BO 41 31 1 Yes
2932 Synchro-check is
BLOCKED (Sync. BLOCK)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO 41 32 1 Yes
2934 Synchro-check function
faulty (Sync. faulty)
Sync. Check OUT O
N
OF
F
* * LED BO 41 34 1 Yes
2935 Synchro-check supervi-
sion time expired
(Sync.Tsup.Exp)
Sync. Check OUT O
N
ON * LED BO 41 35 1 No
2936 Synchro-check request by
control (Sync. req.CNTRL)
Sync. Check OUT O
N
ON * LED BO 41 36 1 No
2941 Synchronization is
running (Sync. running)
Sync. Check OUT O
N
OF
F
ON * LED BO 41 41 1 Yes
2942 Synchro-check override/
bypass (Sync.Override)
Sync. Check OUT O
N
OF
F
ON * LED BO 41 42 1 Yes
2943 Synchronism detected
(Synchronism)
Sync. Check OUT O
N
OF
F
* * LED BO 41 43 1 Yes
2944 SYNC Condition
Usy1>Usy2< true (SYNC
Usy1>Usy2<)
Sync. Check OUT O
N
OF
F
* * LED BO 41 44 1 Yes
2945 SYNC Condition
Usy1<Usy2> true (SYNC
Usy1<Usy2>)
Sync. Check OUT O
N
OF
F
* * LED BO 41 45 1 Yes
2946 SYNC Condition
Usy1<Usy2< true (SYNC
Usy1<Usy2<)
Sync. Check OUT O
N
OF
F
* * LED BO 41 46 1 Yes
2947 Sync. Voltage diff. greater
than limit (Sync. Udiff>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO 41 47 1 Yes
Functions, Settings, Information
E.3 Information List
586 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2948 Sync. Freq. diff. greater
than limit (Sync. fdiff>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO 41 48 1 Yes
2949 Sync. Angle diff. greater
than limit (Sync. φ-diff>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO 41 49 1 Yes
2951 Synchronism release (to
ext. AR) (Sync. release)
Sync. Check OUT * * * LED BO 41 51 1 Yes
2961 Close command from
synchro-check
(Sync.CloseCmd)
Sync. Check OUT * * * LED BO 41 61 1 Yes
2970 SYNC frequency fsy2 > (fn
+ 3Hz) (SYNC fsy2>>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2971 SYNC frequency fsy2 < (fn
+ 3Hz) (SYNC fsy2<<)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2972 SYNC frequency fsy1 > (fn
+ 3Hz) (SYNC fsy1>>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2973 SYNC frequency fsy1 < (fn
+ 3Hz) (SYNC fsy1<<)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2974 SYNC voltage Usy2
>Umax (P.3504) (SYNC
Usy2>>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2975 SYNC voltage Usy2 < U>
(P.3503) (SYNC Usy2<<)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2976 SYNC voltage Usy1
>Umax (P.3504) (SYNC
Usy1>>)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2977 SYNC voltage Usy1 < U>
(P.3503) (SYNC Usy1<<)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 587
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
2978 SYNC Udiff too large
(Usy2>Usy1) (SYNC
Usy2>Usy1)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2979 SYNC Udiff too large
(Usy2<Usy1) (SYNC
Usy2<Usy1)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2980 SYNC fdiff too large
(fsy2>fsy1) (SYNC
fsy2>fsy1)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2981 SYNC fdiff too large
(fsy2<fsy1) (SYNC
fsy2<fsy1)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2982 SYNC PHIdiff too large
(PHIsy2>PHIsy1) (SYNC
φsy2>φsy1)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
2983 SYNC PHIdiff too large
(PHIsy2<PHIsy1) (SYNC
φsy2<φsy1)
Sync. Check OUT O
N
OF
F
ON
OFF
* LED BO
3196 Local relay in Teststate
(local Teststate)
Prot. Inter-
face
IntS
P
O
N
OF
F
ON * LED FK
TO
NL
IN
E
BO
3215 Incompatible Firmware
Versions (Wrong Firm-
ware)
Prot. Inter-
face
OUT O
N
* * LED BO
3217 Prot Int 1: Own Datas
received (PI1 Data reflec)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3218 Prot Int 2: Own Datas
received (PI2 Data reflec)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3227 >Prot Int 1: Transmitter is
switched off (>PI1 light
off)
Prot. Inter-
face
SP O
N
OF
F
* * LED BI BO
Functions, Settings, Information
E.3 Information List
588 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3228 >Prot Int 2: Transmitter is
switched off (>PI2 light
off)
Prot. Inter-
face
SP O
N
OF
F
* * LED BI BO
3229 Prot Int 1: Reception of
faulty data (PI1 Data
fault)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 13
5
1 Yes
3230 Prot Int 1: Total receiption
failure (PI1 Datafailure)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 13
6
1 Yes
3231 Prot Int 2: Reception of
faulty data (PI2 Data
fault)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 13
7
1 Yes
3232 Prot Int 2: Total receiption
failure (PI2 Datafailure)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 13
8
1 Yes
3233 Device table has inconsis-
tent numbers (DT incon-
sistent)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3234 Device tables are unequal
(DT unequal)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3235 Differences between
common parameters (Par.
different)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3236 Different PI for transmit
and receive (PI1<->PI2
error)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3239 Prot Int 1: Transmission
delay too high (PI1 TD
alarm)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 13
9
1 Yes
3240 Prot Int 2: Transmission
delay too high (PI2 TD
alarm)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 14
0
1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 589
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3243 Prot Int 1: Connected
with relay ID (PI1 with)
Prot. Inter-
face
VI O
N
OF
F
* *
3244 Prot Int 2: Connected
with relay ID (PI2 with)
Prot. Inter-
face
VI O
N
OF
F
* *
3274 PI1: IEEE C37.94 not
supported by module
(PI1: C37.94 n/a)
Prot. Inter-
face
OUT On
Of
f
* * LED BO
3275 PI2: IEEE C37.94 not
supported by module
(PI2: C37.94 n/a)
Prot. Inter-
face
OUT On
Of
f
* * LED BO
3457 System operates in a
closed Ringtopology
(Ringtopology)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 14
1
1 Yes
3458 System operates in a
open Chaintopology
(Chaintopology)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 14
2
1 Yes
3464 Communication topology
is complete (Topol
complete)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3475 Relay 1 in Logout state
(Rel1Logout)
Prot. Inter-
face
IntS
P
O
N
OF
F
* * LED FK
TO
NL
IN
E
BO 93 14
3
1 Yes
3476 Relay 2 in Logout state
(Rel2Logout)
Prot. Inter-
face
IntS
P
O
N
OF
F
* * LED FK
TO
NL
IN
E
BO 93 14
4
1 Yes
3477 Relay 3 in Logout state
(Rel3Logout)
Prot. Inter-
face
IntS
P
O
N
OF
F
* * LED FK
TO
NL
IN
E
BO 93 14
5
1 Yes
Functions, Settings, Information
E.3 Information List
590 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3484 Local activation of Logout
state (Logout)
Prot. Inter-
face
IntS
P
O
N
OF
F
* * LED FK
TO
NL
IN
E
BO 93 14
9
1 Yes
3487 Equal IDs in constellation
(Equal IDs)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO
3491 Relay 1 in Login state
(Rel1 Login)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 19
1
1 Yes
3492 Relay 2 in Login state
(Rel2 Login)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 19
2
1 Yes
3493 Relay 3 in Login state
(Rel3 Login)
Prot. Inter-
face
OUT O
N
OF
F
* * LED BO 93 19
3
1 Yes
3541 >Remote Command 1
signal input (>Remote
CMD 1)
Remote
Signals
SP On
Of
f
* * LED BI BO
3542 >Remote Command 2
signal input (>Remote
CMD 2)
Remote
Signals
SP On
Of
f
* * LED BI BO
3543 >Remote Command 3
signal input (>Remote
CMD 3)
Remote
Signals
SP On
Of
f
* * LED BI BO
3544 >Remote Command 4
signal input (>Remote
CMD 4)
Remote
Signals
SP On
Of
f
* * LED BI BO
3545 Remote Command 1
received (Remote CMD1
rec)
Remote
Signals
OUT On
Of
f
* * LED BO 93 15
4
1 Yes
3546 Remote Command 2
received (Remote CMD2
rec)
Remote
Signals
OUT On
Of
f
* * LED BO 93 15
5
1 Yes
3547 Remote Command 3
received (Remote CMD3
rec)
Remote
Signals
OUT On
Of
f
* * LED BO 93 15
6
1 Yes
3548 Remote Command 4
received (Remote CMD4
rec)
Remote
Signals
OUT On
Of
f
* * LED BO 93 15
7
1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 591
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3549 >Remote Signal 1 input
(>Rem. Signal 1)
Remote
Signals
SP On
Of
f
* * LED BI BO
3550 >Remote Signal 2 input
(>Rem.Signal 2)
Remote
Signals
SP On
Of
f
* * LED BI BO
3551 >Remote Signal 3 input
(>Rem.Signal 3)
Remote
Signals
SP On
Of
f
* * LED BI BO
3552 >Remote Signal 4 input
(>Rem.Signal 4)
Remote
Signals
SP On
Of
f
* * LED BI BO
3553 >Remote Signal 5 input
(>Rem.Signal 5)
Remote
Signals
SP On
Of
f
* * LED BI BO
3554 >Remote Signal 6 input
(>Rem.Signal 6)
Remote
Signals
SP On
Of
f
* * LED BI BO
3555 >Remote Signal 7 input
(>Rem.Signal 7)
Remote
Signals
SP On
Of
f
* * LED BI BO
3556 >Remote Signal 8 input
(>Rem.Signal 8)
Remote
Signals
SP On
Of
f
* * LED BI BO
3557 >Remote Signal 9 input
(>Rem.Signal 9)
Remote
Signals
SP On
Of
f
* * LED BI BO
3558 >Remote Signal 10 input
(>Rem.Signal10)
Remote
Signals
SP On
Of
f
* * LED BI BO
3559 >Remote Signal 11 input
(>Rem.Signal11)
Remote
Signals
SP On
Of
f
* * LED BI BO
3560 >Remote Signal 12 input
(>Rem.Signal12)
Remote
Signals
SP On
Of
f
* * LED BI BO
3561 >Remote Signal 13 input
(>Rem.Signal13)
Remote
Signals
SP On
Of
f
* * LED BI BO
3562 >Remote Signal 14 input
(>Rem.Signal14)
Remote
Signals
SP On
Of
f
* * LED BI BO
Functions, Settings, Information
E.3 Information List
592 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3563 >Remote Signal 15 input
(>Rem.Signal15)
Remote
Signals
SP On
Of
f
* * LED BI BO
3564 >Remote Signal 16 input
(>Rem.Signal16)
Remote
Signals
SP On
Of
f
* * LED BI BO
3565 >Remote Signal 17 input
(>Rem.Signal17)
Remote
Signals
SP On
Of
f
* * LED BI BO
3566 >Remote Signal 18 input
(>Rem.Signal18)
Remote
Signals
SP On
Of
f
* * LED BI BO
3567 >Remote Signal 19 input
(>Rem.Signal19)
Remote
Signals
SP On
Of
f
* * LED BI BO
3568 >Remote Signal 20 input
(>Rem.Signal20)
Remote
Signals
SP On
Of
f
* * LED BI BO
3569 >Remote Signal 21 input
(>Rem.Signal21)
Remote
Signals
SP On
Of
f
* * LED BI BO
3570 >Remote Signal 22 input
(>Rem.Signal22)
Remote
Signals
SP On
Of
f
* * LED BI BO
3571 >Remote Signal 23 input
(>Rem.Signal23)
Remote
Signals
SP On
Of
f
* * LED BI BO
3572 >Remote Signal 24 input
(>Rem.Signal24)
Remote
Signals
SP On
Of
f
* * LED BI BO
3573 Remote signal 1 received
(Rem.Sig 1recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 15
8
1 Yes
3574 Remote signal 2 received
(Rem.Sig 2recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 15
9
1 Yes
3575 Remote signal 3 received
(Rem.Sig 3recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
0
1 Yes
3576 Remote signal 4 received
(Rem.Sig 4recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
1
1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 593
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3577 Remote signal 5 received
(Rem.Sig 5recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
2
1 Yes
3578 Remote signal 6 received
(Rem.Sig 6recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
3
1 Yes
3579 Remote signal 7 received
(Rem.Sig 7recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
4
1 Yes
3580 Remote signal 8 received
(Rem.Sig 8recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
5
1 Yes
3581 Remote signal 9 received
(Rem.Sig 9recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
6
1 Yes
3582 Remote signal 10
received (Rem.Sig10recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
7
1 Yes
3583 Remote signal 11
received (Rem.Sig11recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
8
1 Yes
3584 Remote signal 12
received (Rem.Sig12recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 16
9
1 Yes
3585 Remote signal 13
received (Rem.Sig13recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
0
1 Yes
3586 Remote signal 14
received (Rem.Sig14recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
1
1 Yes
3587 Remote signal 15
received (Rem.Sig15recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
2
1 Yes
3588 Remote signal 16
received (Rem.Sig16recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
3
1 Yes
3589 Remote signal 17
received (Rem.Sig17recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
4
1 Yes
3590 Remote signal 18
received (Rem.Sig18recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
5
1 Yes
Functions, Settings, Information
E.3 Information List
594 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3591 Remote signal 19
received (Rem.Sig19recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
6
1 Yes
3592 Remote signal 20
received (Rem.Sig20recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
7
1 Yes
3593 Remote signal 21
received (Rem.Sig21recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
8
1 Yes
3594 Remote signal 22
received (Rem.Sig22recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 17
9
1 Yes
3595 Remote signal 23
received (Rem.Sig23recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 18
0
1 Yes
3596 Remote signal 24
received (Rem.Sig24recv)
Remote
Signals
OUT On
Of
f
* * LED BO 93 18
1
1 Yes
3603 >BLOCK Distance protec-
tion (>BLOCK Distance)
Dis. General SP * * * LED BI BO
3611 >ENABLE Z1B (with setted
Time Delay) (>ENABLE
Z1B)
Dis. General SP O
N
OF
F
* * LED BI BO 28 11 1 Yes
3613 >ENABLE Z1B instanta-
nous (w/o T-Delay)
(>ENABLE Z1Binst)
Dis. General SP O
N
OF
F
* * LED BI BO 28 13 1 Yes
3617 >BLOCK Z4-Trip (>BLOCK
Z4-Trip)
Dis. General SP O
N
OF
F
* * LED BI BO 28 17 1 Yes
3618 >BLOCK Z5-Trip (>BLOCK
Z5-Trip)
Dis. General SP O
N
OF
F
* * LED BI BO 28 18 1 Yes
3619 >BLOCK Z4 for ph-e loops
(>BLOCK Z4 Ph-E)
Dis. General SP O
N
OF
F
* * LED BI BO 28 19 1 Yes
3620 >BLOCK Z5 for ph-e loops
(>BLOCK Z5 Ph-E)
Dis. General SP O
N
OF
F
* * LED BI BO 28 20 1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 595
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3621 >BLOCK Z6-Trip (>BLOCK
Z6-Trip)
Dis. General SP O
N
OF
F
* * LED BI BO 28 41 1 Yes
3622 >BLOCK Z6 for ph-e loops
(>BLOCK Z6 Ph-E)
Dis. General SP O
N
OF
F
* * LED BI BO 28 42 1 Yes
3651 Distance is switched off
(Dist. OFF)
Dis. General OUT O
N
OF
F
* * LED BO 28 51 1 Yes
3652 Distance is BLOCKED
(Dist. BLOCK)
