Vorwort Table of Contents Introduction SIPROTEC 4 Distance Protection 7SA522 V4.74 and higher Functions Mounting and Commissioning Technical Data Ordering Information and AccessoriesOrdering Information Terminal Assignments Manual Connection Examples Default Settings and Protocol-dependent Functions Functions, Settings, Information Literature Glossary Index C53000-G1176-C155-9 1 2 3 4 A B C D E 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 hardware 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 regularly 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 (c) Siemens AG 2016. All rights reserved. Dissemination or reproduction of this document, or evaluation 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 trademarks 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 particular, one will find: * Information regarding the configuration of the scope of the device and a description of the device functions 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 maintenance 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 C53000-G1176-C155-9, Edition 05.2016 3 Vorwort 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 Manahmen nicht getroffen werden. ! Beachten Sie alle Hinweise, um Tod oder schwere Verletzungen zu vermeiden. Danger 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. ! Comply 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. i 4 Comply with all instructions, in order to avoid moderate or minor injuries. NOTE indicates information on the device, handling of the device, or the respective part of the instruction manual which is important to be noted. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Vorwort 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 5 Vorwort 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 6 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Table of Contents Vorwort.........................................................................................................................................................3 1 2 Introduction................................................................................................................................................15 1.1 Overall Operation..............................................................................................................16 1.2 Application Scope............................................................................................................. 19 1.3 Characteristics.................................................................................................................. 21 Functions.................................................................................................................................................... 27 2.1 General.............................................................................................................................28 2.1.1 2.1.1.1 2.1.1.2 2.1.1.3 Functional Scope......................................................................................................... 28 Konfiguration des Funktionsumfangs .................................................................... 28 Setting Notes......................................................................................................... 28 Settings................................................................................................................. 30 2.1.2 2.1.2.1 2.1.2.2 Power System Data 1................................................................................................... 32 Setting Notes......................................................................................................... 33 Settings................................................................................................................. 37 2.1.3 2.1.3.1 2.1.3.2 2.1.3.3 2.1.3.4 Change Group............................................................................................................. 38 Purpose of the Setting Groups................................................................................ 38 Setting Notes......................................................................................................... 39 Settings................................................................................................................. 39 Information List..................................................................................................... 39 2.1.4 2.1.4.1 2.1.4.2 2.1.4.3 Power System Data 2................................................................................................... 39 Setting Notes......................................................................................................... 39 Settings................................................................................................................. 48 Information List..................................................................................................... 50 2.2 Distance Protection .......................................................................................................... 52 2.2.1 2.2.1.1 2.2.1.2 2.2.1.3 2.2.1.4 2.2.1.5 Distance protection, general settings........................................................................... 52 Erdfehlererkennung............................................................................................... 52 Calculation of the Impedances................................................................................55 Setting Notes......................................................................................................... 62 Settings................................................................................................................. 66 Information List..................................................................................................... 68 2.2.2 2.2.2.1 2.2.2.2 2.2.2.3 Distance protection with quadrilateral characteristic (optional).................................... 70 Functional Description........................................................................................... 71 Setting Notes......................................................................................................... 76 Settings................................................................................................................. 83 2.2.3 2.2.3.1 2.2.3.2 2.2.3.3 Distance protection with MHO characteristic (optional)................................................ 85 Functional Description........................................................................................... 85 Setting Notes......................................................................................................... 92 Settings................................................................................................................. 95 2.2.4 2.2.4.1 2.2.4.2 Tripping Logic of the Distance Protection..................................................................... 96 Functional Description........................................................................................... 96 Setting Notes....................................................................................................... 101 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 7 Table of Contents 2.3 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 2.9.1 2.9.1.1 8 Power swing detection (optional).................................................................................... 102 2.3.1 Measures for Weak and Zero Infeed.................................................................................185 Echo function............................................................................................................ 185 Functional Description......................................................................................... 185 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Table of Contents 2.9.2 2.9.2.1 2.9.2.2 Classical Tripping....................................................................................................... 186 Functional Description......................................................................................... 186 Setting Notes....................................................................................................... 189 2.9.3 2.9.3.1 2.9.3.2 Tripping According to French Specification.................................................................190 Functional Description......................................................................................... 190 Setting Notes....................................................................................................... 192 2.9.4 2.9.4.1 2.9.4.2 Tables on Classical Tripping and Tripping according to French Specification................ 194 Settings............................................................................................................... 194 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 9 Table of Contents 2.17 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 2.19.1.1 2.19.1.2 2.19.1.3 2.19.1.4 2.19.1.5 2.19.1.6 2.19.1.7 2.19.1.8 Measurement Supervision......................................................................................... 300 Hardware Monitoring........................................................................................... 300 Software Monitoring............................................................................................ 302 Monitoring External Transformer Circuits..............................................................302 Monitoring the Phase Angle of the Positive Sequence Power.................................307 Malfunction Reaction........................................................................................... 310 Setting Notes....................................................................................................... 312 Settings............................................................................................................... 313 Information List................................................................................................... 314 2.19.2 2.19.2.1 2.19.2.2 2.19.2.3 2.19.2.4 Trip circuit supervision............................................................................................... 315 Functional Description......................................................................................... 315 Setting Notes....................................................................................................... 318 Settings............................................................................................................... 318 Information List................................................................................................... 318 2.20 Function Control and Circuit Breaker Test ....................................................................... 320 2.20.1 2.20.1.1 2.20.1.2 2.20.1.3 2.20.1.4 2.20.1.5 Function Control........................................................................................................320 Line Energization Recognition.............................................................................. 320 Detection of the Circuit Breaker Position............................................................... 323 Open Pole Detektor.............................................................................................. 326 Pickup Logic for the Entire Device ........................................................................ 328 Tripping Logic of the Entire Device....................................................................... 329 2.20.2 2.20.2.1 2.20.2.2 2.20.2.3 Circuit breaker trip test.............................................................................................. 333 Functional Description......................................................................................... 333 Setting Notes....................................................................................................... 334 Information List................................................................................................... 334 2.20.3 2.20.3.1 2.20.3.2 2.20.3.3 2.20.3.4 2.20.3.5 Device....................................................................................................................... 334 Trip-Dependent Indications.................................................................................. 335 Switching Statistics.............................................................................................. 336 Setting Notes....................................................................................................... 336 Settings............................................................................................................... 336 Information List................................................................................................... 336 2.20.4 2.20.4.1 2.20.4.2 2.20.4.3 Ethernet EN100-Module............................................................................................ 338 Functional Description......................................................................................... 338 Setting Notes....................................................................................................... 338 Information List................................................................................................... 338 2.21 10 Fault locator................................................................................................................... 280 2.17.1 Auxiliary Functions .........................................................................................................339 2.21.1 2.21.1.1 2.21.1.2 Commissioning Aids.................................................................................................. 339 Functional Description......................................................................................... 339 Setting Notes....................................................................................................... 342 2.21.2 2.21.2.1 Processing of Messages............................................................................................. 342 Functional Description......................................................................................... 342 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Table of Contents 2.21.3 2.21.3.1 2.21.3.2 2.21.3.3 Statistics....................................................................................................................345 Functional Description......................................................................................... 346 Setting Notes....................................................................................................... 346 Information List................................................................................................... 346 2.21.4 2.21.4.1 2.21.4.2 Measurement............................................................................................................ 347 Functional Description......................................................................................... 347 Information List................................................................................................... 349 2.21.5 2.21.5.1 2.21.5.2 2.21.5.3 2.21.5.4 Oscillographic Fault Records...................................................................................... 350 Functional Description .........................................................................................350 Setting Notes....................................................................................................... 351 Settings............................................................................................................... 351 Information List................................................................................................... 352 2.21.6 2.21.6.1 2.21.6.2 2.21.6.3 2.21.6.4 Demand Measurement Setup.....................................................................................352 Long-Term Average Values................................................................................... 352 Setting Notes....................................................................................................... 352 Settings............................................................................................................... 352 Information List................................................................................................... 353 2.21.7 2.21.7.1 2.21.7.2 2.21.7.3 2.21.7.4 Min/Max Measurement Setup.................................................................................... 353 Reset................................................................................................................... 353 Setting Notes....................................................................................................... 353 Settings............................................................................................................... 353 Information List................................................................................................... 353 2.21.8 2.21.8.1 2.21.8.2 2.21.8.3 Set Points (Measured Values)..................................................................................... 355 Limit value monitoring......................................................................................... 355 Setting Notes....................................................................................................... 356 Information List................................................................................................... 356 2.21.9 2.21.9.1 2.21.9.2 2.21.9.3 Energy.......................................................................................................................356 Energy Metering.................................................................................................. 356 Setting Notes....................................................................................................... 357 Information List................................................................................................... 357 2.22 3 Command Processing ..................................................................................................... 358 2.22.1 2.22.1.1 2.22.1.2 2.22.1.3 2.22.1.4 Control Authorization................................................................................................ 358 Type of Commands.............................................................................................. 358 Sequence in the Command Path...........................................................................358 Interlocking......................................................................................................... 359 Information List................................................................................................... 362 2.22.2 2.22.2.1 Control Device........................................................................................................... 362 Information List................................................................................................... 362 2.22.3 2.22.3.1 2.22.3.2 Process Data.............................................................................................................. 363 Functional Description......................................................................................... 363 Information List................................................................................................... 363 2.22.4 2.22.4.1 Protocol.....................................................................................................................364 Information List................................................................................................... 364 Mounting and Commissioning................................................................................................................. 365 3.1 Mounting and Connections............................................................................................. 366 3.1.1 Configuration Information......................................................................................... 