Dis. General OUT O
N
OF
F
ON
OFF
* LED BO 28 52 1 Yes
3653 Distance is ACTIVE (Dist.
ACTIVE)
Dis. General OUT * * * LED BO 28 53 1 Yes
3654 Setting error K0(Z1) or
Angle K0(Z1)
(Dis.ErrorK0(Z1))
Dis. General OUT O
N
OF
F
* * LED BO
3655 Setting error K0(>Z1) or
Angle K0(>Z1) (DisEr-
rorK0(>Z1))
Dis. General OUT O
N
OF
F
* * LED BO
3671 Distance PICKED UP (Dis.
PICKUP)
Dis. General OUT * OFF * LED BO 28 71 2 Yes
3672 Distance PICKUP L1
(Dis.Pickup L1)
Dis. General OUT * * m LED BO 28 72 2 Yes
3673 Distance PICKUP L2
(Dis.Pickup L2)
Dis. General OUT * * m LED BO 28 73 2 Yes
3674 Distance PICKUP L3
(Dis.Pickup L3)
Dis. General OUT * * m LED BO 28 74 2 Yes
3675 Distance PICKUP Earth
(Dis.Pickup E)
Dis. General OUT * * m LED BO 28 75 2 Yes
3681 Distance Pickup Phase L1
(only) (Dis.Pickup 1pL1)
Dis. General OUT * ON * LED BO 28 81 2 No
3682 Distance Pickup L1E
(Dis.Pickup L1E)
Dis. General OUT * ON * LED BO 28 82 2 No
3683 Distance Pickup Phase L2
(only) (Dis.Pickup 1pL2)
Dis. General OUT * ON * LED BO 28 83 2 No
3684 Distance Pickup L2E
(Dis.Pickup L2E)
Dis. General OUT * ON * LED BO 28 84 2 No
Functions, Settings, Information
E.3 Information List
596 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3685 Distance Pickup L12
(Dis.Pickup L12)
Dis. General OUT * ON * LED BO 28 85 2 No
3686 Distance Pickup L12E
(Dis.Pickup L12E)
Dis. General OUT * ON * LED BO 28 86 2 No
3687 Distance Pickup Phase L3
(only) (Dis.Pickup 1pL3)
Dis. General OUT * ON * LED BO 28 87 2 No
3688 Distance Pickup L3E
(Dis.Pickup L3E)
Dis. General OUT * ON * LED BO 28 88 2 No
3689 Distance Pickup L31
(Dis.Pickup L31)
Dis. General OUT * ON * LED BO 28 89 2 No
3690 Distance Pickup L31E
(Dis.Pickup L31E)
Dis. General OUT * ON * LED BO 28 90 2 No
3691 Distance Pickup L23
(Dis.Pickup L23)
Dis. General OUT * ON * LED BO 28 91 2 No
3692 Distance Pickup L23E
(Dis.Pickup L23E)
Dis. General OUT * ON * LED BO 28 92 2 No
3693 Distance Pickup L123
(Dis.Pickup L123)
Dis. General OUT * ON * LED BO 28 93 2 No
3694 Distance Pickup123E
(Dis.Pickup123E)
Dis. General OUT * ON * LED BO 28 94 2 No
3701 Distance Loop L1E
selected forward
(Dis.Loop L1-E f)
Dis. General OUT * ON
OFF
* LED BO
3702 Distance Loop L2E
selected forward
(Dis.Loop L2-E f)
Dis. General OUT * ON
OFF
* LED BO
3703 Distance Loop L3E
selected forward
(Dis.Loop L3-E f)
Dis. General OUT * ON
OFF
* LED BO
3704 Distance Loop L12
selected forward
(Dis.Loop L1-2 f)
Dis. General OUT * ON
OFF
* LED BO
3705 Distance Loop L23
selected forward
(Dis.Loop L2-3 f)
Dis. General OUT * ON
OFF
* LED BO
3706 Distance Loop L31
selected forward
(Dis.Loop L3-1 f)
Dis. General OUT * ON
OFF
* LED BO
3707 Distance Loop L1E
selected reverse (Dis.Loop
L1-E r)
Dis. General OUT * ON
OFF
* LED BO
3708 Distance Loop L2E
selected reverse (Dis.Loop
L2-E r)
Dis. General OUT * ON
OFF
* LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 597
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3709 Distance Loop L3E
selected reverse (Dis.Loop
L3-E r)
Dis. General OUT * ON
OFF
* LED BO
3710 Distance Loop L12
selected reverse (Dis.Loop
L1-2 r)
Dis. General OUT * ON
OFF
* LED BO
3711 Distance Loop L23
selected reverse (Dis.Loop
L2-3 r)
Dis. General OUT * ON
OFF
* LED BO
3712 Distance Loop L31
selected reverse (Dis.Loop
L3-1 r)
Dis. General OUT * ON
OFF
* LED BO
3713 Distance Loop L1E
selected non-direct.
(Dis.Loop L1E<->)
Dis. General OUT * ON
OFF
* LED BO
3714 Distance Loop L2E
selected non-direct.
(Dis.Loop L2E<->)
Dis. General OUT * ON
OFF
* LED BO
3715 Distance Loop L3E
selected non-direct.
(Dis.Loop L3E<->)
Dis. General OUT * ON
OFF
* LED BO
3716 Distance Loop L12
selected non-direct.
(Dis.Loop L12<->)
Dis. General OUT * ON
OFF
* LED BO
3717 Distance Loop L23
selected non-direct.
(Dis.Loop L23<->)
Dis. General OUT * ON
OFF
* LED BO
3718 Distance Loop L31
selected non-direct.
(Dis.Loop L31<->)
Dis. General OUT * ON
OFF
* LED BO
3719 Distance Pickup
FORWARD (Dis. forward)
Dis. General OUT * * m LED BO 12
8
74 2 No
3720 Distance Pickup REVERSE
(Dis. reverse)
Dis. General OUT * * m LED BO 12
8
75 2 No
3741 Distance Pickup Z1, Loop
L1E (Dis. Z1 L1E)
Dis. General OUT * * * LED BO
3742 Distance Pickup Z1, Loop
L2E (Dis. Z1 L2E)
Dis. General OUT * * * LED BO
3743 Distance Pickup Z1, Loop
L3E (Dis. Z1 L3E)
Dis. General OUT * * * LED BO
3744 Distance Pickup Z1, Loop
L12 (Dis. Z1 L12)
Dis. General OUT * * * LED BO
3745 Distance Pickup Z1, Loop
L23 (Dis. Z1 L23)
Dis. General OUT * * * LED BO
Functions, Settings, Information
E.3 Information List
598 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3746 Distance Pickup Z1, Loop
L31 (Dis. Z1 L31)
Dis. General OUT * * * LED BO
3747 Distance Pickup Z1B, Loop
L1E (Dis. Z1B L1E)
Dis. General OUT * * * LED BO
3748 Distance Pickup Z1B, Loop
L2E (Dis. Z1B L2E)
Dis. General OUT * * * LED BO
3749 Distance Pickup Z1B, Loop
L3E (Dis. Z1B L3E)
Dis. General OUT * * * LED BO
3750 Distance Pickup Z1B, Loop
L12 (Dis. Z1B L12)
Dis. General OUT * * * LED BO
3751 Distance Pickup Z1B, Loop
L23 (Dis. Z1B L23)
Dis. General OUT * * * LED BO
3752 Distance Pickup Z1B, Loop
L31 (Dis. Z1B L31)
Dis. General OUT * * * LED BO
3755 Distance Pickup Z2 (Dis.
Pickup Z2)
Dis. General OUT * * * LED BO
3758 Distance Pickup Z3 (Dis.
Pickup Z3)
Dis. General OUT * * * LED BO
3759 Distance Pickup Z4 (Dis.
Pickup Z4)
Dis. General OUT * * * LED BO
3760 Distance Pickup Z5 (Dis.
Pickup Z5)
Dis. General OUT * * * LED BO
3762 Distance Pickup Z6 (Dis.
Pickup Z6)
Dis. General OUT * * * LED BO
3770 DistanceTime Out T6
(Dis.Time Out T6)
Dis. General OUT * * * LED BO 28 17
6
2 No
3771 DistanceTime Out T1
(Dis.Time Out T1)
Dis. General OUT * * * LED BO 12
8
78 2 No
3774 DistanceTime Out T2
(Dis.Time Out T2)
Dis. General OUT * * * LED BO 12
8
79 2 No
3777 DistanceTime Out T3
(Dis.Time Out T3)
Dis. General OUT * * * LED BO 12
8
80 2 No
3778 DistanceTime Out T4
(Dis.Time Out T4)
Dis. General OUT * * * LED BO 12
8
81 2 No
3779 DistanceTime Out T5
(Dis.Time Out T5)
Dis. General OUT * * * LED BO 12
8
82 2 No
3780 DistanceTime Out T1B
(Dis.TimeOut T1B)
Dis. General OUT * * * LED BO 28 18
0
2 No
3801 Distance protection:
General trip (Dis.Gen.
Trip)
Dis. General OUT * * * LED BO 28 20
1
2 No
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 599
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
3802 Distance TRIP command -
Only Phase L1 (Dis.Trip
1pL1)
Dis. General OUT * ON * LED BO 28 20
2
2 No
3803 Distance TRIP command -
Only Phase L2 (Dis.Trip
1pL2)
Dis. General OUT * ON * LED BO 28 20
3
2 No
3804 Distance TRIP command -
Only Phase L3 (Dis.Trip
1pL3)
Dis. General OUT * ON * LED BO 28 20
4
2 No
3805 Distance TRIP command
Phases L123 (Dis.Trip 3p)
Dis. General OUT * ON * LED BO 28 20
5
2 No
3811 Distance TRIP single-
phase Z1 (Dis.TripZ1/1p)
Dis. General OUT * * * LED BO 28 21
1
2 No
3813 Distance TRIP single-
phase Z1B
(Dis.TripZ1B1p)
Dis. General OUT * * * LED BO 28 21
3
2 No
3816 Distance TRIP single-
phase Z2 (Dis.TripZ2/1p)
Dis. General OUT * * * LED BO 28 21
6
2 No
3817 Distance TRIP 3phase in
Z2 (Dis.TripZ2/3p)
Dis. General OUT * * * LED BO 28 21
7
2 No
3818 Distance TRIP 3phase in
Z3 (Dis.TripZ3/T3)
Dis. General OUT * * * LED BO 28 21
8
2 No
3821 Distance TRIP 3phase in
Z4 (Dis.TRIP 3p. Z4)
Dis. General OUT * * * LED BO 28 20
9
2 No
3822 Distance TRIP 3phase in
Z5 (Dis.TRIP 3p. Z5)
Dis. General OUT * * * LED BO 28 21
0
2 No
3823 DisTRIP 3phase in Z1 with
single-ph Flt. (DisTRIP3p.
Z1sf)
Dis. General OUT * * * LED BO 28 22
4
2 No
3824 DisTRIP 3phase in Z1 with
multi-ph Flt. (DisTRIP3p.
Z1mf)
Dis. General OUT * * * LED BO 28 22
5
2 No
3825 DisTRIP 3phase in Z1B
with single-ph Flt
(DisTRIP3p.Z1Bsf)
Dis. General OUT * * * LED BO 28 24
4
2 No
3826 DisTRIP 3phase in Z1B
with multi-ph Flt.
(DisTRIP3p Z1Bmf)
Dis. General OUT * * * LED BO 28 24
5
2 No
3827 Distance TRIP 3phase in
Z6 (Dis.TRIP 3p. Z6)
Dis. General OUT * * * LED BO 28 43 2 No
3850 DisTRIP Z1B with Telepro-
tection scheme (DisTRIP
Z1B Tel)
Dis. General OUT * * * LED BO 28 25
1
2 No
Functions, Settings, Information
E.3 Information List
600 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4001 >Distance Teleprotection
ON (>Dis.Telep. ON)
Teleprot.
Dist.
SP * * * LED BI BO
4002 >Distance Teleprotection
OFF (>Dis.Telep.OFF)
Teleprot.
Dist.
SP * * * LED BI BO
4003 >Distance Teleprotection
BLOCK (>Dis.Telep. Blk)
Teleprot.
Dist.
SP O
N
OF
F
ON
OFF
* LED BI BO 29 3 1 Yes
4005 >Dist. teleprotection:
Carrier faulty
(>Dis.RecFail)
Teleprot.
Dist.
SP On
Of
f
* * LED BI BO
4006 >Dis.Tele. Carrier RECEP-
TION Channel 1 (>DisTel
Rec.Ch1)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 6 1 Yes
4007 >Dis.Tele.Carrier RECEP-
TION Channel 1,L1
(>Dis.T.RecCh1L1)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 7 1 Yes
4008 >Dis.Tele.Carrier RECEP-
TION Channel 1,L2
(>Dis.T.RecCh1L2)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 8 1 Yes
4009 >Dis.Tele.Carrier RECEP-
TION Channel 1,L3
(>Dis.T.RecCh1L3)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 9 1 Yes
4010 >Dis.Tele. Carrier RECEP-
TION Channel 2
(>Dis.T.Rec.Ch2)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 10 1 Yes
4030 >Dis.Tele. Unblocking:
UNBLOCK Channel 1
(>Dis.T.UB ub 1)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 30 1 Yes
4031 >Dis.Tele. Unblocking:
BLOCK Channel 1
(>Dis.T.UB bl 1)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 31 1 Yes
4032 >Dis.Tele. Unblocking:
UNBLOCK Ch. 1, L1
(>Dis.T.UB ub1L1)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 32 1 Yes
4033 >Dis.Tele. Unblocking:
UNBLOCK Ch. 1, L2
(>Dis.T.UB ub1L2)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 33 1 Yes
4034 >Dis.Tele. Unblocking:
UNBLOCK Ch. 1, L3
(>Dis.T.UB ub1L3)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 34 1 Yes
4035 >Dis.Tele. Unblocking:
UNBLOCK Channel 2
(>Dis.T.UB ub 2)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 35 1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 601
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4036 >Dis.Tele. Unblocking:
BLOCK Channel 2
(>Dis.T.UB bl 2)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 36 1 Yes
4040 >Dis.Tele. BLOCK Echo
Signal (>Dis.T.BlkEcho)
Teleprot.
Dist.
SP On
Of
f
On * LED BI BO 29 40 1 Yes
4050 Dis. Teleprotection
ON/OFF via BI
(Dis.T.on/off BI)
Teleprot.
Dist.
IntS
P
O
N
OF
F
* * LED BO
4051 Teleprotection is switched
ON (Telep. ON)
Device IntS
P
* * * LED BO 12
8
17 1 Yes
4052 Dis. Teleprotection is
switched OFF (Dis.Telep.