366 3.1.2 3.1.2.1 3.1.2.2 3.1.2.3 3.1.2.4 3.1.2.5 Hardware Modifications.............................................................................................370 General................................................................................................................370 Disassembly......................................................................................................... 371 Switching Elements on Printed Circuit Boards....................................................... 374 Schnittstellenmodule........................................................................................... 387 Reassembly.......................................................................................................... 390 3.1.3 3.1.3.1 Mounting.................................................................................................................. 390 Panel Flush Mounting...........................................................................................390 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 11 Table of Contents 3.1.3.2 3.1.3.3 3.2 Checking Data Connections of Serial Interfaces.......................................................... 395 3.2.2 Checking the Protection Data Communication............................................................397 3.2.3 Checking the System Connections............................................................................. 398 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 4 ....................................................................... 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 Technical Data.......................................................................................................................................... 429 4.1 12 Checking Connections.....................................................................................................395 3.2.1 3.3 4 Rack and Cubicle Mounting.................................................................................. 392 Panel Mounting....................................................................................................394 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Table of Contents A B C D E 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 Ordering Information and AccessoriesOrdering Information.................................................................. 487 A.1 Ordering Information...................................................................................................... 488 A.2 Accessories..................................................................................................................... 492 Terminal Assignments.............................................................................................................................. 495 B.1 Panel Flush Mounting or Cubicle Mounting......................................................................496 B.2 Housing for Panel Surface Mounting................................................................................505 Connection Examples............................................................................................................................... 515 C.1 Current Transformer Examples........................................................................................ 516 C.2 Voltage Transformer Examples........................................................................................ 520 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 Functions, Settings, Information..............................................................................................................531 E.1 Functional Scope............................................................................................................ 532 E.2 Settings.......................................................................................................................... 534 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 13 Table of Contents E.3 Information List.............................................................................................................. 558 E.4 Group Alarms..................................................................................................................620 E.5 Measured Values.............................................................................................................621 Literature.................................................................................................................................................. 627 Glossary.................................................................................................................................................... 629 Index.........................................................................................................................................................639 14 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 1 Introduction The SIPROTEC 4 7SA522 is introduced in this chapter. The device is presented in its application, characteristics, and functional scope. 1.1 Overall Operation 16 1.2 Application Scope 19 1.3 Characteristics 21 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 15 Introduction 1.1 Overall Operation 1.1 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 starpoint), 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 optionally be used to measure either the displacement voltage (e-n voltage), or the additiona voltage of synchronism 16 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Introduction 1.1 Overall Operation 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 C 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, communication, 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 equipment (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 synchronization sources. Further communication protocols can be realized via additional interface modules. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 17 Introduction 1.1 Overall Operation 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). 18 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Introduction 1.2 Application Scope 1.2 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 protection 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 measurement. 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 protection 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 singlepole, 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 available: - 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 interfaces, the communication can be built up as a ring. This enables a redundant operation in case a communication 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 19 Introduction 1.2 Application Scope 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 position) of the primary equipment can be displayed on the device, and used for interlocking or plausibility monitoring. 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. Measurement 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 operator interface, such as specifying and modifying configuration parameters and settings, configuring userspecific 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 interrelay 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. 20 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Introduction 1.3 Characteristics 1.3 Characteristics General Features * * Powerful 32-bit microprocessor system * 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 * * Distance protection system realizable for up to three ends * 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 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 readjustment 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 * 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 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 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 * * * * * * * Suitable for lines with series compensation 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 21 Introduction 1.3 Characteristics * * * * 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 standards 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, Y or U2), with zero sequence system quantities (0, U0), with zero sequence current and transformer starpoint current (0, Y), with negative sequence system quantities (2, U2) or with zero sequence power (0 * 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) * * * 22 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Introduction 1.3 Characteristics 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 tripping) 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 independent 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 diff and the frequency difference fdiff * * Alternatively, check of the de-energized state before reclosing * Settable minimum and maximum voltage Closing at asynchronous system conditions with consideration of the CB closing time to achieve system re-connection when voltages are in phase SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 23 Introduction 1.3 Characteristics * 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 * * * * * Fault location output in Ohm, kilometers or miles and % of line length * Output of the fault location in the BCD code or as analog value (depending on the options ordered) Initiated by trip command or dropout of the pickup Computation of the distance to fault with dedicated measured value registers Parallel line compensation can be selected Taking into consideration the load current in case of single-phase earth faults fed from both sides (configurable) Circuit Breaker Failure Protection (optional) 24 * 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Introduction 1.3 Characteristics User-defined Logic Functions (CFC) * Freely programmable combination of internal and external signals for the implementation of userdefined 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 procedure 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 25 26 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 2 Functions This chapter describes the individual functions of the SIPROTEC 4 device 7SA522. It shows the setting possibilities 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 27 Functions 2.1 General 2.1 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 transmitted 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. 2.1.1 Functional Scope 2.1.1.1 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 overhead 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 corresponding settings (functions, limit values) are not displayed during setting. i 2.1.1.2 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- 28 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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 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 Quadrilateral 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 Disabled. 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 function 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 overcurrent protection depending on the ordered version. The latter operates either according to an IEC characteristic (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 procedures 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 29 Functions 2.1 General Address 145 P. INTERFACE 1 and, where required, address 146 STATE PROT I 2 is also valid for communication 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 transformer 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 Taction ... ) 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 threepole 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 integrated compounding. This is particularly useful for long transmission lines where no-load or low-load conditions 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 Disabled, 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 monitored: 1 trip circuit, 2 trip circuits or 3 trip circuits, unless you omit it (Disabled). 2.1.1.3 Settings Addr. Parameter Setting Options Default Setting Comments 103 Grp Chge OPTION Disabled Enabled Disabled Setting Group Change Option 30 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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 overcurr. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 31 Functions 2.1 General 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 2.1.2 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 functions 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. 32 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 2.1.2.1 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 individual 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 E or EE. [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, otherwise 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 transformers. Various possibilities exist for the fourth voltage input U4. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 33 Functions 2.1 General * 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 Usy2-Usy1 is not required. This parameter can only be changed in DIGSI at Display Additional 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 Transformator 220 kV primary, 100 V secondary, 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: Usy2-Usy1 = 360 - 150 = 210. Adresse 214: 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. 34 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General [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 protection 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 4: * Connection of the 4 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 4 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 4 or a sensitive measuring current input. Example: Phase current transformers 500 A / 5 A Earth current transformer 60 A / 1 A SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 35 Functions 2.1 General [formel-strmwdl-parallelschlt-270702-wlk, 1, en_GB] * Connection of the 4 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 = N paral. line / N 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 4 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 4-Eingang nicht benotigt, so wird eingestellt: Adresse 220 I4 transformer = Not connected, Adresse 221 I4/Iph CT ist dann irrelevant. Fur die Schutzfunktionen wird in diesem Fall der Nullstrom aus der Summe der Phasenstrome 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. 36 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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 separately (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 terminated 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-CBtestdead 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. 2.1.2.2 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 37 Functions 2.1 General 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 OpenDelta-VT 212 Usy2 connection L1-E L2-E L3-E L1-L2 L2-L3 L3-L1 L1-L2 VT connection for Usy2 214A 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 Duration 242 T-CBtest-dead 0.00 .. 30.00 sec 0.10 sec Dead Time for CB test-autoreclosure 2.1.3 Change Group 2.1.3.1 Purpose of the Setting Groups Up to four different setting groups can be created for establishing the device's function settings. During operation, the user can locally switch between setting groups using the operator panel, binary inputs (if so configured), 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 functions is the same for all groups. 38 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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. 2.1.3.2 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. 2.1.3.3 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 2.1.3.4 Information List No. Information Type of Information 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 2.1.4 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. 2.1.4.1 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 39 Functions 2.1 General 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 /km X'1 = 0,42 /km The line angle is computed as follows [formel-allg-ltgdaten-2-oz-310702, 1, en_GB] In address 1105 the setting Line Angle = 66is 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 positive 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 /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 /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 F/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 F/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, ) 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: 40 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General [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 /km X'1 = 0.42 /km C' Current Transformer Voltage transformer = 0.008 F/km 600 A / 1 A 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 /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 F/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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 41 Functions 2.1 General 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 computation 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 /km positive sequence impedance X1/s = 0.42 /km positive sequence impedance R0/s = 0.53 /km zero sequence impedance X0/s = 1.19 /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). Accordingly, 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 42 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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 /km positive sequence impedance Z0/s = 0.632 * ej18,4 /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 (K0) + + + I 0 ... +90 arc tan (|Im| / |Re|) + - - IV -90 ... 0 -arc tan (|Im| / |Re|) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Quadrant/range Calculation 43 Functions 2.1 General Real part Imaginary part tan (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 approximation 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 determined 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 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 4 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 ParalLine 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 E/EP 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 44 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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 saturation of the current transformers and initiates a change of the measurement method of the distance protection. 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] i PN = Nominal CT burden [VA] Pi = Nominal CT internal burden [VA] P' = Actual connected burden (protection device + connection cable) 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 functions 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 45 Functions 2.1 General 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 presetting 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 evaluated 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 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 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 parameter can only be altered in DIGSI at Display Additional Settings. 46 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General 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/ measurement, 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 evaluate 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 additional voltage Usy2 for synchronism check has to be connected to the device and this must be correctly parameterised 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 tripping) 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 tripping will only lead to a three-pole coupling, if it occurs within the trip zone. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 47 Functions 2.1 General 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 occurring 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 desirable 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 correspondingly 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 O), or the lagging phase (1pole lagging O) 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. 2.1.4.2 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 secondary nominal current of the current transformer. Addr. Parameter 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 48 C SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General Addr. Parameter 1107 P,Q sign 1110 x' 1111 Line Length 1112 x' 1113 Line Length 1114 c' 1115 c' 1116 RE/RL(Z1) 1117 C Setting Options Default Setting Comments not reversed reversed not reversed P,Q operational measured values sign 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km x' - Line Reactance per length unit 0.1 .. 1000.0 km 100.0 km Line Length 1A 0.0050 .. 15.0000 /mi 0.2420 /mi 5A 0.0010 .. 3.0000 /mi 0.0484 /mi x' - Line Reactance per length unit 0.1 .. 650.0 Miles 62.1 Miles Line Length 1A 0.000 .. 100.000 F/km 0.010 F/km 5A 0.000 .. 500.000 F/km 0.050 F/km c' - capacit. per unit line len. F/km 1A 0.000 .. 160.000 F/mi 0.016 F/mi 5A 0.000 .. 800.000 F/mi 0.080 F/mi -0.33 .. 10.00 1.00 Zero seq. comp. factor RE/RL for Z1 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 5A 0.25 .. 5.00 A 0.50 A Pole Open Current Threshold 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 c' - capacit. per unit line len. F/mile 49 Functions 2.1 General Addr. Parameter 1136 OpenPoleDetect. 1140A I-CTsat. Thres. C Setting Options Default Setting Comments OFF Current AND CB w/ measurement w/ measurement open pole detector 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. (Einstellmoglichkeiten anwendungsabhangig) none MANUAL Closure Impulse after CONTROL 1155 3pole coupling with PICKUP with TRIP with TRIP 3 pole coupling 1156A Trip2phFlt 3pole 1pole leading O 1pole lagging O 3pole Trip type with 2phase faults 1211 Distance Angle 30 .. 90 85 Angle of inclination, distance charact. 2.1.4.3 Information List No. Information Type of Information 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) 50 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.1 General No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 51 Functions 2.2 Distance Protection 2.2 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. 2.2.1 Distance protection, general settings 2.2.1.1 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 displacement voltage measurement. Furthermore, special measures are taken to avoid a pickup for single earth faults in an isolated or resonantearthed system. Earth Current 30 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 secondary 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 32 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 2 has approximately the same magnitude as the zero sequence current 0. 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*N for 30 and 32. 52 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [kennliniederi0i2stufe-270702-wlk, 1, en_GB] Figure 2-7 Characteristic of the 0/2 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 53 Functions 2.2 Distance Protection [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 criterion 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 immediately. 54 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [symmetrieerkennung-st-090705, 1, en_GB] Figure 2-10 k= Symmetry detection for phase-to-phase voltages Setting value for parameter 1223 [erdfehlererk-isoliert-geloescht-st-090705, 2, en_GB] Figure 2-11 2.2.1.2 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 therefore 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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 55 Functions 2.2 Distance Protection L1 * ZL - L2 * ZL = UL1-E - UL2-E with U, Z = R + jX the (complex) measured quantities and 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. 56 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [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 L3 and the earth current E are measured. The impedance to the fault location 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 L3 = r.m.s. value of the phase short-circuit current E = r.m.s. value of the earth short-circuit current U = phase angle of the short-circuit voltage L = phase angle of the phase short-circuit current E = 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 57 Functions 2.2 Distance Protection [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 impedance 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 L3E. Combined with load currents which may flow, the unfaulted loops produce the so called apparent impedances" 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 therefore 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 designated 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 detection 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 O). Alternatively, it is also possible to block the lagging phase58 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection toearth loop (Parameter 2Ph-E faults = Block lagging O). 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 = OO loops only) or only the phase-to-earth loops (Parameter 2Ph-E faults = O-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 O 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 O 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 = O-O 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 = O-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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 59 Functions 2.2 Distance Protection 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 galvanicallyconnected 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 60 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 influenced by the coupling of the earth impedance of the two conductor systems (Figure 2-17). This causes measuring 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. L3 * ZL - E * ZE - EP * (Z0M/3) = UL3-E [messkorrparall-formel-wlk-040618, 1, en_GB] where EP is the earth current of the parallel line and the ratios R0M/3RL and X0M/3XL are constant line parameters, 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 E is larger than EP: compensation is applied at by including ZM * EP 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 61 Functions 2.2 Distance Protection [logikdia-zuschalten-auf-einen-fehler-240402-wlk, 1, en_GB] Figure 2-18 i 2.2.1.3 Circuit breaker closure onto a fault 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 instantaneous 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. 30 is defined as the sum of the phase currents |L1 + L2 + L3|, 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 3 characteristic. 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 criterion is not required, address 1204 is set to . In earthed power systems the earth fault detection can be complemented by a zero sequence voltage detection 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 62 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection Settings. If you want to detect only the earth current, set 3I0> OR 3U0> and also 3U0> Threshold (address 1204) to . 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 influence 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 Seriescompensated 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 4 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 63 Functions 2.2 Distance Protection 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 O (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 O (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 O-O 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 O-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 conditions. 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. NOTE i When testing a single earth fault by means of a test equipment, it must be made sure that the phase-tophase 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 protection during heavy load flow, a load trapezoid characteristic may be set for tripping characteristics with large Rreaches, 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 characteristic (optional) and Section 2.2.3 Distance protection with MHO characteristic (optional)). The R value R load (O-E) (address 1241) refers to the phase-to-earth loops, R load (O-O) (address 1243) to the phase-to-phase loops. The values are set somewhat (approx. 10 %) below the minimum expected 64 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection load impedance. The minimum load impedance appears when the maximum load current and minimum operating 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 = 525 A max 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 (O-O) = 97,98 primar = 10,69 sekundar R load (O-E) = 97,98 primar = 10,69 sekundar The spread angle of the load trapezoid characteristic load (O-E) (address 1242) and load (O-O) (address 1244) must be greater (approx. 5) than the maximum arising load angle (corresponding to the minimum power factor cos). Minimum power factor (example) cos min = 0.63 max = 51 Setting value load (O-O) = max + 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 max = 1732 A minimum operating voltage Umin = 0,9 UN Current Transformer 2000 A/5 A SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 65 Functions 2.2 Distance Protection Voltage Transformer 400 kV/0,1 kV Setting parameter 1.54 RE/RL 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 max calculated above. Ratio between E on healthy line and max 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 secondary 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 (O-O) = 108 primary = 10,8 secondary R load (O-E) = 53,5 primary = 5,35 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). 2.2.1.4 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". 66 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 1201 FCT Distance 1202 Minimum Iph> 1203 3I0> Threshold 1204 3U0> Threshold 1205 Setting Options Default Setting Comments ON OFF ON Distance protection 1A 0.05 .. 4.00 A 0.10 A 5A 0.25 .. 20.00 A 0.50 A Phase Current threshold for dist. meas. 1A 0.05 .. 4.00 A 0.10 A 5A 0.25 .. 20.00 A 0.50 A 1 .. 100 V; 5V 3U0 threshold zero seq. voltage pickup 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 O Block lagging O All loops O-O loops only O-E loops only Block leading O 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C 3I0 threshold for neutral current pickup 67 Functions 2.2 Distance Protection Addr. Parameter C Setting Options Default Setting Comments 1241 R load (O-E) 1A 0.100 .. 600.000 ; 5A 0.020 .. 120.000 ; R load, minimum Load Impedance (ph-e) 20 .. 60 45 PHI load, maximum Load Angle (ph-e) 1A 0.100 .. 600.000 ; 5A 0.020 .. 120.000 ; R load, minimum Load Impedance (ph-ph) 1242 load (O-E) 1243 R load (O-O) 1244 load (O-O) 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 2.2.1.5 Information List No. Information Type of Information 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 68 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 69 Functions 2.2 Distance Protection No. Information Type of Information 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 2.2.2 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). 70 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 2.2.2.1 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 Dist. A load trapezoid with the setting RLoad and Load 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; Dist, RLoad and Load are common for all zones. The parallelogram is symmetrical with respect to the origin of the R-X-coordinate 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 71 Functions 2.2 Distance Protection 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-toearth 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 1) with Loop Measuring Current (Direction) Actual short-circuit voltage Unfaulted voltage L1-E L1 UL1-E UL2 - UL3 L2-E L2 UL2-E UL3 - UL1 L3-E L3 UL3-E UL1 - UL2 L1-E1) L1 - E UL1-E UL2 - UL3 L2-E1) L2 - E UL2-E UL3 - UL1 L3-E1) L3 - E UL3-E UL1 - UL2 L1-L2 L1 - L2 UL1 - UL2 UL2-L3 - UL3-L1 L2-L3 L2 - L3 UL2 - UL3 UL3-L1 - UL1-L2 L3-L1 L3 - L1 UL3 - UL1 UL1-L2 - UL2-L3 1) 1) 1) consideration of earth impedance compensation If there is neither a current measured voltage nor a memorized voltage available which is sufficient for measuring 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 characteristic 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). 72 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [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 inception. 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 impedance diagram by the source impedance ZS1 = E1/1. 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 2 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 additionally be rotated by the load angle. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 73 Functions 2.2 Distance Protection [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 a) b) Voltage characteristic while a fault occurs after a series capacitor without pickup of the protective spark gap 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. 74 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [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. teleprotection 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 75 Functions 2.2 Distance Protection In total, the following zones are available: Independent zones: * 1st zone (fast tripping zone) Z1 with X(Z1); R(Z1) O-O, RE(Z1) O-E, may be delayed by T1-1phase or T1-multi-phase, * 2nd zone (backup zone) Z2 withX(Z2); R(Z2) O-O, RE(Z2) O-E, may be delayed by T2-1phase or. T2-multi-phase, * * * 3rd zone (backup zone) Z3 with X(Z3); R(Z3) O-O, RE(Z3) O-E, may be delayed by T3 DELAY, * 4th zone (backup zone) Z4 with X(Z4); R(Z4) O-O, RE(Z4) O-E, may be delayed by T4 DELAY, 5th zone (backup zone) Z5 with X(Z5)+ (forward) and X(Z5)- (reverse); R(Z5) O-O, RE(Z5) O-E, may be delayed by T5 DELAY. 6th zone (backup zone) Z6 with X(Z6)+ (forward) and X(Z6)- (reverse), R(Z6) O-O, RE(Z6) O-E, may be delayed by T6 DELAY. Dependent (controlled) zone: * Overreaching zone Z1B with X(Z1B); R(Z1B) O-O, RE(Z1B) O-E, may be delayed by T1B-1phase or T1B-multi-phase. 2.2.2.2 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 /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 resetting 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 s1, s2 Setting the reach - example for device A 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] 76 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 (Lange) R1/s = 35 km = 0.19 /km X1/s = 0.42 /km R0/s = 0.53 /km X0/s = 1.19 /km Current Transformer 600 A/5 A Voltage transformer 110 kV/0.1 kV The following line data is calculated: RL = 0.19 /km * 35 km = 6.65 XL = 0.42 /km * 35 km = 14.70 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 = 12.49 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 resistances, 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-tophase 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 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 * 1,2 = 4,8 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 77 Functions 2.2 Distance Protection 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 1 and E are in phase opposition): [formel-resistanzef-wlk-040624, 1, en_GB] with 78 RRE Resistance measured by the SIPROTEC distance protection RL1 Line resistance up to the fault location RArc Arc resistance RE/RL Setting in the distance protection (address 1116 and 1118) 2/1 Ratio 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". SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 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) O-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 with 2/1 =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 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] SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 79 Functions 2.2 Distance Protection 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) i 0.5 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 R = Grading factor = reach of zone Z1 in relation to the line length = 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) U = Voltage transformer angle error (typical: 1) I = 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 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 nondirectional -, 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) O-O (address 1302) for the R intersection of the polygon applicable to phase-to-phase faults, X(Z1) (address 1303) for the X intersection (reach), RE(Z1) O-E (address 1304) for the R intersection applicable to phase-to-earth faults and delay time settings. 80 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection If a fault resistance at the fault location (arc, tower footing etc.) causes a voltage drop in the measured impedance 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 presence 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 = (A + B) * RF If A and B have equal phase, then UF and A 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, A and B 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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 81 Functions 2.2 Distance Protection With a load angle of 20 and a setting R/X = 2.5 (R1 = 25 , X1 = 10 ), 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) O-O (address 1312), RE(Z2) O-E (address 1314); X(Z3) (address 1323), R(Z3) O-O (address 1322), RE(Z3) O-E (address 1324); X(Z4) (address 1333), R(Z4) O-O (address 1332), RE(Z4) O-E (address 1334); X(Z5)+ (address1343) for forward direction, X(Z5)- (address 1346) for reverse direction, R(Z5) O-O (address 1342), RE(Z5) O-E (address 1344); X(Z6)+ (address 1363) for forward direction, X(Z6)- (address 1366) for reverse direction, R(Z6) O-O (address 1362), RE(Z6) O-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 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 sufficient 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 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) O-O, address 1353 X(Z1B), address 1354 RE(Z1B) O-E. The delay times for single-phase and multiple-phase faults can again be set separately: T1B-1phase (address 1355) and T1Bmulti-phase (address 1356). If parameter Op. mode Z1B is set to Forward or Reverse, a non-direc- 82 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 activated 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 threeterminal 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 Prerequisites" 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 overreaching 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 phaseto-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. 2.2.2.3 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 secondary nominal current of the current transformer. Addr. Parameter 1301 Op. mode Z1 1302 R(Z1) O-O 1303 X(Z1) 1304 RE(Z1) O-E C Setting Options Default Setting Comments Forward Reverse Non-Directional Inactive Forward Operating mode Z1 1A 0.050 .. 600.000 1.250 5A 0.010 .. 120.000 0.250 R(Z1), Resistance for phph-faults 1A 0.050 .. 600.000 2.500 X(Z1), Reactance 5A 0.010 .. 120.000 0.500 1A 0.050 .. 600.000 2.500 5A 0.010 .. 120.000 0.500 RE(Z1), Resistance for ph-e faults 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 83 Functions 2.2 Distance Protection Addr. Parameter 1308 Iph>(Z1) 1311 Op. mode Z2 1312 R(Z2) O-O 1313 1314 X(Z2) RE(Z2) O-E C Setting Options Default Setting Comments 1A 0.05 .. 20.00 A 0.20 A 5A 0.25 .. 100.00 A 1.00 A Minimum current for Z1 only Iph>(Z1) Forward Reverse Non-Directional Inactive Forward Operating mode Z2 1A 0.050 .. 600.000 2.500 5A 0.010 .. 120.000 0.500 R(Z2), Resistance for phph-faults 1A 0.050 .. 600.000 5.000 X(Z2), Reactance 5A 0.010 .. 120.000 1.000 1A 0.050 .. 600.000 5.000 5A 0.010 .. 120.000 1.000 RE(Z2), Resistance for ph-e 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 1321 Op. mode Z3 Forward Reverse Non-Directional Inactive Reverse Operating mode Z3 1322 R(Z3) O-O 1A 0.050 .. 600.000 5.000 5A 0.010 .. 120.000 1.000 R(Z3), Resistance for phph-faults 1A 0.050 .. 600.000 10.000 X(Z3), Reactance 5A 0.010 .. 120.000 2.000 1A 0.050 .. 600.000 10.000 5A 1323 X(Z3) 1324 RE(Z3) O-E 0.010 .. 120.000 2.000 RE(Z3), Resistance for ph-e faults 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) O-O 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 R(Z4), Resistance for phph-faults 1333 X(Z4) 1A 0.050 .. 600.000 12.000 X(Z4), Reactance 5A 0.010 .. 120.000 2.400 1334 RE(Z4) O-E 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 RE(Z4), Resistance for ph-e faults 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) O-O 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 R(Z5), Resistance for phph-faults 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 1343 84 X(Z5)+ X(Z5)+, Reactance for Forward direction SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection Addr. Parameter C Setting Options Default Setting Comments 1344 RE(Z5) O-E 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 RE(Z5), Resistance for ph-e faults 0.00 .. 