OFF)
Teleprot.
Dist.
OUT O
N
OF
F
* * LED BO
4054 Dis. Telep. Carrier signal
received (Dis.T.Carr.rec.)
Teleprot.
Dist.
OUT * * * LED BO 12
8
77 2 No
4055 Dis. Telep. Carrier
CHANNEL FAILURE
(Dis.T.Carr.Fail)
Teleprot.
Dist.
OUT * * * LED BO 12
8
39 1 Yes
4056 Dis. Telep. Carrier SEND
signal (Dis.T.SEND)
Teleprot.
Dist.
OUT On On * LED BO 12
8
76 2 No
4057 Dis. Telep. Carrier SEND
signal, L1 (Dis.T.SEND L1)
Teleprot.
Dist.
OUT * * * LED BO
4058 Dis. Telep. Carrier SEND
signal, L2 (Dis.T.SEND L2)
Teleprot.
Dist.
OUT * * * LED BO
4059 Dis. Telep. Carrier SEND
signal, L3 (Dis.T.SEND L3)
Teleprot.
Dist.
OUT * * * LED BO
4060 Dis.Tele.Blocking: Send
signal with jump
(DisJumpBlocking)
Teleprot.
Dist.
OUT * * * LED BO 29 60 2 No
4068 Dis. Telep. Transient
Blocking (Dis.T.Trans.Blk)
Teleprot.
Dist.
OUT * ON * LED BO 29 68 2 No
4070 Dis. Tele.Blocking: carrier
STOP signal (Dis.T.BL
STOP)
Teleprot.
Dist.
OUT * ON * LED BO 29 70 2 No
4080 Dis. Tele.Unblocking:
FAILURE Channel 1
(Dis.T.UB Fail1)
Teleprot.
Dist.
OUT On
Of
f
* * LED BO 29 80 1 Yes
4081 Dis. Tele.Unblocking:
FAILURE Channel 2
(Dis.T.UB Fail2)
Teleprot.
Dist.
OUT On
Of
f
* * LED BO 29 81 1 Yes
Functions, Settings, Information
E.3 Information List
602 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4082 DisTel Blocking: carrier
STOP signal, L1 (Dis.T.BL
STOPL1)
Teleprot.
Dist.
OUT * * * LED BO
4083 DisTel Blocking: carrier
STOP signal, L2 (Dis.T.BL
STOPL2)
Teleprot.
Dist.
OUT * * * LED BO
4084 DisTel Blocking: carrier
STOP signal, L3 (Dis.T.BL
STOPL3)
Teleprot.
Dist.
OUT * * * LED BO
4085 Dis.Tele.Carrier RECEP-
TION, L1, Device1
(Dis.T.RecL1Dev1)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4086 Dis.Tele.Carrier RECEP-
TION, L2, Device1
(Dis.T.RecL2Dev1)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4087 Dis.Tele.Carrier RECEP-
TION, L3, Device1
(Dis.T.RecL3Dev1)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4088 Dis.Tele.Carrier RECEP-
TION, L1, Device2
(Dis.T.RecL1Dev2)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4089 Dis.Tele.Carrier RECEP-
TION, L2, Device2
(Dis.T.RecL2Dev2)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4090 Dis.Tele.Carrier RECEP-
TION, L3, Device2
(Dis.T.RecL3Dev2)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4091 Dis.Tele.Carrier RECEP-
TION, L1, Device3
(Dis.T.RecL1Dev3)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4092 Dis.Tele.Carrier RECEP-
TION, L2, Device3
(Dis.T.RecL2Dev3)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4093 Dis.Tele.Carrier RECEP-
TION, L3, Device3
(Dis.T.RecL3Dev3)
Teleprot.
Dist.
OUT On
Of
f
On * LED BO
4160 >BLOCK Power Swing
detection (>Pow. Swing
BLK)
Power
Swing
SP O
N
OF
F
ON
OFF
* LED BI BO
4163 Power Swing unstable
(P.Swing unstab.)
Power
Swing
OUT O
N
ON * LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 603
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4164 Power Swing detected
(Power Swing)
Power
Swing
OUT O
N
OF
F
ON
OFF
* LED BO 29 16
4
1 Yes
4166 Power Swing TRIP
command (Pow. Swing
TRIP)
Power
Swing
OUT O
N
ON * LED BO 29 16
6
1 No
4167 Power Swing detected in
L1 (Pow. Swing L1)
Power
Swing
OUT O
N
OF
F
ON
OFF
* LED BO
4168 Power Swing detected in
L2 (Pow. Swing L2)
Power
Swing
OUT O
N
OF
F
ON
OFF
* LED BO
4169 Power Swing detected in
L3 (Pow. Swing L3)
Power
Swing
OUT O
N
OF
F
ON
OFF
* LED BO
4177 Power Swing unstable 2
(P.Swing unst. 2)
Power
Swing
OUT * * * LED BO
4203 >BLOCK Weak Infeed
(>BLOCK Weak Inf)
Weak Infeed SP * * * LED BI BO
4204 >BLOCK delayed Weak
Infeed stage (>BLOCK del.
WI)
Weak Infeed SP O
N
OF
F
ON
OFF
* LED BI BO
4205 >Reception (channel) for
Weak Infeed OK (>WI rec.
OK)
Weak Infeed SP O
N
OF
F
ON
OFF
* LED BI BO
4206 >Receive signal for Weak
Infeed (>WI reception)
Weak Infeed SP O
N
OF
F
ON
OFF
* LED BI BO
4221 Weak Infeed is switched
OFF (WeakInf. OFF)
Weak Infeed OUT O
N
OF
F
* * LED BO 25 21 1 Yes
4222 Weak Infeed is BLOCKED
(Weak Inf. BLOCK)
Weak Infeed OUT O
N
OF
F
ON
OFF
* LED BO 25 22 1 Yes
4223 Weak Infeed is ACTIVE
(Weak Inf ACTIVE)
Weak Infeed OUT * * * LED BO 25 23 1 Yes
Functions, Settings, Information
E.3 Information List
604 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4225 Weak Infeed Zero seq.
current detected (3I0
detected)
Weak Infeed OUT O
N
OF
F
ON
OFF
* LED BO
4226 Weak Infeed Undervoltg.
L1 (WI U L1<)
Weak Infeed OUT O
N
OF
F
ON
OFF
* LED BO
4227 Weak Infeed Undervoltg.
L2 (WI U L2<)
Weak Infeed OUT O
N
OF
F
ON
OFF
* LED BO
4228 Weak Infeed Undervoltg.
L3 (WI U L3<)
Weak Infeed OUT O
N
OF
F
ON
OFF
* LED BO
4229 WI TRIP with zero
sequence current (WI TRIP
3I0)
Weak Infeed OUT * * * LED BO
4231 Weak Infeed PICKED UP
(WeakInf. PICKUP)
Weak Infeed OUT * OFF * LED BO 25 31 2 Yes
4232 Weak Infeed PICKUP L1
(W/I Pickup L1)
Weak Infeed OUT * ON * LED BO
4233 Weak Infeed PICKUP L2
(W/I Pickup L2)
Weak Infeed OUT * ON * LED BO
4234 Weak Infeed PICKUP L3
(W/I Pickup L3)
Weak Infeed OUT * ON * LED BO
4241 Weak Infeed General TRIP
command (WeakInfeed
TRIP)
Weak Infeed OUT * * * LED BO 25 41 2 No
4242 Weak Infeed TRIP
command - Only L1
(Weak TRIP 1p.L1)
Weak Infeed OUT * ON * LED BO 25 42 2 No
4243 Weak Infeed TRIP
command - Only L2
(Weak TRIP 1p.L2)
Weak Infeed OUT * ON * LED BO 25 43 2 No
4244 Weak Infeed TRIP
command - Only L3
(Weak TRIP 1p.L3)
Weak Infeed OUT * ON * LED BO 25 44 2 No
4245 Weak Infeed TRIP
command L123 (Weak
TRIP L123)
Weak Infeed OUT * ON * LED BO 25 45 2 No
4246 ECHO Send SIGNAL
(ECHO SIGNAL)
Weak Infeed OUT O
N
ON * LED BO 25 46 2 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 605
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4247 ECHO Tele.Carrier RECEP-
TION, Device1 (ECHO Rec.
Dev1)
Echo Rec.
ov.PI
OUT O
N
OF
F
ON * LED BO
4248 ECHO Tele.Carrier RECEP-
TION, Device2 (ECHO Rec.
Dev2)
Echo Rec.
ov.PI
OUT O
N
OF
F
ON * LED BO
4249 ECHO Tele.Carrier RECEP-
TION, Device3 (ECHO Rec.
Dev3)
Echo Rec.
ov.PI
OUT O
N
OF
F
ON * LED BO
4253 >BLOCK Instantaneous
SOTF Overcurrent
(>BLOCK SOTF-O/C)
SOTF Over-
curr.
SP * * * LED BI BO
4271 SOTF-O/C is switched OFF
(SOTF-O/C OFF)
SOTF Over-
curr.
OUT O
N
OF
F
* * LED BO 25 71 1 Yes
4272 SOTF-O/C is BLOCKED
(SOTF-O/C BLOCK)
SOTF Over-
curr.
OUT O
N
OF
F
ON
OFF
* LED BO 25 72 1 Yes
4273 SOTF-O/C is ACTIVE
(SOTF-O/C ACTIVE)
SOTF Over-
curr.
OUT * * * LED BO 25 73 1 Yes
4281 SOTF-O/C PICKED UP
(SOTF-O/C PICKUP)
SOTF Over-
curr.
OUT * OFF * LED BO 25 81 2 Yes
4282 SOTF-O/C Pickup L1 (SOF
O/CpickupL1)
SOTF Over-
curr.
OUT * ON * LED BO 25 82 2 Yes
4283 SOTF-O/C Pickup L2 (SOF
O/CpickupL2)
SOTF Over-
curr.
OUT * ON * LED BO 25 83 2 Yes
4284 SOTF-O/C Pickup L3 (SOF
O/CpickupL3)
SOTF Over-
curr.
OUT * ON * LED BO 25 84 2 Yes
4295 SOTF-O/C TRIP command
L123 (SOF O/CtripL123)
SOTF Over-
curr.
OUT * ON * LED BO 25 95 2 No
4403 >BLOCK Direct Transfer
Trip function (>BLOCK
DTT)
DTT Direct
Trip
SP * * * LED BI BO
4412 >Direct Transfer Trip
INPUT Phase L1 (>DTT
Trip L1)
DTT Direct
Trip
SP O
N
OF
F
* * LED BI BO
Functions, Settings, Information
E.3 Information List
606 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
4413 >Direct Transfer Trip
INPUT Phase L2 (>DTT
Trip L2)
DTT Direct
Trip
SP O
N
OF
F
* * LED BI BO
4414 >Direct Transfer Trip
INPUT Phase L3 (>DTT
Trip L3)
DTT Direct
Trip
SP O
N
OF
F
* * LED BI BO
4417 >Direct Transfer Trip
INPUT 3ph L123 (>DTT
Trip L123)
DTT Direct
Trip
SP O
N
OF
F
* * LED BI BO
4421 Direct Transfer Trip is
switched OFF (DTT OFF)
DTT Direct
Trip
OUT O
N
OF
F
* * LED BO 51 21 1 Yes
4422 Direct Transfer Trip is
BLOCKED (DTT BLOCK)
DTT Direct
Trip
OUT O
N
OF
F
ON
OFF
* LED BO 51 22 1 Yes
4432 DTT TRIP command - Only
L1 (DTT TRIP 1p. L1)
DTT Direct
Trip
OUT * ON * LED BO 51 32 2 No
4433 DTT TRIP command - Only
L2 (DTT TRIP 1p. L2)
DTT Direct
Trip
OUT * ON * LED BO 51 33 2 No
4434 DTT TRIP command - Only
L3 (DTT TRIP 1p. L3)
DTT Direct
Trip
OUT * ON * LED BO 51 34 2 No
4435 DTT TRIP command L123
(DTT TRIP L123)
DTT Direct
Trip
OUT * ON * LED BO 51 35 2 No
5203 >BLOCK frequency
protection (>BLOCK
Freq.)
Frequency
Prot.
SP O
N
OF
F
* * LED BI BO 70 17
6
1 Yes
5206 >BLOCK frequency
protection stage f1
(>BLOCK f1)
Frequency
Prot.
SP O
N
OF
F
* * LED BI BO 70 17
7
1 Yes
5207 >BLOCK frequency
protection stage f2
(>BLOCK f2)
Frequency
Prot.
SP O
N
OF
F
* * LED BI BO 70 17
8
1 Yes
5208 >BLOCK frequency
protection stage f3
(>BLOCK f3)
Frequency
Prot.
SP O
N
OF
F
* * LED BI BO 70 17
9
1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 607
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
5209 >BLOCK frequency
protection stage f4
(>BLOCK f4)
Frequency
Prot.
SP O
N
OF
F
* * LED BI BO 70 18
0
1 Yes
5211 Frequency protection is
switched OFF (Freq. OFF)
Frequency
Prot.
OUT O
N
OF
F
* * LED BO 70 18
1
1 Yes
5212 Frequency protection is
BLOCKED (Freq.
BLOCKED)
Frequency
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 70 18
2
1 Yes
5213 Frequency protection is
ACTIVE (Freq. ACTIVE)
Frequency
Prot.
OUT O
N
OF
F
* * LED BO 70 18
3
1 Yes
5215 Frequency protection
undervoltage Blk (Freq
UnderV Blk)
Frequency
Prot.
OUT On
Of
f
On
Off
* LED BO 70 23
8
1 Yes
5232 Frequency protection: f1
picked up (f1 picked up)
Frequency
Prot.
OUT * ON
OFF
* LED BO 70 23
0
2 Yes
5233 Frequency protection: f2
picked up (f2 picked up)
Frequency
Prot.
OUT * ON
OFF
* LED BO 70 23
1
2 Yes
5234 Frequency protection: f3
picked up (f3 picked up)
Frequency
Prot.
OUT * ON
OFF
* LED BO 70 23
2
2 Yes
5235 Frequency protection: f4
picked up (f4 picked up)
Frequency
Prot.
OUT * ON
OFF
* LED BO 70 23
3
2 Yes
5236 Frequency protection: f1
TRIP (f1 TRIP)
Frequency
Prot.
OUT * ON * LED BO 70 23
4
2 Yes
5237 Frequency protection: f2
TRIP (f2 TRIP)
Frequency
Prot.
OUT * ON * LED BO 70 23
5
2 Yes
5238 Frequency protection: f3
TRIP (f3 TRIP)
Frequency
Prot.
OUT * ON * LED BO 70 23
6
2 Yes
5239 Frequency protection: f4
TRIP (f4 TRIP)
Frequency
Prot.
OUT * ON * LED BO 70 23
7
2 Yes
5240 Frequency protection:
TimeOut Stage f1 (Time
Out f1)
Frequency
Prot.
OUT * * * LED BO
5241 Frequency protection:
TimeOut Stage f2 (Time
Out f2)
Frequency
Prot.
OUT * * * LED BO
5242 Frequency protection:
TimeOut Stage f3 (Time
Out f3)
Frequency
Prot.
OUT * * * LED BO
Functions, Settings, Information
E.3 Information List
608 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
5243 Frequency protection:
TimeOut Stage f4 (Time
Out f4)
Frequency
Prot.
OUT * * * LED BO
6854 >Trip circuit superv. 1:
Trip Relay (>TripC1
TripRel)
Trip-
Circ.Superv
SP O
N
OF
F
* * LED BI BO
6855 >Trip circuit superv. 1:
Breaker Relay (>TripC1
Bkr.Rel)
Trip-
Circ.Superv
SP O
N
OF
F
* * LED BI BO
6856 >Trip circuit superv. 2:
Trip Relay (>TripC2
TripRel)
Trip-
Circ.Superv
SP O
N
OF
F
* * LED BI BO
6857 >Trip circuit superv. 2:
Breaker Relay (>TripC2
Bkr.Rel)
Trip-
Circ.Superv
SP O
N
OF
F
* * LED BI BO
6858 >Trip circuit superv. 3:
Trip Relay (>TripC3
TripRel)
Trip-
Circ.Superv
SP O
N
OF
F
* * LED BI BO
6859 >Trip circuit superv. 3:
Breaker Relay (>TripC3
Bkr.Rel)
Trip-
Circ.Superv
SP O
N
OF
F
* * LED BI BO
6861 Trip circuit supervision
OFF (TripC OFF)
Trip-
Circ.Superv
OUT O
N
OF
F
* * LED BO
6865 Failure Trip Circuit (FAIL:
Trip cir.)
Trip-
Circ.Superv
OUT O
N
OF
F
* * LED BO 12
8
36 1 Yes
6866 TripC1 blocked: Binary
input is not set (TripC1
ProgFAIL)
Trip-
Circ.Superv
OUT O
N
OF
F
* * LED BO
6867 TripC2 blocked: Binary
input is not set (TripC2
ProgFAIL)
Trip-
Circ.Superv
OUT O
N
OF
F
* * LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 609
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
6868 TripC3 blocked: Binary
input is not set (TripC3
ProgFAIL)
Trip-
Circ.Superv
OUT O
N
OF
F
* * LED BO
7104 >BLOCK Backup OverCur-
rent I>> (>BLOCK O/C I>>)
Back-Up O/C SP O
N
OF
F
* * LED BI BO 64 4 1 Yes
7105 >BLOCK Backup OverCur-
rent I> (>BLOCK O/C I>)
Back-Up O/C SP O
N
OF
F
* * LED BI BO 64 5 1 Yes
7106 >BLOCK Backup OverCur-
rent Ip (>BLOCK O/C Ip)
Back-Up O/C SP O
N
OF
F
* * LED BI BO 64 6 1 Yes
7110 >Backup OverCurrent
InstantaneousTrip (>O/C
InstTRIP)
Back-Up O/C SP O
N
OF
F
ON
OFF
* LED BI BO 64 10 1 Yes
7130 >BLOCK I-STUB (>BLOCK
I-STUB)
Back-Up O/C SP O
N
OF
F
* * LED BI BO 64 30 1 Yes
7131 >Enable I-STUB-Bus func-
tion (>I-STUB ENABLE)
Back-Up O/C SP O
N
OF
F
ON
OFF
* LED BI BO 64 31 1 Yes
7151 Backup O/C is switched
OFF (O/C OFF)
Back-Up O/C OUT O
N
OF
F
* * LED BO 64 51 1 Yes
7152 Backup O/C is BLOCKED
(O/C BLOCK)
Back-Up O/C OUT O
N
OF
F
ON
OFF
* LED BO 64 52 1 Yes
7153 Backup O/C is ACTIVE (O/C
ACTIVE)
Back-Up O/C OUT * * * LED BO 64 53 1 Yes
7161 Backup O/C PICKED UP
(O/C PICKUP)
Back-Up O/C OUT * OFF m LED BO 64 61 2 Yes
7162 Backup O/C PICKUP L1
(O/C Pickup L1)
Back-Up O/C OUT * ON * LED BO 64 62 2 Yes
7163 Backup O/C PICKUP L2
(O/C Pickup L2)
Back-Up O/C OUT * ON * LED BO 64 63 2 Yes
Functions, Settings, Information
E.3 Information List
610 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
7164 Backup O/C PICKUP L3
(O/C Pickup L3)
Back-Up O/C OUT * ON * LED BO 64 64 2 Yes
7165 Backup O/C PICKUP EARTH
(O/C Pickup E)
Back-Up O/C OUT * ON * LED BO 64 65 2 Yes
7171 Backup O/C Pickup - Only
EARTH (O/C PU only E)
Back-Up O/C OUT * ON * LED BO 64 71 2 No
7172 Backup O/C Pickup - Only
L1 (O/C PU 1p. L1)
Back-Up O/C OUT * ON * LED BO 64 72 2 No
7173 Backup O/C Pickup L1E
(O/C Pickup L1E)
Back-Up O/C OUT * ON * LED BO 64 73 2 No
7174 Backup O/C Pickup - Only
L2 (O/C PU 1p. L2)
Back-Up O/C OUT * ON * LED BO 64 74 2 No
7175 Backup O/C Pickup L2E
(O/C Pickup L2E)
Back-Up O/C OUT * ON * LED BO 64 75 2 No
7176 Backup O/C Pickup L12
(O/C Pickup L12)
Back-Up O/C OUT * ON * LED BO 64 76 2 No
7177 Backup O/C Pickup L12E
(O/C Pickup L12E)
Back-Up O/C OUT * ON * LED BO 64 77 2 No
7178 Backup O/C Pickup - Only
L3 (O/C PU 1p. L3)
Back-Up O/C OUT * ON * LED BO 64 78 2 No
7179 Backup O/C Pickup L3E
(O/C Pickup L3E)
Back-Up O/C OUT * ON * LED BO 64 79 2 No
7180 Backup O/C Pickup L31
(O/C Pickup L31)
Back-Up O/C OUT * ON * LED BO 64 80 2 No
7181 Backup O/C Pickup L31E
(O/C Pickup L31E)
Back-Up O/C OUT * ON * LED BO 64 81 2 No
7182 Backup O/C Pickup L23
(O/C Pickup L23)
Back-Up O/C OUT * ON * LED BO 64 82 2 No
7183 Backup O/C Pickup L23E
(O/C Pickup L23E)
Back-Up O/C OUT * ON * LED BO 64 83 2 No
7184 Backup O/C Pickup L123
(O/C Pickup L123)
Back-Up O/C OUT * ON * LED BO 64 84 2 No
7185 Backup O/C Pickup L123E
(O/C PickupL123E)
Back-Up O/C OUT * ON * LED BO 64 85 2 No
7191 Backup O/C Pickup I>>
(O/C PICKUP I>>)
Back-Up O/C OUT * ON * LED BO 64 91 2 Yes
7192 Backup O/C Pickup I> (O/C
PICKUP I>)
Back-Up O/C OUT * ON * LED BO 64 92 2 Yes
7193 Backup O/C Pickup Ip (O/C
PICKUP Ip)
Back-Up O/C OUT * ON * LED BO 64 93 2 Yes
7201 O/C I-STUB Pickup (I-STUB
PICKUP)
Back-Up O/C OUT * ON
OFF
* LED BO 64 10
1
2 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 611
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
7211 Backup O/C General TRIP
command (O/C TRIP)
Back-Up O/C OUT * * * LED BO 12
8
72 2 No
7212 Backup O/C TRIP - Only L1
(O/C TRIP 1p.L1)
Back-Up O/C OUT * ON * LED BO 64 11
2
2 No
7213 Backup O/C TRIP - Only L2
(O/C TRIP 1p.L2)
Back-Up O/C OUT * ON * LED BO 64 11
3
2 No
7214 Backup O/C TRIP - Only L3
(O/C TRIP 1p.L3)
Back-Up O/C OUT * ON * LED BO 64 11
4
2 No
7215 Backup O/C TRIP Phases
L123 (O/C TRIP L123)
Back-Up O/C OUT * ON * LED BO 64 11
5
2 No
7221 Backup O/C TRIP I>> (O/C
TRIP I>>)
Back-Up O/C OUT * ON * LED BO 64 12
1
2 No
7222 Backup O/C TRIP I> (O/C
TRIP I>)
Back-Up O/C OUT * ON * LED BO 64 12
2
2 No
7223 Backup O/C TRIP Ip (O/C
TRIP Ip)
Back-Up O/C OUT * ON * LED BO 64 12
3
2 No
7235 O/C I-STUB TRIP (I-STUB
TRIP)
Back-Up O/C OUT * ON * LED BO 64 13
5
2 No
7325 CB1-TEST TRIP command -
Only L1 (CB1-TESTtrip L1)
Testing OUT O
N
OF
F
* * LED BO 15
3
25 1 Yes
7326 CB1-TEST TRIP command -
Only L2 (CB1-TESTtrip L2)
Testing OUT O
N
OF
F
* * LED BO 15
3
26 1 Yes
7327 CB1-TEST TRIP command -
Only L3 (CB1-TESTtrip L3)
Testing OUT O
N
OF
F
* * LED BO 15
3
27 1 Yes
7328 CB1-TEST TRIP command
L123 (CB1-TESTtrip123)
Testing OUT O
N
OF
F
* * LED BO 15
3
28 1 Yes
7329 CB1-TEST CLOSE
command (CB1-TEST
close)
Testing OUT O
N
OF
F
* * LED BO 15
3
29 1 Yes
7345 CB-TEST is in progress
(CB-TEST running)
Testing OUT O
N
OF
F
* * LED BO 15
3
45 1 Yes
Functions, Settings, Information
E.3 Information List
612 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
7346 CB-TEST canceled due to
Power Sys. Fault (CB-
TSTstop FLT.)
Testing OUT
_Ev
O
N
*
7347 CB-TEST canceled due to
CB already OPEN (CB-
TSTstop OPEN)
Testing OUT
_Ev
O
N
*
7348 CB-TEST canceled due to
CB was NOT READY (CB-
TSTstop NOTr)
Testing OUT
_Ev
O
N
*
7349 CB-TEST canceled due to
CB stayed CLOSED (CB-
TSTstop CLOS)
Testing OUT
_Ev
O
N
*
7350 CB-TEST was successful
(CB-TST .OK.)
Testing OUT
_Ev
O
N
*
10201 >BLOCK Uph-e>(>) Over-
volt. (phase-earth) (>Uph-
e>(>) BLK)
Voltage
Prot.
SP * * * LED BI BO
10202 >BLOCK Uph-ph>(>)
Overvolt (phase-phase)
(>Uph-ph>(>) BLK)
Voltage
Prot.
SP * * * LED BI BO
10203 >BLOCK 3U0>(>) Over-
volt. (zero sequence)
(>3U0>(>) BLK)
Voltage
Prot.
SP * * * LED BI BO
10204 >BLOCK U1>(>) Overvolt.
(positive seq.) (>U1>(>)
BLK)
Voltage
Prot.
SP * * * LED BI BO
10205 >BLOCK U2>(>) Overvolt.
(negative seq.) (>U2>(>)
BLK)
Voltage
Prot.
SP * * * LED BI BO
10206 >BLOCK Uph-e<(<)
Undervolt (phase-earth)
(>Uph-e<(<) BLK)
Voltage
Prot.
SP * * * LED BI BO
10207 >BLOCK Uphph<(<)
Undervolt (phase-phase)
(>Uphph<(<) BLK)
Voltage
Prot.
SP * * * LED BI BO
10208 >BLOCK U1<(<) Undervolt
(positive seq.) (>U1<(<)
BLK)
Voltage
Prot.
SP * * * LED BI BO
10215 Uph-e>(>) Overvolt. is
switched OFF (Uph-e>(>)
OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 15 1 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 613
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
10216 Uph-e>(>) Overvolt. is
BLOCKED (Uph-e>(>) BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 16 1 Yes
10217 Uph-ph>(>) Overvolt. is
switched OFF (Uph-
ph>(>) OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 17 1 Yes
10218 Uph-ph>(>) Overvolt. is
BLOCKED (Uph-ph>(>)
BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 18 1 Yes
10219 3U0>(>) Overvolt. is
switched OFF (3U0>(>)
OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 19 1 Yes
10220 3U0>(>) Overvolt. is
BLOCKED (3U0>(>) BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 20 1 Yes
10221 U1>(>) Overvolt. is
switched OFF (U1>(>)
OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 21 1 Yes
10222 U1>(>) Overvolt. is
BLOCKED (U1>(>) BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 22 1 Yes
10223 U2>(>) Overvolt. is
switched OFF (U2>(>)
OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 23 1 Yes
10224 U2>(>) Overvolt. is
BLOCKED (U2>(>) BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 24 1 Yes
10225 Uph-e<(<) Undervolt. is
switched OFF (Uph-e<(<)
OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 25 1 Yes
10226 Uph-e<(<) Undervolt. is
BLOCKED (Uph-e<(<) BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 26 1 Yes
Functions, Settings, Information
E.3 Information List
614 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
10227 Uph-ph<(<) Undervolt. is
switched OFF (Uph-
ph<(<) OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 27 1 Yes
10228 Uphph<(<) Undervolt. is
BLOCKED (Uph-ph<(<)
BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 28 1 Yes
10229 U1<(<) Undervolt. is
switched OFF (U1<(<)
OFF)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 29 1 Yes
10230 U1<(<) Undervolt. is
BLOCKED (U1<(<) BLK)
Voltage
Prot.
OUT O
N
OF
F
ON
OFF
* LED BO 73 30 1 Yes
10231 Over-/Under-Voltage
protection is ACTIVE
(U</> ACTIVE)
Voltage
Prot.
OUT O
N
OF
F
* * LED BO 73 31 1 Yes
10240 Uph-e> Pickup (Uph-e>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 40 2 Yes
10241 Uph-e>> Pickup (Uph-e>>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 41 2 Yes
10242 Uph-e>(>) Pickup L1
(Uph-e>(>) PU L1)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 42 2 Yes
10243 Uph-e>(>) Pickup L2
(Uph-e>(>) PU L2)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 43 2 Yes
10244 Uph-e>(>) Pickup L3
(Uph-e>(>) PU L3)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 44 2 Yes
10245 Uph-e> TimeOut (Uph-e>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10246 Uph-e>> TimeOut (Uph-
e>> TimeOut)
Voltage
Prot.
OUT * * * LED BO
10247 Uph-e>(>) TRIP command
(Uph-e>(>) TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 47 2 Yes
10248 Uph-e> Pickup L1 (Uph-e>
PU L1)
Voltage
Prot.
OUT * * * LED BO 73 13
3
2 Yes
10249 Uph-e> Pickup L2 (Uph-e>
PU L2)
Voltage
Prot.
OUT * * * LED BO 73 13
4
2 Yes
10250 Uph-e> Pickup L3 (Uph-e>
PU L3)
Voltage
Prot.
OUT * * * LED BO 73 13
5
2 Yes
10251 Uph-e>> Pickup L1 (Uph-
e>> PU L1)
Voltage
Prot.