30.00 sec; 0.90 sec T5 delay 1A 0.050 .. 600.000 4.000 5A 0.010 .. 120.000 0.800 X(Z5)-, Reactance for Reverse direction Forward Reverse Non-Directional Inactive Forward Operating mode Z1B (overrreach zone) 1A 0.050 .. 600.000 1.500 5A 0.010 .. 120.000 0.300 R(Z1B), Resistance for phph-faults 1A 0.050 .. 600.000 3.000 X(Z1B), Reactance 5A 0.010 .. 120.000 0.600 1A 0.050 .. 600.000 3.000 5A 1345 T5 DELAY 1346 X(Z5)- 1351 Op. mode Z1B 1352 R(Z1B) O-O 1353 X(Z1B) 1354 RE(Z1B) O-E 0.010 .. 120.000 0.600 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) O-O 1A 0.050 .. 600.000 15.000 5A 0.010 .. 120.000 3.000 R(Z6), Resistance for phph-faults 1A 0.050 .. 600.000 15.000 5A 0.010 .. 120.000 3.000 1A 0.050 .. 600.000 15.000 5A 0.010 .. 120.000 3.000 RE(Z6), Resistance for ph-e faults 1363 1364 X(Z6)+ RE(Z6) O-E 1365 T6 DELAY 1366 X(Z6)- 2.2.3 RE(Z1B), Resistance for phe faults X(Z6)+, Reactance for Forward direction 0.00 .. 30.00 sec; 1.50 sec T6 delay 1A 0.050 .. 600.000 4.000 5A 0.010 .. 120.000 0.800 X(Z6)-, Reactance for Reverse direction 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 characteristic (optional). 2.2.3.1 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 impedance loop. The basic shape of an MHO characteristic is shown in Figure 2-30 as an example of a zone. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 85 Functions 2.2 Distance Protection 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 Line. A load trapezoid with the setting RLoad and Load 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 Dist as well as the load impedance parameters RLoad, and Loadare 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 characteristic 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 memorized 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-toearth 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. 86 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [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 impedance diagram by the polarization quantity k*ZS1 = k*E1/1. 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 impedance is in the reverse direction. All fault locations right up to the device mounting location (current transformers) 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 2 which is determined by the source impedance 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 87 Functions 2.2 Distance Protection [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 insufficiently 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 88 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 a) b) Voltage characteristic while a fault occurs after a series capacitor without pickup of the protective spark gap 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 proportion of up to 80 % could be necessary. This, however, would lead to a considerable increase of the MHO characteristic. 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 89 Functions 2.2 Distance Protection [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 Z1 and Z2 (Figure 2-35). These phasors result from the difference between the two zeniths of the circle diameter and the fault impedance. The zenith Zr corresponds to the set value for the zone under consideration (Zr and MHO as shown in Figure 2-30), the zenith k*ZS corresponds to the polarization magnitude. Therefore the difference phasors are Z1 = ZF - Zr Z2 = 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 groer, auerhalb kleiner als 90. 90 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 91 Functions 2.2 Distance Protection * * * * * * 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. 2.2.3.2 Setting Notes General The function parameters for the MHO characteristic only apply if during the configuration of the scope of functions the MHO characteristic was selected for phase-to-phase measurement (address 112) and/or phasetoearth 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 /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 resetting 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 s1, s2 Setting the reach - example for device A 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: 92 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection [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) R1/s = 35 km = 0,19 /km X1/s = 0,42 /km R0/s = 0,53 /km X0/s = 1,19 /km Current Transformer Voltage Transformer 600 A/5 A 110 kV/0,1 kV The following line data is calculated: RL = 0,19 /km * 35 km = 6,65 XL = 0,42 /km * 35 km = 14,70 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 = 12,49 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 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 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 93 Functions 2.2 Distance Protection 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. NOTE i 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 activated 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 threeterminal 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 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 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 determined 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. 94 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection These parameters have an impact on the expansion of the characteristics dependent on the source impedance. 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 available if address 119 Iph>(Z1) is set to Enabled. 2.2.3.3 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 secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 1305 T1-1phase C 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 5A 0.25 .. 100.00 A 1.00 A Minimum current for Z1 only Iph>(Z1) 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 2.500 ZR(Z1), Impedance Reach 5A 0.010 .. 40.000 0.500 Forward Reverse Inactive Forward Operating mode Z2 1A 0.050 .. 200.000 5.000 ZR(Z2), Impedance Reach 5A 0.010 .. 40.000 1.000 Forward Reverse Inactive Reverse 1411 Op. mode Z2 1412 ZR(Z2) 1421 Op. mode Z3 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Operating mode Z3 95 Functions 2.2 Distance Protection Addr. Parameter C Setting Options Default Setting Comments 1422 ZR(Z3) 1A 0.050 .. 200.000 5.000 ZR(Z3), Impedance Reach 5A 0.010 .. 40.000 1.000 Forward Reverse Inactive Forward Operating mode Z4 1A 0.050 .. 200.000 10.000 ZR(Z4), Impedance Reach 5A 0.010 .. 40.000 2.000 Forward Reverse Inactive Inactive Operating mode Z5 1A 0.050 .. 200.000 10.000 ZR(Z5), Impedance Reach 5A 0.010 .. 40.000 2.000 Forward Reverse Inactive Forward Operating mode Z1B (extended zone) 1A 0.050 .. 200.000 3.000 ZR(Z1B), Impedance Reach 5A 0.010 .. 40.000 0.600 Forward Reverse Inactive Inactive Operating mode Z6 1A 0.050 .. 200.000 15.000 ZR(Z6), Impedance Reach 5A 0.010 .. 40.000 3.000 1431 Op. mode Z4 1432 ZR(Z4) 1441 Op. mode Z5 1442 ZR(Z5) 1451 Op. mode Z1B 1452 ZR(Z1B) 1461 Op. mode Z6 1462 ZR(Z6) 1471A Mem.Polariz.PhE 0.0 .. 100.0 % 15.0 % Voltage Memory polarization (phase-e) 1472A CrossPolarizPhE 0.0 .. 100.0 % 15.0 % Cross polarization (phasee) 1473A Mem.Polariz.P-P 0.0 .. 100.0 % 15.0 % Voltage Memory polarization (ph-ph) 1474A CrossPolarizP-P 0.0 .. 100.0 % 15.0 % Cross polarization (phasephase) 2.2.4 Tripping Logic of the Distance Protection 2.2.4.1 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. teleprotection 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 96 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 97 Functions 2.2 Distance Protection [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 98 Tripping logic for the 4th, 5th, and 6th zone, shown for Z4 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 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 overreaching 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 Disabled). 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 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 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 automatic 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 99 Functions 2.2 Distance Protection [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. 100 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.2 Distance Protection 2.2.4.2 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 101 Functions 2.3 Power swing detection (optional) 2.3 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. 2.3.1 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 electrical 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. 2.3.2 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: 102 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.3 Power swing detection (optional) * 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 R and X features a change of direction within one measuring window. A fault usually causes a change of direction in R as well as in X within one measuring window. * Trajectory continuity: During a power swing, the distance between two subsequent impedance values features a clear change in R or X. In case of a fault, the impedance vector jumps to the fault impedance without moving afterwards. * Trajectory uniformity: During a power swing, the ratio between two subsequent changes of R or X 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 detection 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 (at N = 1 A) or 1 (at N = 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 (at IN = 1 A) or 1 (at IN = 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 103 Functions 2.3 Power swing detection (optional) [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 associated 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 2-47 104 Blocking logic of the power swing supplement SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.3 Power swing detection (optional) Power Swing Tripping If tripping in the event of an unstable power swing (out-of-step condition) is desired, the parameter PowerSwing 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 characteristic 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. 2.3.3 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 105 Functions 2.3 Power swing detection (optional) i NOTE The power swing supplement works together with the impedance pickup and is only available in this combination. 2.3.4 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 2.3.5 Information List No. Information Type of Information 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 2 106 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.4 Protection data interfaces and communication topology (optional) 2.4 Protection data interfaces and communication topology (optional) Where a teleprotection scheme is to be used to achieve 100 % instantaneous protection (Section 2.6 Teleprotection 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 communication paths to the protection data interfaces of the devices. 2.4.1 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 margin 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 communication 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 communication chain can be formed. The number of devices (address 147 NUMBER OF RELAY) must correspond to SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 107 Functions 2.4 Protection data interfaces and communication topology (optional) 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. Otherwise, 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 transmission 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 replaceable. 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 information, please refer to the Appendix under "Ordering Information and Accessories". i 108 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 deterministic 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.4 Protection data interfaces and communication topology (optional) [bsp-kom-verbin-180510-wlk, 1, en_GB] Figure 2-52 i Examples for communication connections NOTE The redundancy of different communication connections (for ring topology) requires a consistent separation 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 corresponding 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 109 Functions 2.4 Protection data interfaces and communication topology (optional) 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. 2.4.2 Setting Notes General Protection data interfaces connect the devices with the communication media. The communication is permanently 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 transmission path), the message PI1 TD alarm will be issued. 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. 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). 110 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.4 Protection data interfaces and communication topology (optional) An ID number is also to be given to each single device (device-ID). The device-ID is used by the communication 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 111 Functions 2.4 Protection data interfaces and communication topology (optional) [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 conditions 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 teleprotection schemes are automatically switched from 3 to 2 ends. If no remote end is available, Dis.T.Carr.Fail is signalled. 2.4.3 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 1 112 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.4 Protection data interfaces and communication topology (optional) 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 2.4.4 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 113 Functions 2.4 Protection data interfaces and communication topology (optional) No. Information Type of Information 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 114 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.5 Remote signals via protection data interface (optional) 2.5 Remote signals via protection data interface (optional) 2.5.1 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 information to all other devices at the ends of the protected object, even if the topology is incomplete. Where selection 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 communication 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. 2.5.2 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 115 Functions 2.5 Remote signals via protection data interface (optional) No. Information Type of Information 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 116 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection 2.6 Teleprotection for distance protection 2.6.1 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 protection, 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 unverzogerte und selektive Abschaltung durch den Distanzschutz zu erreichen, kann der Distanzschutz durch Signalubertragungsverfahren Informationen mit der Gegenstation austauschen und sie weiterverwenden. Dies kann uber 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 singlepole 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 segregated. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 117 Functions 2.6 Teleprotection for distance protection 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 transmission 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. 2.6.2 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 2.6.3 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. 118 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection [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 characteristic (optional) under the margin heading "Independent Zones Z1 up to Z6" and "Controlled Zone Z1B"). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 119 Functions 2.6 Teleprotection for distance protection [logikdia-der-mitnahme-ueber-z1b-ein-leitungsende-konv-skg, 1, en_GB] Figure 2-57 120 Logic diagram of the permissive underreach transfer trip (PUTT) using Z1B (one line end, conventional, no protection data interface) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection [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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 121 Functions 2.6 Teleprotection for distance protection 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 automatic 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 available in Z1B, the phase-selective release effected via the signal extension is stored. If the own distance protection 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. 2.6.4 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 approximately 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. 122 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection [funktionsschema-direkten-mitnahme-wlk-290702, 1, en_GB] Figure 2-59 2.6.5 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 123 Functions 2.6 Teleprotection for distance protection [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 automatic 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 automatic reclosure by setting parameter 1st AR -> Z1B, and by an external recloser device via the binary input >Enable ARzones. 124 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection [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, conventional, no protection data interface)) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 125 Functions 2.6 Teleprotection for distance protection [logikdia-signalvergleichsverfahrens-ein-leitungsende-240402-wlk, 1, en_GB] Figure 2-62 2.6.6 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. 126 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection 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 transmission. 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 overreaching 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 127 Functions 2.6 Teleprotection for distance protection 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 automatic 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 direction 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 tripping" 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 available in Z1B, the phase-selective release effected via the signal extension is stored. If the own distance protection pickup in Z1B drops out, it will be deleted. 128 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection [logikdiagramm-unblockverfs-1-leitungsende-wlk-300702, 1, en_GB] Figure 2-64 Send and enabling logic of the unblocking scheme SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 129 Functions 2.6 Teleprotection for distance protection [unblock-logik-240402-wlk, 1, en_GB] Figure 2-65 2.6.7 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 transmitted signal at the fault location may be so severe that reception at the other line end cannot necessarily be guaranteed. 130 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 131 Functions 2.6 Teleprotection for distance protection [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. 132 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection 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 direction 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. 2.6.8 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 2.6.9 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 133 Functions 2.6 Teleprotection for distance protection 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 protection 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 protection 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 detection with the simultaneous reception of a signal from the teleprotection scheme logic, as shown in the corresponding 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 2-69 134 Generation of the echo release signal SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection 2.6.10 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 parameters 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 Teleprotection for distance protection: Direct Underreach Transfer Trip PUTT (Z1B) POTT UNBLOCKING BLOCKING Remote trip without any pickup, Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT), Permissive Overreach Transfer Trip (POTT), Directional Unblocking scheme, 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): Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT) Permissive Overreach Transfer Trip (POTT) PUTT (Z1B) 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// 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 135 Functions 2.6 Teleprotection for distance protection 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 transmission 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 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 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 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 expiration 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. 