OUT * * * LED BO 73 13
6
2 Yes
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 615
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
10252 Uph-e>> Pickup L2 (Uph-
e>> PU L2)
Voltage
Prot.
OUT * * * LED BO 73 13
7
2 Yes
10253 Uph-e>> Pickup L3 (Uph-
e>> PU L3)
Voltage
Prot.
OUT * * * LED BO 73 13
8
2 Yes
10255 Uph-ph> Pickup (Uphph>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 55 2 Yes
10256 Uph-ph>> Pickup
(Uphph>> Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 56 2 Yes
10257 Uph-ph>(>) Pickup L1-L2
(Uphph>(>)PU L12)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 57 2 Yes
10258 Uph-ph>(>) Pickup L2-L3
(Uphph>(>)PU L23)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 58 2 Yes
10259 Uph-ph>(>) Pickup L3-L1
(Uphph>(>)PU L31)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 59 2 Yes
10260 Uph-ph> TimeOut
(Uphph> TimeOut)
Voltage
Prot.
OUT * * * LED BO
10261 Uph-ph>> TimeOut
(Uphph>> TimeOut)
Voltage
Prot.
OUT * * * LED BO
10262 Uph-ph>(>) TRIP
command (Uphph>(>)
TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 62 2 Yes
10263 Uph-ph> Pickup L1-L2
(Uphph> PU L12)
Voltage
Prot.
OUT * * * LED BO 73 13
9
2 Yes
10264 Uph-ph> Pickup L2-L3
(Uphph> PU L23)
Voltage
Prot.
OUT * * * LED BO 73 14
0
2 Yes
10265 Uph-ph> Pickup L3-L1
(Uphph> PU L31)
Voltage
Prot.
OUT * * * LED BO 73 14
1
2 Yes
10266 Uph-ph>> Pickup L1-L2
(Uphph>> PU L12)
Voltage
Prot.
OUT * * * LED BO 73 14
2
2 Yes
10267 Uph-ph>> Pickup L2-L3
(Uphph>> PU L23)
Voltage
Prot.
OUT * * * LED BO 73 14
3
2 Yes
10268 Uph-ph>> Pickup L3-L1
(Uphph>> PU L31)
Voltage
Prot.
OUT * * * LED BO 73 14
4
2 Yes
10270 3U0> Pickup (3U0>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 70 2 Yes
10271 3U0>> Pickup (3U0>>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 71 2 Yes
10272 3U0> TimeOut (3U0>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10273 3U0>> TimeOut (3U0>>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10274 3U0>(>) TRIP command
(3U0>(>) TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 74 2 Yes
Functions, Settings, Information
E.3 Information List
616 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
10280 U1> Pickup (U1> Pickup) Voltage
Prot.
OUT * ON
OFF
* LED BO 73 80 2 Yes
10281 U1>> Pickup (U1>>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 81 2 Yes
10282 U1> TimeOut (U1>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10283 U1>> TimeOut (U1>>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10284 U1>(>) TRIP command
(U1>(>) TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 84 2 Yes
10290 U2> Pickup (U2> Pickup) Voltage
Prot.
OUT * ON
OFF
* LED BO 73 90 2 Yes
10291 U2>> Pickup (U2>>
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 91 2 Yes
10292 U2> TimeOut (U2>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10293 U2>> TimeOut (U2>>
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10294 U2>(>) TRIP command
(U2>(>) TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 94 2 Yes
10300 U1< Pickup (U1< Pickup) Voltage
Prot.
OUT * ON
OFF
* LED BO 73 10
0
2 Yes
10301 U1<< Pickup (U1<<
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 10
1
2 Yes
10302 U1< TimeOut (U1<
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10303 U1<< TimeOut (U1<<
TimeOut)
Voltage
Prot.
OUT * * * LED BO
10304 U1<(<) TRIP command
(U1<(<) TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 10
4
2 Yes
10310 Uph-e< Pickup (Uph-e<
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 11
0
2 Yes
10311 Uph-e<< Pickup (Uph-e<<
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 11
1
2 Yes
10312 Uph-e<(<) Pickup L1
(Uph-e<(<) PU L1)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 11
2
2 Yes
10313 Uph-e<(<) Pickup L2
(Uph-e<(<) PU L2)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 11
3
2 Yes
10314 Uph-e<(<) Pickup L3
(Uph-e<(<) PU L3)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 11
4
2 Yes
10315 Uph-e< TimeOut (Uph-e<
TimeOut)
Voltage
Prot.
OUT * * * LED BO
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 617
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
10316 Uph-e<< TimeOut (Uph-
e<< TimeOut)
Voltage
Prot.
OUT * * * LED BO
10317 Uph-e<(<) TRIP command
(Uph-e<(<) TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 11
7
2 Yes
10318 Uph-e< Pickup L1 (Uph-e<
PU L1)
Voltage
Prot.
OUT * * * LED BO 73 14
5
2 Yes
10319 Uph-e< Pickup L2 (Uph-e<
PU L2)
Voltage
Prot.
OUT * * * LED BO 73 14
6
2 Yes
10320 Uph-e< Pickup L3 (Uph-e<
PU L3)
Voltage
Prot.
OUT * * * LED BO 73 14
7
2 Yes
10321 Uph-e<< Pickup L1 (Uph-
e<< PU L1)
Voltage
Prot.
OUT * * * LED BO 73 14
8
2 Yes
10322 Uph-e<< Pickup L2 (Uph-
e<< PU L2)
Voltage
Prot.
OUT * * * LED BO 73 14
9
2 Yes
10323 Uph-e<< Pickup L3 (Uph-
e<< PU L3)
Voltage
Prot.
OUT * * * LED BO 73 15
0
2 Yes
10325 Uph-ph< Pickup (Uph-ph<
Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 12
5
2 Yes
10326 Uph-ph<< Pickup (Uph-
ph<< Pickup)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 12
6
2 Yes
10327 Uphph<(<) Pickup L1-L2
(Uphph<(<)PU L12)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 12
7
2 Yes
10328 Uphph<(<) Pickup L2-L3
(Uphph<(<)PU L23)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 12
8
2 Yes
10329 Uphph<(<) Pickup L3-L1
(Uphph<(<)PU L31)
Voltage
Prot.
OUT * ON
OFF
* LED BO 73 12
9
2 Yes
10330 Uphph< TimeOut
(Uphph< TimeOut)
Voltage
Prot.
OUT * * * LED BO
10331 Uphph<< TimeOut
(Uphph<< TimeOut)
Voltage
Prot.
OUT * * * LED BO
10332 Uphph<(<) TRIP
command (Uphph<(<)
TRIP)
Voltage
Prot.
OUT * ON * LED BO 73 13
2
2 Yes
10333 Uph-ph< Pickup L1-L2
(Uphph< PU L12)
Voltage
Prot.
OUT * * * LED BO 73 15
1
2 Yes
10334 Uph-ph< Pickup L2-L3
(Uphph< PU L23)
Voltage
Prot.
OUT * * * LED BO 73 15
2
2 Yes
10335 Uph-ph< Pickup L3-L1
(Uphph< PU L31)
Voltage
Prot.
OUT * * * LED BO 73 15
3
2 Yes
10336 Uph-ph<< Pickup L1-L2
(Uphph<< PU L12)
Voltage
Prot.
OUT * * * LED BO 73 15
4
2 Yes
10337 Uph-ph<< Pickup L2-L3
(Uphph<< PU L23)
Voltage
Prot.
OUT * * * LED BO 73 15
5
2 Yes
Functions, Settings, Information
E.3 Information List
618 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
No. Description Function Typ
e of
Info
rma
tion
Log Buffers Configurable in Matrix IEC 60870-5-103
Event Log ON/OFF
Trip (Fault) Log ON/OFF
Ground Fault Log ON/OFF
Marked in Oscill. Record
LED
Binary Input
Function Key
Relay
Chatter Suppression
Type
information number
Data Unit
General Interrogation
10338 Uph-ph<< Pickup L3-L1
(Uphph<< PU L31)
Voltage
Prot.
OUT * * * LED BO 73 15
6
2 Yes
14080 E/F 3I0>>> is blocked (E/F
3I0>>>BLOCK)
Earth Fault
O/C
OUT O
N
OF
F
ON
OFF
* LED BO
14081 E/F 3I0>> is blocked (E/F
3I0>> BLOCK)
Earth Fault
O/C
OUT O
N
OF
F
ON
OFF
* LED BO
14082 E/F 3I0> is blocked (E/F
3I0> BLOCK)
Earth Fault
O/C
OUT O
N
OF
F
ON
OFF
* LED BO
14083 E/F 3I0p is blocked (E/F
3I0p BLOCK)
Earth Fault
O/C
OUT O
N
OF
F
ON
OFF
* LED BO
30053 Fault recording is running
(Fault rec. run.)
Osc. Fault
Rec.
OUT * * * LED BO
31000 Q0 operationcounter=
(Q0 OpCnt=)
Control
Device
VI
31001 Q1 operationcounter=
(Q1 OpCnt=)
Control
Device
VI
31002 Q2 operationcounter=
(Q2 OpCnt=)
Control
Device
VI
31008 Q8 operationcounter=
(Q8 OpCnt=)
Control
Device
VI
31009 Q9 operationcounter=
(Q9 OpCnt=)
Control
Device
VI
Functions, Settings, Information
E.3 Information List
SIPROTEC 4, 7SA522, Manual 619
C53000-G1176-C155-9, Edition 05.2016
Group Alarms
Nr. Bedeutung Nr. Bedeutung
140 Stör-Sammelmel. 144
181
192
194
Störung 5V
Störung Messw.
IN(1/5A) falsch
IE-Wdl. falsch
160 Warn-Sammelmel. 162
163
165
167
168
169
170
171
177
183
184
185
186
187
188
189
190
191
193
361
3654
3655
Störung ΣI
Störung Isymm
Störung ΣUphe
Störung Usymm
Störung Umess
Fuse-Failure
FFM unverzögert
Stör. Ph-Folge
Stör Batterie
Störung BG1
Störung BG2
Störung BG3
Störung BG4
Störung BG5
Störung BG6
Störung BG7
Störung BG0
Stör. Offset
Stör.Abgleichw.
>U-Wdl.-Aut.
Dis Feh.K0(Z1)
Dis Feh.K0(>Z1)
161 Messw.-Überw.I 162
163
Störung ΣI
Störung Isymm
164 Messw.-Überw.U 165
167
168
Störung ΣUphe
Störung Usymm
Störung Umess
E.4
Functions, Settings, Information
E.4 Group Alarms
620 SIPROTEC 4, 7SA522, Manual
C53000-G1176-C155-9, Edition 05.2016
Measured Values
No. Description Function IEC 60870-5-103 Configurable in
Matrix
Type
information number
Compatibility
Data Unit
Position
CFC
Control Display
Default Display
- Upper setting limit for IL1dmd
(IL1dmd>)
Set Points(MV) - - - - - CFC CD DD
- Upper setting limit for IL2dmd
(IL2dmd>)
Set Points(MV) - - - - - CFC CD DD
- Upper setting limit for IL3dmd
(IL3dmd>)
Set Points(MV) - - - - - CFC CD DD
- Upper setting limit for I1dmd
(I1dmd>)
Set Points(MV) - - - - - CFC CD DD
- Upper setting limit for Pdmd (|
Pdmd|>)
Set Points(MV) - - - - - CFC CD DD
- Upper setting limit for Qdmd (|
Qdmd|>)
Set Points(MV) - - - - - CFC CD DD
- Upper setting limit for Sdmd
(Sdmd>)
Set Points(MV) - - - - - CFC CD DD
- Lower setting limit for Power
Factor (PF<)
Set Points(MV) - - - - - CFC CD DD
601 I L1 (IL1 =) Measurement 128 148 Yes 9 1 CFC CD DD
134 129 No 9 1
602 I L2 (IL2 =) Measurement 128 148 Yes 9 2 CFC CD DD
134 129 No 9 2
603 I L3 (IL3 =) Measurement 128 148 Yes 9 3 CFC CD DD
134 129 No 9 3
610 3I0 (zero sequence) (3I0 =) Measurement 134 129 No 9 14 CFC CD DD
611 3I0sen (sensitive zero sequence)
(3I0sen=)
Measurement 134 118 No 9 3 CFC CD DD
612 IY (star point of transformer) (IY =) Measurement - - - - - CFC CD DD
613 3I0par (parallel line neutral)
(3I0par=)
Measurement - - - - - CFC CD DD
619 I1 (positive sequence) (I1 =) Measurement - - - - - CFC CD DD
620 I2 (negative sequence) (I2 =) Measurement - - - - - CFC CD DD
621 U L1-E (UL1E=) Measurement 128 148 Yes 9 4 CFC CD DD
134 129 No 9 4
622 U L2-E (UL2E=) Measurement 128 148 Yes 9 5 CFC CD DD
134 129 No 9 5
623 U L3-E (UL3E=) Measurement 128 148 Yes 9 6 CFC CD DD
134 129 No 9 6
624 U L12 (UL12=) Measurement 134 129 No 9 10 CFC CD DD
625 U L23 (UL23=) Measurement 134 129 No 9 11 CFC CD DD
626 U L31 (UL31=) Measurement 134 129 No 9 12 CFC CD DD
E.5
Functions, Settings, Information
E.5 Measured Values
SIPROTEC 4, 7SA522, Manual 621
C53000-G1176-C155-9, Edition 05.2016
No. Description Function IEC 60870-5-103 Configurable in
Matrix
Type
information number
Compatibility
Data Unit
Position
CFC
Control Display
Default Display
627 Uen (Uen =) Measurement - - - - - CFC CD DD
631 3U0 (zero sequence) (3U0 =) Measurement 134 118 No 9 1 CFC CD DD
632 Measured value Usy2 (Usy2=) Measurement - - - - - CFC CD DD
633 Ux (separate VT) (Ux =) Measurement - - - - - CFC CD DD
634 U1 (positive sequence) (U1 =) Measurement - - - - - CFC CD DD
635 U2 (negative sequence) (U2 =) Measurement - - - - - CFC CD DD
636 Measured value U-diff (Usy1-
Usy2) (Udiff =)
Measurement 130 1 No 9 2 CFC CD DD
637 Measured value Usy1 (Usy1=) Measurement 130 1 No 9 3 CFC CD DD
638 Measured value Usy2 (Usy2=) Measurement 130 1 No 9 1 CFC CD DD
641 P (active power) (P =) Measurement 128 148 Yes 9 7 CFC CD DD
134 129 No 9 7
642 Q (reactive power) (Q =) Measurement 128 148 Yes 9 8 CFC CD DD
134 129 No 9 8
643 Power Factor (PF =) Measurement 134 129 No 9 13 CFC CD DD
644 Frequency (Freq=) Measurement 128 148 Yes 9 9 CFC CD DD
134 129 No 9 9
645 S (apparent power) (S =) Measurement - - - - - CFC CD DD
646 Frequency fsy2 (F-sy2 =) Measurement 130 1 No 9 4 CFC CD DD
647 Frequency difference (F-diff=) Measurement 130 1 No 9 5 CFC CD DD
648 Angle difference (φ-diff=) Measurement 130 1 No 9 6 CFC CD DD
649 Frequency fsy1 (F-sy1 =) Measurement 130 1 No 9 7 CFC CD DD
679 U1co (positive sequence,
compounding) (U1co=)
Measurement - - - - - CFC CD DD
684 U0 (zero sequence) (U0 =) Measurement 134 118 No 9 2 CFC CD DD
833 I1 (positive sequence) Demand
(I1dmd =)
Demand meter - - - - - CFC CD DD
834 Active Power Demand (Pdmd =) Demand meter - - - - - CFC CD DD
835 Reactive Power Demand (Qdmd =) Demand meter - - - - - CFC CD DD
836 Apparent Power Demand (Sdmd
=)
Demand meter - - - - - CFC CD DD
837 I L1 Demand Minimum (IL1d Min) Min/Max meter - - - - - CFC CD DD
838 I L1 Demand Maximum (IL1d Max) Min/Max meter - - - - - CFC CD DD
839 I L2 Demand Minimum (IL2d Min) Min/Max meter - - - - - CFC CD DD
840 I L2 Demand Maximum (IL2d Max) Min/Max meter - - - - - CFC CD DD
841 I L3 Demand Minimum (IL3d Min) Min/Max meter - - - - - CFC CD DD
842 I L3 Demand Maximum (IL3d Max) Min/Max meter - - - - - CFC CD DD
843 I1 (positive sequence) Demand
Minimum (I1dmdMin)
Min/Max meter - - - - - CFC CD DD
844 I1 (positive sequence) Demand
Maximum (I1dmdMax)
Min/Max meter - - - - - CFC CD DD
Functions, Settings, Information
E.5 Measured Values
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No. Description Function IEC 60870-5-103 Configurable in
Matrix
Type
information number
Compatibility
Data Unit
Position
CFC
Control Display
Default Display
845 Active Power Demand Minimum
(PdMin=)
Min/Max meter - - - - - CFC CD DD
846 Active Power Demand Maximum
(PdMax=)
Min/Max meter - - - - - CFC CD DD
847 Reactive Power Demand Minimum
(QdMin=)
Min/Max meter - - - - - CFC CD DD
848 Reactive Power Demand
Maximum (QdMax=)
Min/Max meter - - - - - CFC CD DD
849 Apparent Power Demand
Minimum (SdMin=)
Min/Max meter - - - - - CFC CD DD
850 Apparent Power Demand
Maximum (SdMax=)
Min/Max meter - - - - - CFC CD DD
851 I L1 Minimum (IL1Min=) Min/Max meter - - - - - CFC CD DD
852 I L1 Maximum (IL1Max=) Min/Max meter - - - - - CFC CD DD
853 I L2 Mimimum (IL2Min=) Min/Max meter - - - - - CFC CD DD
854 I L2 Maximum (IL2Max=) Min/Max meter - - - - - CFC CD DD
855 I L3 Minimum (IL3Min=) Min/Max meter - - - - - CFC CD DD
856 I L3 Maximum (IL3Max=) Min/Max meter - - - - - CFC CD DD
857 Positive Sequence Minimum (I1
Min=)
Min/Max meter - - - - - CFC CD DD
858 Positive Sequence Maximum (I1
Max=)
Min/Max meter - - - - - CFC CD DD
859 U L1E Minimum (UL1EMin=) Min/Max meter - - - - - CFC CD DD
860 U L1E Maximum (UL1EMax=) Min/Max meter - - - - - CFC CD DD
861 U L2E Minimum (UL2EMin=) Min/Max meter - - - - - CFC CD DD
862 U L2E Maximum (UL2EMax=) Min/Max meter - - - - - CFC CD DD
863 U L3E Minimum (UL3EMin=) Min/Max meter - - - - - CFC CD DD
864 U L3E Maximum (UL3EMax=) Min/Max meter - - - - - CFC CD DD
865 U L12 Minimum (UL12Min=) Min/Max meter - - - - - CFC CD DD
867 U L12 Maximum (UL12Max=) Min/Max meter - - - - - CFC CD DD
868 U L23 Minimum (UL23Min=) Min/Max meter - - - - - CFC CD DD
869 U L23 Maximum (UL23Max=) Min/Max meter - - - - - CFC CD DD
870 U L31 Minimum (UL31Min=) Min/Max meter - - - - - CFC CD DD
871 U L31 Maximum (UL31Max=) Min/Max meter - - - - - CFC CD DD
874 U1 (positive sequence) Voltage
Minimum (U1 Min =)
Min/Max meter - - - - - CFC CD DD
875 U1 (positive sequence) Voltage
Maximum (U1 Max =)
Min/Max meter - - - - - CFC CD DD
880 Apparent Power Minimum
(SMin=)
Min/Max meter - - - - - CFC CD DD
881 Apparent Power Maximum
(SMax=)
Min/Max meter - - - - - CFC CD DD
Functions, Settings, Information
E.5 Measured Values
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No. Description Function IEC 60870-5-103 Configurable in
Matrix
Type
information number
Compatibility
Data Unit
Position
CFC
Control Display
Default Display
882 Frequency Minimum (fMin=) Min/Max meter - - - - - CFC CD DD
883 Frequency Maximum (fMax=) Min/Max meter - - - - - CFC CD DD
888 Pulsed Energy Wp (active)
(Wp(puls))
Energy 133 55 No 205 - CFC CD DD
889 Pulsed Energy Wq (reactive)
(Wq(puls))
Energy 133 56 No 205 - CFC CD DD
924 Wp Forward (Wp+=) Energy 133 51 No 205 - CFC CD DD
925 Wq Forward (Wq+=) Energy 133 52 No 205 - CFC CD DD
928 Wp Reverse (Wp-=) Energy 133 53 No 205 - CFC CD DD
929 Wq Reverse (Wq-=) Energy 133 54 No 205 - CFC CD DD
963 I L1 demand (IL1dmd=) Demand meter - - - - - CFC CD DD
964 I L2 demand (IL2dmd=) Demand meter - - - - - CFC CD DD
965 I L3 demand (IL3dmd=) Demand meter - - - - - CFC CD DD
966 R L1E (R L1E=) Measurement - - - - - CFC CD DD
967 R L2E (R L2E=) Measurement - - - - - CFC CD DD
970 R L3E (R L3E=) Measurement - - - - - CFC CD DD
971 R L12 (R L12=) Measurement - - - - - CFC CD DD
972 R L23 (R L23=) Measurement - - - - - CFC CD DD
973 R L31 (R L31=) Measurement - - - - - CFC CD DD
974 X L1E (X L1E=) Measurement - - - - - CFC CD DD
975 X L2E (X L2E=) Measurement - - - - - CFC CD DD
976 X L3E (X L3E=) Measurement - - - - - CFC CD DD
977 X L12 (X L12=) Measurement - - - - - CFC CD DD
978 X L23 (X L23=) Measurement - - - - - CFC CD DD
979 X L31 (X L31=) Measurement - - - - - CFC CD DD
1040 Active Power Minimum Forward
(Pmin Forw=)
Min/Max meter - - - - - CFC CD DD
1041 Active Power Maximum Forward
(Pmax Forw=)
Min/Max meter - - - - - CFC CD DD
1042 Active Power Minimum Reverse
(Pmin Rev =)
Min/Max meter - - - - - CFC CD DD
1043 Active Power Maximum Reverse
(Pmax Rev =)
Min/Max meter - - - - - CFC CD DD
1044 Reactive Power Minimum Forward
(Qmin Forw=)
Min/Max meter - - - - - CFC CD DD
1045 Reactive Power Maximum Forward
(Qmax Forw=)
Min/Max meter - - - - - CFC CD DD
1046 Reactive Power Minimum Reverse
(Qmin Rev =)
Min/Max meter - - - - - CFC CD DD
1047 Reactive Power Maximum Reverse
(Qmax Rev =)
Min/Max meter - - - - - CFC CD DD
Functions, Settings, Information
E.5 Measured Values
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No. Description Function IEC 60870-5-103 Configurable in
Matrix
Type
information number
Compatibility
Data Unit
Position
CFC
Control Display
Default Display
1048 Power Factor Minimum Forward
(PFminForw=)
Min/Max meter - - - - - CFC CD DD
1049 Power Factor Maximum Forward
(PFmaxForw=)
Min/Max meter - - - - - CFC CD DD
1050 Power Factor Minimum Reverse
(PFmin Rev=)
Min/Max meter - - - - - CFC CD DD
1051 Power Factor Maximum Reverse
(PFmax Rev=)
Min/Max meter - - - - - CFC CD DD
1052 Active Power Demand Forward
(Pdmd Forw=)
Demand meter - - - - - CFC CD DD
1053 Active Power Demand Reverse
(Pdmd Rev =)
Demand meter - - - - - CFC CD DD
1054 Reactive Power Demand Forward
(Qdmd Forw=)
Demand meter - - - - - CFC CD DD
1055 Reactive Power Demand Reverse
(Qdmd Rev =)
Demand meter - - - - - CFC CD DD
7751 Prot.Interface 1:Transmission
delay (PI1 TD)
Statistics - - - - - CFC CD DD
7752 Prot.Interface 2:Transmission
delay (PI2 TD)
Statistics - - - - - CFC CD DD
7753 Prot.Interface 1: Availability per
min. (PI1A/m)
Statistics - - - - - CFC CD DD
7754 Prot.Interface 1: Availability per
hour (PI1A/h)
Statistics - - - - - CFC CD DD
7755 Prot.Interface 2: Availability per
min. (PI2A/m)
Statistics - - - - - CFC CD DD
7756 Prot.Interface 2: Availability per
hour (PI2A/h)
Statistics - - - - - CFC CD DD
7761 Relay ID of 1. relay (Relay ID) Measure relay1 - - - - - CFC CD DD
7781 Relay ID of 2. relay (Relay ID) Measure relay2 - - - - - CFC CD DD
7801 Relay ID of 3. relay (Relay ID) Measure relay3 - - - - - CFC CD DD
10102 Min. Zero Sequence Voltage 3U0
(3U0min =)
Min/Max meter - - - - - CFC CD DD
10103 Max. Zero Sequence Voltage 3U0
(3U0max =)
Min/Max meter - - - - - CFC CD DD
14000 IL1 (primary) (IL1 =) Measure relay1 - - - - - CFC CD DD
14001 Angle IL1 (φIL1 =) Measure relay1 - - - - - CFC CD DD
14002 IL2 (primary) (IL2 =) Measure relay1 - - - - - CFC CD DD
14003 Angle IL2 (φIL2 =) Measure relay1 - - - - - CFC CD DD
14004 IL3 (primary) (IL3 =) Measure relay1 - - - - - CFC CD DD
14005 Angle IL3 (φIL3 =) Measure relay1 - - - - - CFC CD DD
14010 UL1E (primary) (UL1E =) Measure relay1 - - - - - CFC CD DD
14011 Angle UL1E (φUL1E =) Measure relay1 - - - - - CFC CD DD
Functions, Settings, Information
E.5 Measured Values
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No. Description Function IEC 60870-5-103 Configurable in
Matrix
Type
information number
Compatibility
Data Unit
Position
CFC
Control Display
Default Display
14012 UL2E (primary) (UL2E =) Measure relay1 - - - - - CFC CD DD
14013 Angle UL2E (φUL2E =) Measure relay1 - - - - - CFC CD DD
14014 UL3E (primary) (UL3E =) Measure relay1 - - - - - CFC CD DD
14015 Angle UL3E (φUL3E =) Measure relay1 - - - - - CFC CD DD
14020 IL1 (primary) (IL1 =) Measure relay2 - - - - - CFC CD DD
14021 Angle IL1 (φIL1 =) Measure relay2 - - - - - CFC CD DD
14022 IL2 (primary) (IL2 =) Measure relay2 - - - - - CFC CD DD
14023 Angle IL2 (φIL2 =) Measure relay2 - - - - - CFC CD DD
14024 IL3 (primary) (IL3 =) Measure relay2 - - - - - CFC CD DD
14025 Angle IL3 (φIL3 =) Measure relay2 - - - - - CFC CD DD
14030 UL1E (primary) (UL1E =) Measure relay2 - - - - - CFC CD DD
14031 Angle UL1E (φUL1E =) Measure relay2 - - - - - CFC CD DD
14032 UL2E (primary) (UL2E =) Measure relay2 - - - - - CFC CD DD
14033 Angle UL2E (φUL2E =) Measure relay2 - - - - - CFC CD DD
14034 UL3E (primary) (UL3E =) Measure relay2 - - - - - CFC CD DD
14035 Angle UL3E (φUL3E =) Measure relay2 - - - - - CFC CD DD
14040 IL1 (primary) (IL1 =) Measure relay3 - - - - - CFC CD DD
14041 Angle IL1 (φIL1 =) Measure relay3 - - - - - CFC CD DD
14042 IL2 (primary) (IL2 =) Measure relay3 - - - - - CFC CD DD
14043 Angle IL2 (φIL2 =) Measure relay3 - - - - - CFC CD DD
14044 IL3 (primary) (IL3 =) Measure relay3 - - - - - CFC CD DD
14045 Angle IL3 (φIL3 =) Measure relay3 - - - - - CFC CD DD
14050 UL1E (primary) (UL1E =) Measure relay3 - - - - - CFC CD DD
14051 Angle UL1E (φUL1E =) Measure relay3 - - - - - CFC CD DD
14052 UL2E (primary) (UL2E =) Measure relay3 - - - - - CFC CD DD
14053 Angle UL2E (φUL2E =) Measure relay3 - - - - - CFC CD DD
14054 UL3E (primary) (UL3E =) Measure relay3 - - - - - CFC CD DD
14055 Angle UL3E (φUL3E =) Measure relay3 - - - - - CFC CD DD
Functions, Settings, Information
E.5 Measured Values
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Literature
/1/ SIPROTEC 4 System Description
E50417-H1176-C151-B2
/2/ SIPROTEC DIGSI, Start UP
E50417-G1176-C152-A3
/3/ DIGSI CFC, Manual
E50417-H1176-C098-A9
/4/ SIPROTEC SIGRA 4
Handbuch; E50417-H1176-C070-A4
/5/ Digital Distance Protection: Basics and Applications; Edition: 2. completely revised and extended version (May
14, 2008); Language: German
ISBN-10: 389578320X, ISBN-13: 987-3895783203
/6/ Application Examples for SIPROTEC Protection Devices
E50001-K4451-A101-A1
/7/ Case Studies for SIPROTEC Protection Devices and Power Quality
E50001-K4452-A101-A1
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Glossary
Bay controllers
Bay controllers are devices with control and monitoring functions without protective functions.
Bit pattern indication
Bit pattern indication is a processing function by means of which items of digital process information applying
across several inputs can be detected together in parallel and processed further. The bit pattern length can be
specified as 1, 2, 3 or 4 bytes.
BP_xx
→ Bit pattern indication (Bitstring Of x Bit), x designates the length in bits (8, 16, 24 or 32 bits).
Buffer battery
The buffer battery ensures that specified data areas, flags, timers and counters are retained retentively.
C_xx
Command without feedback
CF_xx
Command with feedback
CFC
Continuous Function Chart. CFC is a graphical editor with which a program can be created and configured by
using ready-made blocks.