136 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.6 Teleprotection for distance protection i NOTE The ECHO SIGNAL (No. 4246) must be allocated separately to the output relays for the transmitter actuation, 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 transmitted as a separate signal without taking any special measures.enthalten. 2.6.11 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 protection 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 2.6.12 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 137 Functions 2.6 Teleprotection for distance protection No. Information Type of Information 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 138 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 2.7 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 requirements. 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 determined 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. 2.7.1 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*0 = L1 + L2 + L3. Depending on the version ordered, and the configured application for the fourth current input 4 of the device, the zero-sequence current can be measured or calculated. If input 4 is connected in the starpoint of the set of current transformers or to a separate earth current transformer 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 4, this current 4 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 4 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 zerosequence 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. Naturally, all three phase-to-earth voltages obtained from a set of three star-connected voltage transformers must be available and connected to the device. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 139 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Definite time very high set current stage 30>>> The triple zero-sequence current 30 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 30>>> 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, NonDirectional or Inactive. 140 * 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) [logikdia-der-3i0svgstufe-240402wlk, 1, en_GB] Figure 2-71 Logic diagram of the 30>>>-stage Definite time high set current stage 30>> The logic of the high-set current stage 30>> is the same as that of the 30>>>-stage. In all references 3I0>>> must merely be replaced with 3I0>>. In all other respects Figure 2-71 applies. Definite time overcurrent stage 30> The logic of the overcurrent stage 30> too, is the same as that of the 30>>>-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 paragraph) to definite-time stage. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 141 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Inverse time overcurrent stage 30P 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 beginning 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.TDELAY 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. 142 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) [logikdia-der-3i0p-stufe-abhaengiger-umz-240402-wlk, 1, en_GB] Figure 2-72 Logic diagram of the 30P stage (inverse time overcurrent protection), example for IEC characteristics 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 MaxTDELAY 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 MinTDELAY can be determined; below this time no tripping can occur. Below a current factor of 3I0p Startpoint, 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 143 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) [logikdia-der-3i0p-stufe-der-log-inv-kennlinie-240402-wlk, 1, en_GB] Figure 2-73 Logic diagram of the 30P 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 144 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 zerosequence voltage is too low or the voltage transformer circuit breaker is tripped, this stage is also disabled. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 145 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 comp, which is also referred to as compensated zero-sequence power, i.e. Sr = 3 0*3 U0*cos( - comp) with = (U0; 0). comp thus determines the direction of the maximum sensitivity (cos( - comp) = 1, wenn = comp). 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 = comp) and in time direction by a factor k. [logikdia-nullleistungsschutz-wlk-090902, 1, en_GB] Figure 2-75 146 Zero-sequence power protection SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Figure 2-75 shows the logic diagram. The tripping time depends on the level of the compensated zerosequence power Sr as defined above. For meshed earthed systems the zero-sequence voltage and the zerosequence 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 transformer and for devices without separate earth current transformer, inrush blocking is only effective if the earth current is higher than 0.41 N or if the current of the 2nd harmonic is higher than 0.041 N. 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 E (= -3*0), which is compared to a reference voltage UP. The voltage required for direction determination UP may be derived from the starpoint current Y of an earthed transformer (source transformer), provided that the transformer is available. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 147 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Moreover, both the zero-sequence voltage 3*U0 and the starpoint current Y 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 Y. 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 starpoint current is measured. For the determination of direction, a minimum current 30 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 measuring 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. 148 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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*0 [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*0 * 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 zerosequence 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 30 and 3U0, the negative sequence signals 32 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 singlepole 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 compensated 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 comp, i.e. Sr = 30*3U0*cos( - comp). The direction determination yields SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 149 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) * * forward if Sr is positive and Sr > S VORWARTS, reverse if Sr is negative and |Sr| > S VORWARTS. The determination of direction requires a minimum current 30 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 multiphase. If the fault is single-phase, the faulted phase is selected. The phase selector is blocked during a singlepole 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 150 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 151 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 maintained 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 2-81 152 Logic diagram of single-pole tripping with phase selector SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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. 2.7.2 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 153 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 singlepole dead time. If the corresponding stage is to be blocked, the setting YES remains unchanged. If not, set No (non-dir.). 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 tripping 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 30>>- and 30>>> stages are best suited for fast tripping stages (instantaneous), as these stages use an abridged filter with shorter response time. Whereas, the stages 30> and 30P 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. 154 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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-Directional (in both directions). If the stage is not required, set its mode to Inactive. For the inverse time overcurrent stage 30P 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 30P 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-Directional (in both directions). If the stage is not required, set its mode to Inactive. For the inverse time overcurrent stage 30P 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 30P 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 155 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 NonDirectional (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) determines 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 30 = 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 2-82 156 Curve parameters in the logarithmic-inverse characteristic SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 directions). 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 characteristic 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 additional 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 157 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 = 30 * 3U0 * cos( - comp) The angle comp 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 = comp. 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 3 0>> stage directional with a short or no delay time and the 3 0> stage with the same pickup threshold, but a longer delay time as directional backup stage. The 3 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 E = -3 0, whose angle is compared with a reference quantity. The desired reference quantity is set in POLARIZATION (address 3160): The default setting U0 + IY or U2 is universal. The device then selects automatically whether the reference 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 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 Y as reference signal, apply the setting with IY only . This makes sense if a reliable transformer starpoint current Y is always available at the device input 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 4 of normal sensitivity and that the current from the transformer starpoint infeed is connected to 4. If direction determination is to be carried out using exclusively the negative sequence system signals 3 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. 158 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 determination, this setting is of no consequence. The set threshold should not be exceeded by asymmetries in the operational 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 voltagecontrolled 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 determination. 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 direction 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 characteristic 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 159 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) [netz-1pol-erdkurzschluss-20101104, 1, en_GB] Figure 2-84 Z1A, Z2A, Z0A Z1B, Z2B, Z0B ZL, Z0L ZF Power system diagram and symmetrical components for a single-pole earth fault in reverse direction Source impedance side A, symmetrical components Source impedance side B, symmetrical components Line impedance, positive sequence and zerosequence impedance Fault impedance For the protection of lines whose zero-sequence impedance is significantly higher than the infeed zerosequence impedance (Z 0L + Z 0B > Z 0A in Figure 2-84 ), the following setting is recommended for parameter3186 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. 160 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) 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 protection (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 30 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 teleprotection to allow undelayed release of the tripping during internal faults. For the 30> 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 corresponding parameter is set to NO, therefore, in this example: address 3123 3I0>> Telep/BI for stage 30>>, address 3113 3I0>>> Telep/BI for stage 30>>>, address 3148 3I0p Telep/BI for stage 30P (if used). If the echo function is used in conjunction with the teleprotection scheme, or if the weak-infeed tripping function 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 shortcircuit 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 transformers. 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 generated. 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 transformer 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 parameter 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 161 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) (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 disabled 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). 2.7.3 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 secondary nominal current of the current transformer. Addr. Parameter 3101 C Setting Options Default Setting Comments 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 5A 0.05 .. 5.00 A 2.50 A 3Io-Min threshold for Teleprot. schemes 3105 3IoMin Teleprot 1A 0.003 .. 1.000 A 0.500 A 5A 0.015 .. 5.000 A 2.500 A 3Io-Min threshold for Teleprot. schemes 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 Teleprot./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 162 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Addr. Parameter 3117 C Setting Options Default Setting Comments 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 Teleprot./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> 3I0> Pickup 3131 3I0> 1A 0.05 .. 25.00 A 1.00 A 5A 0.25 .. 125.00 A 5.00 A 1A 0.003 .. 25.000 A 1.000 A 5A 0.015 .. 125.000 A 5.000 A 3I0> Pickup 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 Teleprot./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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 163 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Addr. Parameter 3140 Setting Options Default Setting Comments 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 1A 0.003 .. 25.000 A 1.000 A 5A 0.015 .. 125.000 A 5.000 A 1A 0.003 .. 25.000 A 1.000 A 5A 0.015 .. 125.000 A 5.000 A 1A 0.05 .. 25.00 A 1.00 A 5A 0.25 .. 125.00 A 5.00 A 1A 0.003 .. 25.000 A 1.000 A 5A 0.015 .. 125.000 A 5.000 A 1A 0.05 .. 25.00 A 1.00 A 5A 0.25 .. 125.00 A 5.00 A 1A 0.003 .. 25.000 A 1.000 A 5A 0.015 .. 125.000 A 5.000 A 1A 0.05 .. 25.00 A 1.00 A 5A 0.25 .. 125.00 A 5.00 A 3141 3I0p PICKUP 3141 3I0p PICKUP 3141 3I0p PICKUP 3141 3I0p PICKUP 3141 3I0p PICKUP 3141 3I0p PICKUP 3141 3I0p PICKUP C 3I0p Pickup 3I0p Pickup 3I0p Pickup 3I0p Pickup 3I0p Pickup 3I0p Pickup 3I0p Pickup 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 Teleprot./BI 3148 3I0p Telep/BI NO YES NO Instantaneous trip via Teleprot./BI 3148 3I0p Telep/BI NO YES NO Instantaneous trip via Teleprot./BI 3148 3I0p Telep/BI NO YES NO Instantaneous trip via Teleprot./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 164 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Addr. Parameter 3149 C Setting Options Default Setting Comments 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 characteristic 3155 k 0.00 .. 3.00 sec 0.50 sec k-factor for Sr-characteristic 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 165 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) Addr. Parameter 3160 Setting Options Default Setting Comments 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 5A 0.25 .. 5.00 A 0.25 A Min. earth current IY for polarizing 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 5A 0.25 .. 5.00 A 0.25 A Min. neg. seq. polarizing current 3I2 3168 PHI comp 0 .. 360 255 Compensation angle PHI comp. for Sr 3169 S forward 1A 0.1 .. 10.0 VA 0.3 VA 5A 0.5 .. 50.0 VA 1.5 VA Forward direction power threshold 10 .. 45 % 15 % 2nd harmonic ratio for inrush restraint 1A 0.50 .. 25.00 A 7.50 A 5A 2.50 .. 125.00 A 37.50 A Max.Current, overriding inrush restraint 3170 2nd InrushRest 3171 Imax InrushRest C 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 direction 3187A XserCap 1A 0.000 .. 600.000 0.000 5A 0.000 .. 120.000 0.000 Reactance X of series capacitor 2.7.4 Information List No. Information Type of Information Comments 1305 >EF BLK 3I0>>> SP >Earth Fault O/C Block 3I0>>> 166 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.7 Earth fault overcurrent protection in earthed systems (optional) No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 167 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 2.8 Teleprotection for earth fault overcurrent protection (optional) 2.8.1 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 comparison 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 singlephase 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 identified 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 conventional 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 168 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 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 2.8.2 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 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 opposite 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". SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 169 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 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 direction 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. 170 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) [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 interface. 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 171 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) [logikdia-ef-richtverglsverf-1-ende-mitwss-171102-wlk, 1, en_GB] Figure 2-88 2.8.3 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. 172 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) Principle The unblocking method is a permissive scheme. It differs from the directional comparison 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 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 transmission. 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 opposite 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 overcurrent 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 173 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 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 1or >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 direction 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 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 Section2.9.2 Classical Tripping. 174 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) [logikdiagramm-unblockverfs-1-ltgse-ef-wlk-300702, 1, en_GB] Figure 2-90 Logic diagram of the unblocking scheme (one line end) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 175 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) [unblock-logik-ef-wlk-190802, 1, en_GB] Figure 2-91 2.8.4 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 transmitted signal at the fault location may be so severe that reception at the other line end cannot necessarily be guaranteed. 176 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 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 overcurrent 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 177 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) [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 transmitted (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 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. 178 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) The occurrence of erroneous signals resulting from transients during clearance of external faults or from direction 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. 