CFC blocks
Blocks are parts of the user program delimited by their function, their structure or their purpose.
Chatter ON
A rapidly intermittent input (for example, due to a relay contact fault) is switched off after a configurable
monitoring time and can thus not generate any further signal changes. The function prevents overloading of
the system when a fault arises.
Combination devices
Combination devices are bay devices with protection functions and a control display.
Combination matrix
From DIGSI V4.6 onward, up to 32 compatible SIPROTEC 4 devices can communicate with one another in an
Inter Relay Communication combination (IRC combination). Which device exchanges which information is
defined with the help of the combination matrix.
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Communication branch
A communications branch corresponds to the configuration of 1 to n users that communicate by means of a
common bus.
Communication reference CR
The communication reference describes the type and version of a station in communication by PROFIBUS.
Component view
In addition to a topological view, SIMATIC Manager offers you a component view. The component view does
not offer any overview of the hierarchy of a project. It does, however, provide an overview of all the SIPROTEC
4 devices within a project.
COMTRADE
Common Format for Transient Data Exchange, format for fault records.
Container
If an object can contain other objects, it is called a container. The object Folder is an example of such a
container.
Control Display
The display which is displayed on devices with a large (graphic) display after you have pressed the control key
is called the control display. It contains the switchgear that can be controlled in the feeder with status display.
It is used to perform switching operations. Defining this display is part of the configuration.
Data pane
The right-hand area of the project window displays the contents of the area selected in the → navigation
window, for example indications, measured values, etc. of the information lists or the function selection for
the device configuration.
DCF77
The extremely precise official time is determined in Germany by the "Physikalisch-Technische-Bundesanstalt
PTB" in Braunschweig. The atomic clock station of the PTB transmits this time via the long-wave time-signal
transmitter in Mainflingen near Frankfurt/Main. The emitted time signal can be received within a radius of
approx. 1,500 km from Frankfurt/Main.
Device container
In the Component View, all SIPROTEC 4 devices are assigned to an object of type Device container. This object
is a special object of DIGSI Manager. However, since there is no component view in DIGSI Manager, this object
only becomes visible in conjunction with STEP 7.
Double command
Double commands are process outputs which indicate 4 process states at 2 outputs: 2 defined (for example
ON/OFF) and 2 undefined states (for example intermediate positions)
Double-point indication
Double-point indications are items of process information which indicate 4 process states at 2 inputs: 2
defined (for example ON/OFF) and 2 undefined states (for example intermediate positions).
DP
→ Double-point indication
Glossary
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DP_I
→ Double point indication, intermediate position 00
Drag and drop
Copying, moving and linking function, used at graphics user interfaces. Objects are selected with the mouse,
held and moved from one data area to another.
Earth
The conductive earth whose electric potential can be set equal to zero at every point. In the area of earth elec-
trodes the earth can have a potential deviating from zero. The term "Earth reference plane" is often used for
this state.
Earth (verb)
This term means that a conductive part is connected via an earthing system to the → earth.
Earthing
Earthing is the total of all means and measures used for earthing.
Electromagnetic compatibility
Electromagnetic compatibility (EMC) is the ability of an electrical apparatus to function fault-free in a specified
environment without influencing the environment unduly.
EMC
→ Electromagnetic compatibility
ESD protection
ESD protection is the total of all the means and measures used to protect electrostatic sensitive devices.
EVA
Limiting value, user-defined
ExBPxx
External bit pattern indication via an ETHERNET connection, device-specific → Bit pattern indication
ExC
External command without feedback via an ETHERNET connection, device-specific
ExCF
Command with feedback via an ETHERNET connection, device-specific
ExDP
External double point indication via an ETHERNET connection, device-specific → Double point indication
ExDP_I
External double point indication via an ETHERNET connection, intermediate position 00, device-specific →
Double point indication
ExMV
External metered value via an ETHERNET connection, device-specific
Glossary
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ExSI
External single point indication via an ETHERNET connection, device-specific → Single point indication
ExSI_F
External single point indication via an ETHERNET connection, Spontaneous event, device-specific → Fleeting
indication, → Single point indication
Field devices
Generic term for all devices assigned to the field level: Protection devices, combination devices, bay control-
lers.
Fleeting Indication
Fleeting indications are single-point indications present for a very short time, in which only the coming of the
process signal is logged and further processed time-correctly.
FMS communication branch
Within an FMS communication branch, the users communicate on the basis of the PROFIBUS FMS protocol via
a PROFIBUS FMS network.
Folder
This object type is used to create the hierarchical structure of a project.
General interrogation (GI)
During the system start-up the state of all the process inputs, of the status and of the fault image is sampled.
This information is used to update the system-end process image. The current process state can also be
sampled after a data loss by means of a GI.
GOOSE message
GOOSE messages (Generic Object Oriented Substation Event) according to IEC 61850 are data packets which
are transferred event-controlled via the Ethernet communication system. They serve for direct information
exchange among the relays. This mechanism implements cross-communication between bay units.
GPS
Global Positioning System. Satellites with atomic clocks on board orbit the earth twice a day on different paths
in approx. 20,000 km. They transmit signals which also contain the GPS universal time. The GPS receiver
determines its own position from the signals received. From its position it can derive the delay time of a satel-
lite signal and thus correct the transmitted GPS universal time.
Hierarchy level
Within a structure with higher-level and lower-level objects a hierarchy level is a container of equivalent
objects.
HV field description
The HV project description file contains details of fields which exist in a ModPara-project. The actual field infor-
mation of each field is stored in a HV field description file. Within the HV project description file, each field is
allocated such a HV field description file by a reference to the file name.
HV project description
All the data is exported once the configuration and parameterization of PCUs and sub-modules using ModPara
has been completed. This data is split up into several files. One file contains details about the fundamental
project structure. This also includes, for example, information detailing which fields exist in this project. This
file is called a HV project description file.
Glossary
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ID
Internal double point indication → Double point indication
ID_S
Internal double point indication, intermediate position 00 → Double point indication
IEC
International Electrotechnical Commission, international standardization body
IEC61850
International communication standard for communication in substations. The objective of this standard is the
interoperability of devices from different manufacturers on the station bus. An Ethernet network is used for
data transfer.
IEC address
Within an IEC bus a unique IEC address has to be assigned to each SIPROTEC 4 device. A total of 254 IEC
addresses are available for each IEC bus.
IEC communication branch
Within an IEC communication branch the users communicate on the basis of the IEC60-870-5-103 protocol via
an IEC bus.
Initialization string
An initialization string comprises a range of modem-specific commands. These are transmitted to the modem
within the framework of modem initialization. The commands can, for example, force specific settings for the
modem.
Inter relay communication
→ IRC combination
IntSP
Internal single point indication → Single point indication
IntSP_Ev
Internal indication Spontaneous event → Fleeting indication, → Single point indication
IRC combination
Inter Relay Communication, IRC, is used for directly exchanging process information between SIPROTEC 4
devices. You require an object of type IRC combination to configure an inter relay communication. Each user
of the combination and all the necessary communication parameters are defined in this object. The type and
scope of the information exchanged between the users is also stored in this object.
IRIG B
Time signal code of the Inter-Range Instrumentation Group
ISO 9001
The ISO 9000 ff range of standards defines measures used to assure the quality of a product from the develop-
ment stage to the manufacturing stage.
Glossary
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LFO-Filter
(Low-Frequency-Oscillation) Filter for low frequency oscillations
Link address
The link address gives the address of a V3/V2 device.
List view
The right window section of the project window displays the names and icons of objects which represent the
contents of a container selected in the tree view. Because they are displayed in the form of a list, this area is
called the list view.
LPS
Line Post Sensor
LV
Limiting value
Master
Masters may send data to other users and request data from other users. DIGSI operates as a master.
Metered value
Metered values are a processing function with which the total number of discrete similar events (counting
pulses) is determined for a period, usually as an integrated value. In power supply companies the electrical
work is usually recorded as a metered value (energy purchase/supply, energy transportation).
MLFB
MLFB is the abbreviation for "MaschinenLesbare FabrikateBezeichnung" (machine-readable product designa-
tion). This is the equivalent of an order number. The type and version of a SIPROTEC 4 device is coded in the
order number.
Modem connection
This object type contains information on both partners of a modem connection, the local modem and the
remote modem.
Modem profile
A modem profile consists of the name of the profile, a modem driver and may also comprise several initializa-
tion commands and a user address. You can create several modem profiles for one physical modem. To do so
you need to link various initialization commands or user addresses to a modem driver and its properties and
save them under different names.
Modems
Modem profiles for a modem connection are stored in this object type.
MV
Measured value
MVMV
Metered value which is formed from the measured value
Glossary
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MVT
Measured value with time
MVU
Measured value, user-defined
Navigation pane
The left pane of the project window displays the names and symbols of all containers of a project in the form
of a folder tree.
Object
Each element of a project structure is called an object in DIGSI.
Object properties
Each object has properties. These might be general properties that are common to several objects. An object
can also have specific properties.
Off-line
In offline mode a connection to a SIPROTEC 4 device is not required. You work with data which are stored in
files.
On-line
When working in online mode, there is a physical connection to a SIPROTEC 4 device. This connection can be
implemented as a direct connection, as a modem connection or as a PROFIBUS FMS connection.
OUT
Output Indication
OUT_Ev
Output indication Spontaneous event→ Fleeting indication
Parameterization
Comprehensive term for all setting work on the device. The parameterization is done with DIGSI or sometimes
also directly on the device.
Parameter set
The parameter set is the set of all parameters that can be set for a SIPROTEC 4 device.
Phone book
User addresses for a modem connection are saved in this object type.
PMV
Pulse metered value
Process bus
Devices with a process bus interface allow direct communication with SICAM HV modules. The process bus
interface is equipped with an Ethernet module.
Glossary
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PROFIBUS
PROcess FIeld BUS, the German process and field bus standard, as specified in the standard EN 50170, Volume
2, PROFIBUS. It defines the functional, electrical, and mechanical properties for a bit-serial field bus.
PROFIBUS address
Within a PROFIBUS network a unique PROFIBUS address has to be assigned to each SIPROTEC 4 device. A total
of 254 PROFIBUS addresses are available for each PROFIBUS network.
Project
Content-wise, a project is the image of a real power supply system. Graphically, a project is represented as a
number of objects which are integrated in a hierarchical structure. Physically, a project consists of a number of
directories and files containing project data.
Protection devices
All devices with a protective function and no control display.
Reorganizing
Frequent addition and deletion of objects results in memory areas that can no longer be used. By reorganizing
projects, you can release these memory areas again. However, a cleanup also reassigns the VD addresses. The
consequence is that all SIPROTEC 4 devices have to be reinitialized.
RIO file
Relay data Interchange format by Omicron.
RSxxx-interface
Serial interfaces RS232, RS422/485
Service interface
Rear serial interface on the devices for connecting DIGSI (for example, via modem).
SICAM PAS (Power Automation System)
Substation control system: The range of possible configurations spans from integrated standalone systems
(SICAM PAS and M&C with SICAM PAS CC on one computer) to separate hardware for SICAM PAS and SICAM
PAS CC to distributed systems with multiple SICAM Station Units. The software is a modular system with basic
and optional packages. SICAM PAS is a purely distributed system: the process interface is implemented by the
use of bay units / remote terminal units.
SICAM Station Unit
The SICAM Station Unit with its special hardware (no fan, no rotating parts) and its Windows XP Embedded
operating system is the basis for SICAM PAS.
SICAM WinCC
The SICAM WinCC operator control and monitoring system displays the state of your network graphically, visu-
alizes alarms, interrupts and indications, archives the network data, offers the possibility of intervening
manually in the process and manages the system rights of the individual employee.
Single command
Single commands are process outputs which indicate 2 process states (for example, ON/OFF) at one output.
Glossary
636 SIPROTEC 4, 7SA522, Manual
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Single point indication
Single indications are items of process information which indicate 2 process states (for example, ON/OFF) at
one output.
SIPROTEC
The registered trademark SIPROTEC is used for devices implemented on system base V4.
SIPROTEC 4 device
This object type represents a real SIPROTEC 4 device with all the setting values and process data it contains.
SIPROTEC 4 Variant
This object type represents a variant of an object of type SIPROTEC 4 device. The device data of this variant
may well differ from the device data of the original object. However, all variants derived from the original
object have the same VD address as the original object. For this reason they always correspond to the same
real SIPROTEC 4 device as the original object. Objects of type SIPROTEC 4 variant have a variety of uses, such
as documenting different operating states when entering parameter settings of a SIPROTEC 4 device.
Slave
A slave may only exchange data with a master after being prompted to do so by the master. SIPROTEC 4
devices operate as slaves.
SP
→ Single point indication
SP_W
→ Single point indication Spontaneous event → Fleeting indication, → Single point indication
System interface
Rear serial interface on the devices for connecting to a substation controller via IEC or PROFIBUS.
TI
Transformer Tap Indication
Time stamp
Time stamp is the assignment of the real time to a process event.
Topological view
DIGSI Manager always displays a project in the topological view. This shows the hierarchical structure of a
project with all available objects.
Transformer Tap Indication
Transformer tap indication is a processing function on the DI by means of which the tap of the transformer tap
changer can be detected together in parallel and processed further.
Tree view
The left pane of the project window displays the names and symbols of all containers of a project in the form
of a folder tree. This area is called the tree view.
Ungrounded
Without any electrical connection to → ground.
Glossary
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User address
A user address comprises the name of the user, the national code, the area code and the user-specific phone
number.
Users
From DIGSI V4.6 onward , up to 32 compatible SIPROTEC 4 devices can communicate with one another in an
Inter Relay Communication combination. The individual participating devices are called users.
VD
A VD (Virtual Device) includes all communication objects and their properties and states that are used by a
communication user through services. A VD can be a physical device, a module of a device or a software
module.
VD address
The VD address is assigned automatically by DIGSI Manager. It exists only once in the entire project and thus
serves to identify unambiguously a real SIPROTEC 4 device. The VD address assigned by DIGSI Manager must
be transferred to the SIPROTEC 4 device in order to allow communication with DIGSI Device Editor.
VFD
A VFD (Virtual Field Device) includes all communication objects and their properties and states that are used
by a communication user through services.
VI
VI stands for Value Indication.
Glossary
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Index
Symbols
(Fail Conductor) 302
1,2,3 ...
28, 52, 300, 320, 339, 358, 488
A
AC Voltage 431
Acknowledgement of Commands 363
Adaptive Dead Time 466
Adaptive dead time (ADT) 233
ADC offset 300
Additional Functions 481
Analogue Inputs 430
Angle of inclination of the tripping characteristics 63
Anlagendaten 2 39
Assignment to the polygons 75
Asymmetrical measuring voltage failure 313
Automatic reclosing commands 346
Automatic reclosure
Circuit breaker auxiliary contacts 219
Circuit breaker test 325
Automatic Reclosure 215, 466
Automatic reclosure function
1-pole and 3-pole Reclose Cycle 220
1-pole reclose cycle 220
3-pole reclose cycle 220
Action Times 217
Control 226
External Auto-Reclosure Device 225
Initiation 217
Operating modes 218
Auxiliary and Reference Voltages 300
Auxiliary voltage 430
Auxiliary Voltage 370
B
Binary Inputs 431
Binary Outputs 342, 432
Blocking 152, 153
Blocking Scheme 130
Buffer battery 300
Busbar tripping 411
C
Calculation of the Impedances 55
Certifications 439
Change Group 38
Changing Setting Group 367
Check:
Blocking Scheme 421
Blocking Scheme (Earth-fault Protection) 423
Breaker Failure Protection 410
Current, Voltage connection 412
Direction 413
Permissive Schemes 420
Permissive Schemes (Earth-fault Protection) 422
Permissive Underreach Transfer Trip 422
Polarity Check for the Current Input I 415
Polarity Check for the Voltage Input 414
Signal Transmission (Breaker Failure Protection/End
Fault Protection) 423
Signal Transmission (int., ext. Remote Tripping) 424
Switching states of the binary Inputs/Outputs 403
Switching Test of Operating Equipment 424
System Interface 401
Teleprotection (Distance Protection) 420
Teleprotection System (Earth-fault Protection) 422
Checking a Connection 406
Checking:
Time Synchronisation Interface 401
Checking: System Connections 398
Checking: Termination 396
Circuit breaker
Closing time 37
External trip 196
Malfunction 292
position logic 323
Test 37
Test programs 333
Tripping check 424
Circuit Breaker
Detection Circuit Breaker Position 323
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Measuring the Operating Time 419
Circuit breaker auxiliary contacts 286
Circuit breaker failure protection 284, 294
End fault protection 473
Pole discrepancy supervision 473
Times 473
Circuit Breaker Failure Protection 473
Circuit breaker monitoring 473
Initiation conditions 473
Circuit breaker for voltage transformers 313
Circuit breaker not operational 297
Circuit breaker status 45
Climatic Stress Tests 438
Closing under asynchronous system conditions 248
Closing under synchronous system conditions 247
Command Execution 359, 359
Command Output 363
Command Path 358
Commisioning aids 25
Commissioning Aids
WEB-Monitor 339
Common phase initiation 287
Communication 20
Communication converter 108
Communication Converter 406, 407
Communication Interfaces 432
Communication Media 108
Communication Topology 405
Comparison Pickup
Earth fault overcurrent protection 169
Configuration of auto-reclosure 232
Configuring the functional scope 28
Consistency
Parameterisation 408
Topology 408
Construction 439
Control Logic 362
Control Voltage for Binary Inputs 371
Controlled zone 82, 94
Conventional transmission 135
Conventional Transmission 180
Counters and Memories 346
cross polarisation 88
Cubicle Mounting 392, 484, 485
Current flow monitoring 285
Current Inputs 430
Current Symmetry 302
Current transformer saturation 45
D
DC Voltage 430
Dead line check 233
Dead Line Check 466
Default displays 343
Definite time high set current stage 3I>> 141
Definite time overcurrent stage 3I> 141
Definite time stages 154
Definite time very high set current stage 3I>>> 140
Delay times- single-stage/two-stage circuit breaker failure
protection 291
Dependent zone 92
Dependent zone: 76
Deployment Conditions 439
Determination of direction 71
Lines with series compensation 149
long lines 148
Negative phase-sequence system 149
Series-compensated lines 74
Transformer star point current 147
Zero-sequence power (compensated) 149
Zero-sequence system 147
Zero-sequence voltage 147
Device and system logic 529
Device Logout (Functional Logout) 112
Dialog Box 404
Digital transmission 135
Digital Transmission 181
Direct connection 108
Direct Underreach Transfer Trip 122
direction of the short-circuit 72
Directional Blocking Scheme 176
directional characteristic 73
Directional characteristic
MHO-Characteristic 86
Directional Check with Load Current 413
Directional Comparison Pickup 169
Directional Unblocking Scheme 172
Display of measured values 347
Distance protection
Matching of earth to line impedance 37
Distance Protection 21, 441
Earth fault detection 441
Earth Impedance Ratio 441
Mutual Impedance Ratio 441
Phase preference 441
Times 442
Double earth faults in effectively earthed systems 64
Double earth faults in non-earthed systems 59, 64
Double Faults in Earthed Systems 58
E
Earth fault
Single-pole tripping 37
Earth fault detection 62
Earth fault overcurrent protection
Direction determination 158
Zero-sequence power stage 157
Earth Fault Protection 446
Characteristics 446
Determination of Direction 449
High-current Stage 446
Inrush Restraint 449
Index
640 SIPROTEC 4, 7SA522, Manual
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Inverse Current IEC-Characteristics 447
Inverse Current Stage with logarithmic inverse Char-
acteristics 448
Inverse Current Stage with mit ANSI-Characteris-
tics 447
Overcurrent stage 446
Very high set current stage 446
Zero Sequence Output Stage (power stage) 448
Zero Sequence Voltage Stage (U0 inverse) 448
Earth impedance ratio 41
Echo Function 134, 136, 183
Electrical Tests 436
EMC Tests for Interference Emission (Type Test) 437
EMC Tests for Interference Immunity (Type Tests) 436
Emergency Operation 443
EN100-Module
Interface selection 338
End fault protection 293, 297
End fault stage 201
Energy Metering 356
Erdfehlererkennung 52
Event buffer 343
Exchanging Interfaces 371
External Direct and Remote Tripping 461
F
Fast tripping zone (MHO) 91
Fast tripping zone (Polygon) 76
Fault Annunciations 336
Fault Indications 344
Fault location
Matching of earth to line impedance 37
Fault Location Options 345
Fault Locator 472
Fault Logging 482
Fault record 344
Fault Recording 20, 482
Fault Records 350
Feedback monitoring 363
Ffiber optic 108
Final Preparation of the Device 427
Forced three-pole trip 233
frequency protection 274
Overfrequency protection 274
Underfrequency protection 274
Frequency protection
delay time 277
Frequency measurement 274
Frequency stages 274
Operating ranges 274
pickup values 277
Pickup/tripping 275
Power swings 275
Frequency Protection 471
Operating Range 471
Pick-up Values 471
Times 471
Tolerances 471
Function Blocks 477
Functional Logout 109
Funktionsumfang 28
Fuse-Failure-Monitor 303, 313
G
General Interrogation 345
Grading coordination chart 76, 92
H
High current stages I>>, 3I>> 206
High set current stage I>> 199
Humidity 439
I
IEC 61850 GOOSE (inter-device communication) 483
Independent zones 76, 91
Independent Zones 80, 93
Indications 344
Information to a Control Centre 344
Input/Output Board
C-I/O-1; C-I/O-10 374
C-I/O-2 381
Input/output boardC-I/O-7 385
Inrush restraint 147, 161
Instantaneous High-current Switch-onto-fault Protec-
tion 465
Instantaneous tripping 193
before automatic reclosure 203
Insulation Test 436
Integrated Display 343
Interlocking 359
Interrupted currents 346
Inverse Current Stage (Earth Fault Protection)
ANSI-Characteristics 447
IEC-Characteristics 447
Logarithmic inverse Characteristics 448
Inverse Time Current Stage (Earth fault overcurrent
protection)
ANSI Characteristic 155
Inverse time overcurrent stage 143
Inverse time overcurrent stage 3I 142
Inverse time stage (Earth fault overcurrent protection)
IEC characteristic 155
Logarithmic inverse characteristic 156
Inverse Time Stages (time overcurrent protection)
IEC Curve 463
Inverse Time Stages (Time Overcurrent Protection)
Index
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ANSI-Characteristic 463
L
Life Status contact 370
Limit value monitoring 355
Limiting with user defined functions 478
Limits for CFC blocks 478
Line Data 40
Line Energization Recognition 320
Load range 64
Long-Term Average Values 352
Loops 72
M
Malfunction Reaction 310
Mean values 352
Measured Value Acquisition
Currents 301
Voltages 301
Measured Value Correction 281
Measured values 198, 347, 474
Measured voltage failure monitoring 313
Measured Voltage Failure Monitoring 306
Mechanische Prüfungen 438
Memory Components 300
MHO-Characteristic
Pickup 91
MHO-Charakteristic 85
Minimum Current 62
Modem 108
Monitoring Functions 474
Monitoring phase angle 313
Monitoring the Phase Angle 307
Mounting: Panel Mounting 394
N
Nominal Currents 370
Non-energized switching 247
O
One-pole dead time 327
Open Pole Detektor 326
Operating modes of the closing check 246
Operating polygons 71
Operating state change 404
Operating Time of the Circuit Breaker 419
Operational Indication Buffer 482
Operational Indications 344
Operational measured values 481
Operator Interface
Control 395
Optical Fibres 397
Oscillographic Recording for Test 425
Output Relays 342
Overcurrent stage
I (inverse) 200
I> (independent) 200
Overcurrent Stages
3I (Inverse-time Overcurrent Protection with ANSI
Characteristics) 209
3I (Inverse-time Overcurrent Protection with IEC
Characteristics) 208
3I> (Definite-time Overcurrent Protection) 207
I (Inverse-time Overcurrent Protection with ANSI
Characteristics) 209
I (Inverse-time Overcurrent Protection with IEC Char-
acteristics) 208
I> (Definite-time Overcurrent Protection) 207
Overreach schemes
Distance protection 445
Earth Fault Protection 455
Overreach Schemes
via Protection Data Interface 445, 455
overvoltage protection
any single-phase voltage 469
zero-sequence system 3 469
Overvoltage protection
Compounding 257
Negative sequence system 258, 267, 468
Phase-to-earth 266, 468
Phase-to-phase 256, 266, 468
positive sequence system 266, 468
Positive sequence system 257
Zero-sequence system 267
Zero-sequence system 3 259
Overvoltage Protection 255
P
Panel Flush Mounting 484, 485
Panel Mounting 394
Parallel line measured value correction 61
Parallel line measured value correction (optional) 63
Parallel line mutual impedance 44
Permissive Overreach Transfer Trip (POTT)
Distance protection 123
Permissive Underreach Transfer Trip with Zone Accelera-
tion Z1B (PUTT) 118
Phase current stabilization 147, 161
Phase selection 192
Phase selector 150
Phase-segregated initiation - Circuit breaker failure
protection 288
Pickup Logic for the Entire Device 328
Index
642 SIPROTEC 4, 7SA522, Manual
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Pickup Value (SOFT) 214
Pickup/tripping logic 204
Polarised MHO characteristic 86
Polarity Check
Current Input I 415
Polarity Check:
Voltage Input 414
Pole discrepancy supervision 294, 297
Polygonal Charakteristic 71
POTT
Distance protection 123
Power Swing 444
Power Swing Detection 444
Power System Data 1 32
Protection Data Interface 110
Protection Data Communication 460
Protection Data Interface and Communication
Topology 458
Protection Data Interface-Test Mode 410
Protection Data Topology 107, 110
R
Rack Mounting 392
Rated frequency 36
Reading/Setting/Resetting 346
Real Time Clock and Buffer Battery 482
Reclose cycle 234, 236, 236
Reclosure
Blocking 218
Multiple 221
Reduced dead time 233
Reduced Dead Time 466
Remote commands 115
Remote Commands 476
Remote Indications 476
Remote measured values 349
Remote signals 115
Remote trip 196
Reset 353
Reset of Stored LED / Relays 335
Resistance tolerance
resistance of the fault arc 77
Retrievable Indications 345
Retrieving Parameters 357
S
Sampling frequency 300
Schaltprüfung der projektierten Operating Equip-
ment 424
Series-compensated lines 63
Service / Modem Interface (optional) 433
Service Interface
Test 395
Set Points for Measured Values 356
Setting Groups 38
Changing 367
Signal transmission 115
Single-stage circuit breaker failure protection 296
Specifications 436
Spontaneous Fault Messeges 335
Spontaneous Indications 345, 345
Stage I>>> 210
Standard Interlocking 360
Start Test Measurement Recording 425
Statistics 482
Sum Monitoring 312
Supervision with binary input 318
Switching
onto a fault 61, 64, 203
onto an earth fault 153
Switching (Interlocked/non-interlocked) 360
Switching onto an earth fault 161
Switching Statistics 482
Symmetry monitoring 312
Synchro check 242
Synchro Check
Δ measurement 467
Asynchronous power conditions 467
Operating Modes 467
Synchronous power conditions 467
Voltages 467
Synchronism Check 467
Synchronism conditions for automatic reclosure 249
Synchronism conditions for manual closure and control
command 250
System Interface 433
T
Teleprotection 117
with earth fault protection 161
Teleprotection schemes 186
Teleprotection Schemes 117
with Distance Protection 445
Teleprotection Schemes (optional)
with Earth Fault Protection 455
Temperatures 438
Terminating of Bus-capable Interfaces 371
Termination 396
Test Mode 401
Test Mode Teleprotection 410
Test:
Binary inputs 405
Indication Direction 403
LEDs 405
Operator Interface 395
Output relay 404
Phase Rotation 412
Service Interface 395
Time Synchronization Interface 396
Index
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User-defined Functions 424
VT miniature circuit breaker 412
Test: System interface 395
Test:Command Direction 403
Three-phase measuring voltage failure 313
Three-pole coupling 47
Time Overcurrent Protection 462
Characteristics 462
High-set Current Stages 462
Operating modes 462
Overcurrent Stages 462
Stub Fault Protection 464
Time Synchronisation Interface 436
Time Synchronization Interface 396
Transfer trip to the remote end circuit breaker 293
Transient blocking 136
Transient Blocking 133, 179, 182
Transmission Block 401
Transmission channels 117
Transmission Failure 109
Transmission of Binary Information 476
Transmission statistics 346
Trip Circuit Supervision 368, 475
Trip command duration 37
Trip with delay 193
Trip-Dependent Indications 335
Tripping characteristic 85
Tripping logic 100
Tripping Logic of the Entire Device 329
Tripping zones 90
Trips 346
Two-stage circuit breaker failure protection 295
Type of Commands 358
Type of Contact for Output Relays 371
U
Unblocking Scheme 126
Underreach scheme
Distance protection 445
Underreach Schemes
via a Protection Data Interface 445
Undervoltage 186
positive sequence system 264
Undervoltage protection
Phase to-phase 469
phase-to-earth 268
Phase-to-earth 469
phase-to-phase 268
Phase-to-phase 263
positive sequence system 269
Positive sequence system 469
Undervoltage Protection
Phase-Earth 261
User-defined Functions 477
V
Vibration and Shock Resistance during Stationary Opera-
tion 438
Vibration and Shock Resistance during Transport 438
Voltage Inputs 430
Voltage Jump 190
Voltage measuring inputs 33
Voltage Phase Sequence 303
Voltage Protection 255
Voltage supply 430
Voltage Symmetry 303
W
Watchdog 302
Weak Infeed 179
Weak-infeed Tripping
classical 456
French Specification 457
Operating Mode 456
Times 456
Undervoltage 456
Web-Monitor 25
Z
Zero Infeed 179
Zero-sequence power protection 146
Zero-sequence voltage time protection 144
Zero-Sequence Voltage-controlled Stage with Inverse
Characteristic 157
Zero-voltage stages for single-phase voltage 261
Zone logic 96, 99
Zone pickup 90
Index
644 SIPROTEC 4, 7SA522, Manual
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