2.8.5 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 2.8.6 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 179 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 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 protection 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 2.8.7 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 Teleprotection for earth fault overcurrent protection (optional): Dir.Comp.Pickup UNBLOCKING 180 Directional comparison pickup, Directional unblocking scheme, SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) Directional blocking scheme. BLOCKING 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 Teleprot. 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 (EC 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 EB or EC must then be larger than in the situation described previously. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 181 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) [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 transmission 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 permanent 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 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 expiration 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. 182 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) 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 2.8.8 NOTE The ECHO SIGNAL (No 4246) must be allocated separately to the output relays for the transmitter actuation, 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 transmitted 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 2.8.9 Information List No. Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type of Information Comments 183 Functions 2.8 Teleprotection for earth fault overcurrent protection (optional) No. Information Type of Information 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 184 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.9 Measures for Weak and Zero Infeed 2.9 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. 2.9.1 Echo function 2.9.1.1 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 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 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 protection (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 distribution. 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 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 transmitted 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 protection, 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 therefore ineffective. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 185 Functions 2.9 Measures for Weak and Zero Infeed [logik-echofkt-signal-100422-wlk, 1, en_GB] Figure 2-98 Logic diagram of the echo function with teleprotection 2.9.2 Classical Tripping 2.9.2.1 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 activation of the echo function (see Section 2.6 Teleprotection for distance protection).This provides the permissive 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 Teleprotection for earth fault overcurrent protection (optional)). Auch beim Erdkurzschlussschutz kann mit den Ubertragungsverfahren nach dem Freigabeprinzip am speisenden Leitungsende mit Hilfe der Echofunktion (siehe Abschnitt 2.8 Teleprotection for earth fault overcurrent protection (optional)) das Auslosekommando 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 function to release the infeeding line end is activated (refer also to Section 2.6 Teleprotection for distance protection 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 . 186 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.9 Measures for Weak and Zero Infeed 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 40ms 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 detection, the function cannot pick up anymore once a fault detection in the affected phase was present (RS flipflop 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 exclusively earth fault protection issues a release condition. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 187 Functions 2.9 Measures for Weak and Zero Infeed [logik-ase-hiko-20100422, 1, en_GB] Figure 2-99 *) 188 Logic diagram of the weak infeed tripping Where the distance protection and the earth fault protection function share the same transmission 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.9 Measures for Weak and Zero Infeed 2.9.2.2 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 overcurrent protection (optional)). The receive signal is a functional component of the trip condition. Accordingly, the weak infeed tripping function 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 overreach 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 protection 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 189 Functions 2.9 Measures for Weak and Zero Infeed 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 NOTE The ECHO SIGNAL (No. 4246) must be allocated separately to the output relays for the transmitter actuation, 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 transmitted as a separate signal without taking any special measures. 2.9.3 Tripping According to French Specification 2.9.3.1 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. 190 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.9 Measures for Weak and Zero Infeed Non-delayed Tripping [logikdiagramm-ase-unverz-wlk-151002, 1, en_GB] Figure 2-100 Logic diagram for non-delayed tripping SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 191 Functions 2.9 Measures for Weak and Zero Infeed Trip with Delay [logikdiagramm-ase-verz-wlk-151002, 1, en_GB] Figure 2-101 2.9.3.2 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. 192 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.9 Measures for Weak and Zero Infeed 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. . 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 undervoltage is determined for all 3 phases. If the measured phase-to-phase voltage falls below the threshold (address 1131 PoleOpenVoltage), undervoltage 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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 193 Functions 2.9 Measures for Weak and Zero Infeed * Address 2517 1pol. Trip enables a single-pole trip command for phase-to-ground faults if it is parameterised 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 multipole 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 permanently 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. 2.9.4 Tables on Classical Tripping and Tripping according to French Specification 2.9.4.1 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 secondary nominal current of the current transformer. Addr. Parameter 2501 Setting Options Default Setting Comments 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. 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. 2514 3I0> Threshold 2515 TM 194 C 0.00 .. 30.00 sec 0.60 sec 3I0> exceeded extension 1A 0.05 .. 1.00 A 0.50 A 5A 0.25 .. 5.00 A 2.50 A 3I0 threshold for neutral current pickup 0.00 .. 30.00 sec 0.40 sec WI delay single pole SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.9 Measures for Weak and Zero Infeed Addr. Parameter 2516 2517 Setting Options Default Setting Comments TT 0.00 .. 30.00 sec 1.00 sec WI delay multi pole 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 2.9.4.2 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C 195 Functions 2.10 External direct and remote tripping 2.10 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. 2.10.1 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 tripping 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 teleprotection function for the transmission of the signal as this already incorporates the optional extension of the transmitted 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. 196 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.10 External direct and remote tripping 2.10.2 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. 2.10.3 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 2.10.4 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 197 Functions 2.11 Overcurrent protection (optional) 2.11 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. 2.11.1 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 interruption of the voltage transformer secondary circuits (emergency operation). The emergency operation therefore replaces the distance protection as short circuit protection if loss of the measured voltage signal is recognized 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 overcurrent 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 . 2.11.2 Functional Description Measured values The phase currents are fed to the device via the input transformers of the measuring input. Earth current 3*0 is either measured directly or calculated depending on the ordered device version and usage of the fourth current input 4 of the device. If 4 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 4, this current 4 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. 1.6A. In the event of larger currents, the device automatically switches over to 198 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) 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 4 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 >> 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 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 199 Functions 2.11 Overcurrent protection (optional) [logikdiagramm-i-vg-stufe-wlk-310702, 1, en_GB] Figure 2-104 1) 2) Logic diagram of the stage The output indications associated with the pickup signals can be found in Table 2-5 The output indications associated with the trip signals can be found in Table 2-6 Definite time overcurrent stage > The logic of the overcurrent stage is the same as that of the 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 P 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. 200 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) [logikdia-ip-stufe-amz-iec-wlk-310702, 1, en_GB] Figure 2-105 1) 2) Logic diagram of the P stage (inverse time overcurrent protection), for example IEC characteristics The output indications associated with the pickup signals can be found in Table 2-5 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 particular importance with the 11/2 circuit breaker arrangements. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 201 Functions 2.11 Overcurrent protection (optional) [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 A and/or B flows while the line isolator 1 is open, this implies that a fault in the stub range between the current transformers A, B 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 A + B 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 operated 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). 202 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) [logikdiagramm-endfehlerschutz-wlk-310702, 1, en_GB] Figure 2-107 1) 2) Logic diagram of stub fault protection The output indications associated with the pickup signals can be found in Table 2-5 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 typically 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 203 Functions 2.11 Overcurrent protection (optional) This function is independent of the high-current instantaneous tripping described in Section 2.12 Instantaneous 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 >> Trip L1 Figure O/C Pickup L1 7162 O/C Pickup L2 7163 O/C Pickup L3 7164 O/C Pickup E 7165 O/C PICKUP I>> 7191 O/C PICKUP I> 7192 Figure 2-105 Figure 2-105 Figure 2-105 Figure 2-105 O/C PICKUP Ip 7193 Figure 2-107 Figure 2-107 Figure 2-107 Figure 2-107 I-STUB PICKUP 7201 O/C PICKUP 7161 >>> Trip L1 Figure 2-105 Figure 2-107 >> Trip L2 Figure 2-104 > Trip L2 >>> Trip L2 Figure 2-105 Figure 2-107 >> Trip L3 Figure 2-104 p Trip L2 > Trip L3 >>> Trip L3 Figure 2-105 Figure 2-107 >> Trip E Figure 2-104 p Trip L3 > Trip E p TripE >>> Trip E >> Trip L1 >> Trip L2 >> Trip L3 >> Trip E No. Figure 2-104 > Trip L1 p Trip L1 Output Indication Figure 2-105 Figure 2-107 Figure 2-104 Figure 2-104 Figure 2-104 Figure 2-104 > Trip L1 > Trip L2 > Trip L3 > Trip E p Trip L1 p Trip L2 p Trip L3 p Trip E >>> Trip L1 >>> Trip L2 >>> Trip L3 >>> Trip E (All pickups) 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 indicated in case of single-pole tripping (refer also to Section 2.20.1 Function Control "Tripping Logic of the Entire Device"). 204 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) Table 2-6 Trip signals of the single phases Internal Indication >> OFF L1 Figure > OFF L1 >>> OFF L1 Figure 2-105 Figure 2-107 >> OFF L2 Figure 2-104 p OFF L1 > OFF L2 >>> OFF L2 Figure 2-105 Figure 2-107 >> OFF L3 Figure 2-104 p OFF L2 > OFF L3 >>> OFF L3 Figure 2-105 Figure 2-107 >> OFF E Figure 2-104 p OFF L3 > OFF E p OFFE >>> OFF E >> OFF L1 >> OFF L2 >> OFF L3 >> OFF E Output Indication No. Figure 2-104 O/C TRIP 1p.L1 or O/C TRIP L123 7212 or 7215 O/C TRIP 1p.L2 or O/C TRIP L123 7213 or 7215 O/C TRIP 1p.L3 or O/C TRIP L123 7214 or 7215 O/C TRIP L123 7215 O/C TRIP I>> 7221 O/C TRIP I> 7222 Figure 2-105 Figure 2-105 Figure 2-105 Figure 2-105 O/C TRIP Ip 7223 Figure 2-107 Figure 2-107 Figure 2-107 Figure 2-107 I-STUB TRIP 7235 O/C TRIP 7211 Figure 2-105 Figure 2-107 Figure 2-104 Figure 2-104 Figure 2-104 Figure 2-104 > OFF L1 > OFF L2 > OFF L3 > OFF E p OFF L1 p OFF L2 p OFF L3 p OFF E >>> OFF L1 >>> OFF L2 >>> OFF L3 >>> OFF E (General TRIP) 2.11.3 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 205 Functions 2.11 Overcurrent protection (optional) 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 overcurrents, 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 transformers. 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 ph>>, 30>> The >>-stages Iph>> (address 2610) and 3I0>> PICKUP (address 2612) together with the >-stages or the p 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 >> stages always operate with a defined delay time. If the >> stages are used for instantaneous tripping before the automatic reclosure (via CFC interconnection), the current setting corresponds to the > or p 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 reclosure 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), the>> 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) R1/s = 60 km = 0.19 /km X1/s = 0.42 /km Short-circuit power at the beginning of the line: Sk' = 2.5 GVA Current Transformer 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 /km * 60 km = 27.66 [formel-ueberstromzeit-hochstrom-1-oz-010802, 1, en_GB] The 3-phase short-circuit current at the end of the line is k end: 206 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) [formel-ueberstromzeit-hochstrom-2-oz-010802, 1, en_GB] With a safety factor of 10%, the following primary setting value is calculated: Setting value >> = 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 >> 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 >>-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 ph>, 30> 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 max = 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 > = 1.1 * 630 A = 693 A With settings in secondary quantities the following setting value is calculated: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 207 Functions 2.11 Overcurrent protection (optional) [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 measured 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 operating 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 > 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 > 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 transients during line energization. Overcurrent Stages P, 30P 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 incorporated. 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 P = 630 A, Secondary: Set value P = 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 separate 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. 208 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) 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 protection. 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 P 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 P, 30P 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 incorporated. 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 incorporated. 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 P = 630 A, Secondary: Setting value P = 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 separate 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 protection. 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 P 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 209 Functions 2.11 Overcurrent protection (optional) 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 ph>>> When using the >>> 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 A and B, 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 ISTUB Telep/BI = YES you determine that the >>>-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 >>>-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 protection function solely depends on the position of the isolator. 2.11.4 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 2601 Operating Mode 2610 Iph>> 2611 T Iph>> 2612 3I0>> PICKUP C Setting Options Default Setting Comments ON:with VT loss ON:always activ OFF ON:with VT loss Operating mode 1A 0.05 .. 50.00 A; 2.00 A Iph>> Pickup 5A 0.25 .. 250.00 A; 10.00 A 0.00 .. 30.00 sec; 0.30 sec T Iph>> Time delay 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> 2622 3I0> 210 0.00 .. 30.00 sec; 0.50 sec T Iph> Time delay 1A 0.05 .. 25.00 A; 0.20 A 3I0> Pickup 5A 0.25 .. 125.00 A; 1.00 A SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.11 Overcurrent protection (optional) Addr. Parameter 2623 2624 Setting Options Default Setting Comments T 3I0> 0.00 .. 30.00 sec; 2.00 sec T 3I0> Time delay I> Telep/BI NO YES NO Instantaneous trip via Teleprot./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 2632 3I0> STUB C 0.00 .. 30.00 sec; 0.30 sec T Iph STUB Time delay 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 Teleprot./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 2650 3I0p PICKUP 2652 T 3I0p TimeDial 2653 2656 0.00 .. 30.00 sec 0.00 sec T Ip Additional Time Delay 1A 0.05 .. 4.00 A; A 3I0p Pickup 5A 0.25 .. 20.00 A; A 0.05 .. 3.00 sec; 0.50 sec T 3I0p Time Dial TimeDial TD3I0p 0.50 .. 15.00 ; 5.00 Time Dial TD 3I0p 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 Teleprot./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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 211 Functions 2.11 Overcurrent protection (optional) 2.11.5 Information List No. Information Type of Information 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 212 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.12 Instantaneous high-current switch-on-to-fault protection (SOTF) 2.12 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. 2.12.1 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 "Energization", 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 213 Functions 2.12 Instantaneous high-current switch-on-to-fault protection (SOTF) 2.12.2 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. 2.12.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 2401 FCT SOTF-O/C 2404 I>>> C Setting Options Default Setting Comments ON OFF ON Inst. High Speed SOTF-O/C is 1A 0.10 .. 25.00 A 2.50 A I>>> Pickup 5A 0.50 .. 125.00 A 12.50 A 2.12.4 Information List No. Information Type of Information 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 214 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 2.13 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 automatic 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 overhead line/cable), it must be ensured that reclosure can only be performed in the event of a fault on the overhead 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. 2.13.1 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 215 Functions 2.13 Automatic reclosure function (optional) 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 reclosure 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 overreaching 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 faultdirection comparison protection (Section 2.8 Teleprotection for earth fault overcurrent protection (optional)). 216 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) If, however, the signal transmission is switched off or the transmission path is disturbed, the internal automatic 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 tripping of the protection functions can be established via the binary inputs and outputs or the integrated userdefinable 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 OPENCLOSE- 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 automatic 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 recommended 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 necessary 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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 217 Functions 2.13 Automatic reclosure function (optional) * * * 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 automatic 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 determines 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 functions 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 endgultigen trip or other events which block the auto reclose function after it has been 218 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 pressure 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 monitoring 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 219 Functions 2.13 Automatic reclosure function (optional) 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 1pole 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 1pole 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 3pole 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 220 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 1pole 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 intervention 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 permissible reclosure, following a protection stage that is valid without auto-reclosure. The automatic reclosing function 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 221 Functions 2.13 Automatic reclosure function (optional) * 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 3pole. 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 initiated, 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 3pole trip command due to the tripping logic (Section 2.20.1 Function Control), independent of this forced 3pole 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 interface (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 externally 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 procedure. 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: 222 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 A, B, C I, II, III X Example of a reduced dead time (RDT) Busbars Relay locations 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 transformers 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 reclosure until one of the reclosure attempts is successful or a final trip takes place. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 223 Functions 2.13 Automatic reclosure function (optional) [beispiel-asp-wlk-310702, 1, en_GB] Figure 2-113 A, B, C I, II, III X Example of adaptive dead time (ADT) Busbars Relay locations 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 reclosure 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 reclosure 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). 224 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 382 >Only 1ph AR 381 >1p Trip Perm With this binary input, the external reclosure device controls stages of the individual 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 Reclosure"). 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 protection or comparison mode with distance protection, see also margin heading "Selectivity before Reclosure", above). 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 functions 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 225 Functions 2.13 Automatic reclosure function (optional) [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 automatic 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: 226 2711 >AR Start Generalanregung fur die Wiedereinschaltautomatik (nur fur Wirkzeit benotigt), 2712 >Trip L1 AR Auslosekommando L1 fur die Wiedereinschaltautomatik, 2713 >Trip L2 AR Auslosekommando L2 fur die Wiedereinschaltautomatik, 2714 >Trip L3 AR Auslosekommando L3 fur die Wiedereinschaltautomatik. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) The general pickup is decisive for starting the action times. It is also required if the automatic reclosing function 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 2889 AR 1.CycZoneRel 2820 AR Program1pole Internal automatic reclosure function ready for 1-pole reclose cycle, i.e. allows 1-pole tripping (logic inversion of the 3-pole coupling). Internal automatic reclosure function ready for the first reclose cycle, i.e. releases the stage of the external protection device for reclosure, the corresponding 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). 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: 2715 >Trip 1pole AR General fault detection for the internal automatic reclosure function (only required for action time), Trip command 1-pole for the internal automatic reclosure function, 2716 >Trip 3pole AR Trip command 3-pole for the internal automatic reclosure function. 2711 >AR Start 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 protection 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 227 Functions 2.13 Automatic reclosure function (optional) [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 tripping (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 228 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 monitoring 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 BI M K *) Connection example for 2 protection devices with 2 automatic reclosure functions Binary inputs Signal output Command for all protection functions operating with AR. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 229 Functions 2.13 Automatic reclosure function (optional) [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 2-122 230 Setting of the software filter time SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 2.13.2 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 interrogation 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 problems 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 mechanism 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 231 Functions 2.13 Automatic reclosure function (optional) 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 interpreted as an evolving fault. With EV. FLT. RECOG. with TRIP a fault during a dead time is only interpreted 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 autoreclosure, 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 1pole 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 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 T2TRIP(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 adaptive 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 transport until the remote end has also closed. Therefore this delay must be added to the dead time for consideration 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. 232 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 1pole trip or if the CB auxiliary contacts report an implausible circuit breaker state (see also Section 2.13 Automatic 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 parameters 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 Ustable 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 adaptive 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 configuration 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 functionality 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 233 Functions 2.13 Automatic reclosure function (optional) 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 protection 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 meantime 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 tripping 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 Ulive> 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 3pole 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". 234 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 protection functions, the action time may also be omitted; this applies especially when an initiating protection function 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 tripping is of course only possible if the device and the corresponding protection function are also capable of 1pole tripping: Table 2-7 AR control mode = TRIP ... 3456 1.AR Tdead1Trip 3457 1.AR Tdead3Trip is the dead time after 1-pole tripping. 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 3454 1.AR Tdead 2Flt is the dead time after 1-phase pickup. 3455 1.AR Tdead 3Flt is the dead time after 3-phase pickup. is the dead time after 2-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 "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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 235 Functions 2.13 Automatic reclosure function (optional) 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 configuration of the scope of protection functions. For the 2nd cycle: 3461 2.AR: START 3462 2.AR: T-ACTION Start in 2nd cycle generally allowed 3464 2.AR Tdead 1Flt 3465 2.AR Tdead 2Flt Dead time after 1-phase pickup 3466 2.AR Tdead 3Flt 3467 2.AR Tdead1Trip Dead time after 3-phase pickup 3468 2.AR Tdead3Trip 3469 2.AR: Tdead EV. Dead time after 3-pole tripping 3470 2.AR: CB? CLOSE 3471 2.AR SynRequest CB ready interrogation before reclosing Action time for the 2nd cycle Dead time after 2-phase pickup Dead time after 1-pole tripping Dead time after evolving fault Sync. check after 3-pole tripping For the 3rd cycle: 3472 3.AR: START 3473 3.AR: T-ACTION Start in 3rd cycle generally allowed 3475 3.AR Tdead 1Flt 3476 3.AR Tdead 2Flt Dead time after 1-phase pickup 3477 3.AR Tdead 3Flt 3478 3.AR Tdead1Trip Dead time after 3-phase pickup 3479 3.AR Tdead3Trip 3480 3.AR: Tdead EV. Dead time after 3-pole tripping 3481 3.AR: CB? CLOSE 3482 3.AR SynRequest CB ready interrogation before reclosing Action time for the 3rd cycle Dead time after 2-phase pickup Dead time after 1-pole tripping Dead time after evolving fault Sync. check after 3-pole tripping For the 4th cycle: 3483 4.AR: START 3484 4.AR: T-ACTION Start in 4th cycle generally allowed 3486 4.AR Tdead 1Flt 3487 4.AR Tdead 2Flt Dead time after 1-phase pickup 3488 4.AR Tdead 3Flt 3489 4.AR Tdead1Trip Dead time after 3-phase pickup 3490 4.AR Tdead3Trip 3491 4.AR: Tdead EV. Dead time after 3-pole tripping 3492 4.AR: CB? CLOSE 3493 4.AR SynRequest CB ready interrogation before reclosing Action time for the 4th cycle Dead time after 2-phase pickup Dead time after 1-pole tripping Dead time after evolving fault 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. 236 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 operational 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). 2.13.3 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 237 Functions 2.13 Automatic reclosure function (optional) 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 overcurrent 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 238 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 239 Functions 2.13 Automatic reclosure function (optional) 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 2.13.4 Information List No. Information Type of Information 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 240 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.13 Automatic reclosure function (optional) No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 241 Functions 2.14 Synchronism and voltage check (optional) 2.14 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 determines the time for issuing the close command such that the voltages are identical the instant the breaker poles make contact. 2.14.1 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 transformers (Figure 2-124), its vector group can be compensated for by the 7SA522 relay, so that no external matching transformers are necessary. 242 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.14 Synchronism and voltage check (optional) [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 automatic 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 verified before checking the conditions for synchronism. After the synchronism check grants the release, the interlocking 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 function 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 automatic 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 function control (Section 2.20.1 Function Control) issues a measuring request provided that this was configured 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 conditions for manual closure apply (parameter MC...). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 243 Functions 2.14 Synchronism and voltage check (optional) * 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. DURATION. 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 difference AR maxFreq.Diff or MC maxFreq.Diff or angle difference AR maxAngleDiff or MC maxAngleDiff 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 function outputs "CO- " (refer also to Section 2.22.1 Control Authorization). 244 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.14 Synchronism and voltage check (optional) [logik-synchrocheck-seite1, 1, en_GB] SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 245 Functions 2.14 Synchronism and voltage check (optional) [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. Released if measuring point Usy1> is energized and the measuring point Usy2< is de-energized. Released if measuring point Usy1< is de-energized and the measuring point Usy2< is also de-energized. Released without any check. AR Usy1>Usy2< AR Usy1<Usy2< AR OVERRIDE The closing check for manual reclosing is possible in one of the following operating modes: 246 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.14 Synchronism and voltage check (optional) 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. Released if measuring point Usy1> is energized and the measuring point Usy2< is de-energized. Released if measuring point Usy1< is de-energized and the measuring point Usy2< is also de-energized. Released without any check. MC Usy1> Usy2< MC Usy1< Usy2< MC OVERRIDE 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 |sy1 - sy2| within the permissible tolerance AR maxAngleDiff or MC maxAngleDiff? 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 247 Functions 2.14 Synchronism and voltage check (optional) 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. 2.14.2 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 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 (fN3 Hz); nominal operational voltage of the primary power system (phase-phase) in kV; 1103 FullScaleVolt. and, if switching under asynchronous system conditions is allowed, 239 T-CB close 248 the closing time of the circuit breaker. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.14 Synchronism and voltage check (optional) ! 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). Otherwise, 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 dif=) 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. Moreover, 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 Freigabe. 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 249 Functions 2.14 Synchronism and voltage check (optional) 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 3516 AR Usy1<Usy2> 3517 AR Usy1>Usy2< 3518 AR Usy1<Usy2< 3519 AR OVERRIDE both measuring points Usy1 and Usy2 must be energized (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; 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) ; 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); both measuring points Usy1 and Usy2 must be de-energized ( Dead Volt. Thr., address 3502); 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 Synccheck, no checks are performed before manual closing. For commands through the integrated control (local, DIGSI, serial interface), address 3509 SyncCB determines 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. 250 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.14 Synchronism and voltage check (optional) 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 3536 MC Usy1< Usy2> 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; 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 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 251 Functions 2.14 Synchronism and voltage check (optional) 2.14.3 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 5V 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 (Einstellmoglichkeiten anwendungsabhangig) 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 252 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.14 Synchronism and voltage check (optional) 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 5V 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 (Einstellmoglichkeiten anwendungsabhangig) 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 253 Functions 2.14 Synchronism and voltage check (optional) 2.14.4 Information List No. Information Type of Information 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. -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 sy2>sy1 OUT SYNC PHIdiff too large (PHIsy2>PHIsy1) 2983 SYNC sy2<sy1 OUT SYNC PHIdiff too large (PHIsy2<PHIsy1) 254 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) 2.15 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 disconnected 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. 2.15.1 Overvoltage Protection Phase-to-earth overvoltage Figure 2-126 depicts the logic diagram of the phase voltage stages. The fundamental component is numerically 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 Uphe>(>) TRIP. The phase-to-earth overvoltage protection can be blocked via a binary input >Uph-e>(>) BLK. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 255 Functions 2.15 Under and over-voltage protection (optional) [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. 256 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 257 Functions 2.15 Under and over-voltage protection (optional) 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, Meas the measured current at the local line end, CL the line capacitance, RL the line resistance, LL the 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. 258 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) [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 asymmetrical voltage failure was detected ("Fuse-Failure-Monitor", also see Section 2.19.1 Measurement Supervision, 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 automatically 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"). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 259 Functions 2.15 Under and over-voltage protection (optional) 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 automatically 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. 260 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) [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. 2.15.2 Undervoltage Protection Undervoltage Phase-to-earth Figure 2-131 depicts the logic diagram of the phase voltage stages. The fundamental component is numerically 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 261 Functions 2.15 Under and over-voltage protection (optional) 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 Uphe< (address 3753) or T Uph-e<< (address 3755) is signalled and usually results in the trip commandUphe<(<) 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-FailureMonitor", also see Section 2.19.1 Measurement Supervision) or if the trip of the mcb of the voltage transformers 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 automatically 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. 262 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) [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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 263 Functions 2.15 Under and over-voltage protection (optional) 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 automatically 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 ("FuseFailure-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. 264 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) [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. 2.15.3 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 265 Functions 2.15 Under and over-voltage protection (optional) i NOTE For overvoltage protection it is particularly important to observe the setting notes: NEVER set an overvoltage 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 steadystate 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 overvoltage 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, weakloaded 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 overvoltages 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 calculation. 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. 266 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) 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 detection 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-toearth 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 addition 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 Connection". 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 implemented 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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 267 Functions 2.15 Under and over-voltage protection (optional) * 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 phaseto-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 thresholds. 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 criterion 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 criterion CURR.SUP.Uphph< (address 3768) is switched ON. With busbar side voltage transformers it can be 268 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) 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 criterion 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. 2.15.4 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 overvoltage 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 overvoltage 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) overvoltage 3722 3U0> 1.0 .. 220.0 V; 30.0 V 3U0> Pickup (or Ux>) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 269 Functions 2.15 Under and over-voltage protection (optional) 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-Measurement 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 undervoltage 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 undervoltage 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 270 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) 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 2.15.5 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 271 Functions 2.15 Under and over-voltage protection (optional) No. Information Type of Information 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 272 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.15 Under and over-voltage protection (optional) No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 273 Functions 2.16 Frequency protection (optional) 2.16 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 conditions. 2.16.1 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 overfrequency stage f>. * If a stage is set to a value below the rated frequency, it is automatically interpreted to be an underfrequency 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 proportional to the frequency and is practically linear in the specified range (fN 10 %). Filters and repeated measurements 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 f/dt remains unchanged during several repeated measurements. If, however, a phase jump in the measured voltage temporarily simulates a frequency deviation, the sign of f/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 sufficiently 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). 274 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.16 Frequency protection (optional) 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 measurement 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 configured 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 decision 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 immediately 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 275 Functions 2.16 Frequency protection (optional) [logikdiagramm-frequenzschutz-wlk-190802, 1, en_GB] Figure 2-133 Logic diagram of the frequency protection 2.16.2 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 overfrequency 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: 276 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.16 Frequency protection (optional) * * * 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 irregular frequency deviations. Pickup values, delay time The configured pickup value determines whether a frequency stage is to respond to overfrequency or underfrequency. * If a stage is set to a value above the rated frequency, it is automatically interpreted to be an overfrequencystage f>. * If a stage is set to a value below the rated frequency, it is automatically interpreted to be an underfrequency 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. 20mHz, 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 277 Functions 2.16 Frequency protection (optional) 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. 2.16.3 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 2.16.4 Information List No. Information Type of Information 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 278 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.16 Frequency protection (optional) No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 279 Functions 2.17 Fault locator 2.17 Fault locator The measurement of the distance to a fault is an important supplement to the protection functions. Availability of the line for power transmission within the system can be increased when the fault is located. 2.17.1 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 annunciationFlt.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 protection, 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 primary and secondary, * 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. Fault resistance R in primary and 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 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 allocated 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 annunciationBCD 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. 280 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.17 Fault locator 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 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 impedance are influenced by the mutual coupling of the earth impedance of both parallel lines. This causes measuring 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 influence 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 4 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 F2 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 impedance 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 M E1, E2 Fault currents and voltages on double-end fed lines : Measuring point : Source voltage (EMF) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 281 Functions 2.17 Fault locator IF1, IF2 IF1 + IF2 UF1 RF ZF1, ZF2 ZF1E, ZF2E ZS1, ZS2 ZS1E, ZS2E : Partial fault currents : Total fault current : Fault voltage at the measuring point : Common fault resistance : Fault impedances : Earth fault impedances : Source impedances : Earth source impedances 2.17.2 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 calculation 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 /km or /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 4 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 overhead 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 terminated immediately even when it occurs before this time has expired. Allocate the corresponding output relays 282 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.17 Fault locator 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. 2.17.3 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 2.17.4 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 283 Functions 2.18 Circuit breaker failure protection (optional) 2.18 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. 2.18.1 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 monitoring 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). 284 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) [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 interruption 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 E (3*0) 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*0 = L1 + L2 + L3 Additionally, the value calculated by 7SA522 of three times the negative sequence current 3*2 is used for plausibility check. This is calculated according to the equation: 3*2 = L1 + a2*L2 + a*L3 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 parameterized 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 >BFactivate3I0>. 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 parameterized earth current threshold is also used for the phase current monitoring (Figure 2-137). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 285 Functions 2.18 Circuit breaker failure protection (optional) [logik-strmflsueberw-plausibilitaet-110113, 1, en_GB] Figure 2-137 1) Current flow monitoring with plausibility currents 3*0 und 3*2 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 protection, the circuit breaker is assumed to be open as soon as the current disappears, even if the associated auxiliary 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. 286 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) [logik-verriegel-hikos-wlk-010802, 1, en_GB] Figure 2-138 1) 2) Interlock of the auxiliary contact criterion - example for phase L1 if phase-segregated auxiliary contacts are available 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 recommended 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 auxiliary 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 287 Functions 2.18 Circuit breaker failure protection (optional) [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 ", 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 criterion. 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 1pole. 288 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) 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 fur Anwurf von externem Schutzgerat mit Freigabe durch einen getrennten Satz Auslosekontakte 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 289 Functions 2.18 Circuit breaker failure protection (optional) 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 conditions. Initiation can be blocked via the binary input >BLOCK BkrFail (e.g. during test of the feeder protection relay). [logik-7vk61-anwurfbed-1-pol-ausloese, 1, en_GB] Figure 2-143 290 Initiation conditions for single-pole trip commands SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) 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 adjacent 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 291 Functions 2.18 Circuit breaker failure protection (optional) [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. 292 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) [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 adjacent 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 (= measurement 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 applicable, 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 protection is initiated and current flow is detected (current criteria "L*> current criterion" according to Figure 2-137), SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 293 Functions 2.18 Circuit breaker failure protection (optional) 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 2.18.2 Setting Notes General The circuit breaker failure protection and its ancillary functions (end fault protection, pole discrepancy supervision) 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. 294 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) 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 criterion 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, i * 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. 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 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 295 Functions 2.18 Circuit breaker failure protection (optional) [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 tolerance 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 2-152 296 Time sequence example for normal clearance of a fault, and with circuit breaker failure, using single-stage breaker failure protection SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) 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 condition 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 automatic 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. 2.18.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 3901 FCT BreakerFail 3902 I> BF 3903 1p-RETRIP (T1) 3904 T1-1pole SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C Setting Options Default Setting Comments ON OFF ON Breaker Failure Protection 1A 0.05 .. 20.00 A 0.10 A Pick-up threshold I> 5A 0.25 .. 100.00 A 0.50 A NO YES YES 1pole retrip with stage T1 (local trip) 0.00 .. 30.00 sec; 0.00 sec T1, Delay after 1pole start (local trip) 297 Functions 2.18 Circuit breaker failure protection (optional) Addr. Parameter 3905 C Setting Options Default Setting Comments 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 supervision 3932 T-PoleDiscrep. 0.00 .. 30.00 sec; 2.00 sec Trip delay with pole discrepancy 2.18.4 Information List No. Information Type of Information 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 298 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.18 Circuit breaker failure protection (optional) No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 299 Functions 2.19 Monitoring Functions 2.19 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. 2.19.1 Measurement Supervision 2.19.1.1 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 undershooting 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 immediately 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 indications 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 inadmissibly 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. 300 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions 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 F = |L1 + L2 + L3 + k*E| > I THRESHOLD + I FACTOR* | | Factor k (address 221 I4/Iph CT) takes into account a possible different ratio of a separate E transformer (e.g. cable core balance current transformer). I THRESHOLD and I FACTOR. are setting parameters. The I FACTOR | | 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). | | is the sum of all currents: | | = |L1| + |L2| + |L3| + |k*E| This fault is signaled as Failure I (no. 162). i NOTE Current sum monitoring can operate properly only when the residual current of the protected line is fed to the fourth current input (4) 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 U Ph-E (no. 165). i NOTE Voltage sum monitoring is only effective if an external displacement voltage is connected to the displacement voltage measuring input. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 301 Functions 2.19 Monitoring Functions 2.19.1.2 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 discovered. 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"). 2.19.1.3 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 monitored in the device by magnitude comparison. The smallest phase current is compared to the largest phase current. Asymmetry is recognized if: |min| / |max| < BAL. FACTOR I as long as max > BALANCE I LIMIT max is the highest, min 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 302 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions 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 monitored in the device by magnitude comparison. The smallest phase voltage is compared to the largest. Asymmetry 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". SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 303 Functions 2.19 Monitoring Functions [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 sufficiently 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 reliable 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 evaluated 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 immediately 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 zerosequence current or the negative-sequence current, but only through the fact that the voltages in the zerosequence 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. 304 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions 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 differential 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 FuseFail (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 ). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 305 Functions 2.19 Monitoring Functions The effect of the signals VT FuseFail (No. 170) and VT FuseFail>10s (No. 169) on the protection functions 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 transformers are not connected), the absence of the voltage can be detected and reported by an additional monitoring 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 transformer 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. 306 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions The O/C emergency operation is possible during the voltage failure, provided that the O/C protection is parameterized 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 2.19.1.4 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, A = 200 und B = 340 have been set. If the measured phase angle (S1) of the positive sequence power is innerhalb the area of the P-Q plane delimited by the angles A and B, the indication (PQ Pos. Seq.) (No. 130) is output. The angles A and B can be freely set in the range between 0 and 359. The area starts at A and extends in a mathematically positive sense as far as the angle B. A hysteresis of 2 is provided to prevent erroneous indications which might emerge at the threshold limits. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 307 Functions 2.19 Monitoring Functions [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 . 308 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions [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 Set wrong (No. 132 is output. The following conditions must be fulfilled for measurement to be enabled: * The positive sequence current 1is 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 A and 2942 B must be at least 3 apart. Incorrect parameter settings cause the indication 132 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 (PQ Pos) block (No. 131). Figure 2-162 shows the logic of the positive sequence system phase angle monitoring. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 309 Functions 2.19 Monitoring Functions [logikphasenwinkelueberwachung-wlk-040514, 1, en_GB] Figure 2-162 2.19.1.5 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 Auxiliary Supply Voltage Loss External (aux. voltage) internal (converter) Device out of operation or All LEDs dark alarm Error 5V (144) Measured Value Acquis- Internal (converter or refer- Protection out of operaition ence voltage) tion, alarm Indication (No.) Output DOK2) drops LED "ERROR" DOK2) drops as allocated Buffer battery Internal (battery) Indication Hardware Watchdog Internal (processor failure) Device not in operation Error A/D-conv. (181) Fail Battery (177) LED "ERROR" Software-Watchdog Internal (program sequence) Restart attempt 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 310 1) DOK2) drops SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions Monitoring Possible Causes Malfunction Response Indication (No.) Output 1 A/5 A setting 1/5 A jumper wrong Messages: Protection out of operation DOK2) drops Adjustment values Internal (EEPROM or RAM) Indication: Use of default values Error1A/5Awrong (192) Error A/Dconv. (181) LED "ERROR" Alarm adjustm. (193) ADC offse Internal (ADC) Indication as allocated Earth current transformer sensitive/insensitive I/O module does not correspond to the order number (MLFB) of the device. Indications: Protection out of operation Modules Module does not comply with ordering number (MLFB). Indications: Protection out of operation Current sum Internal (measured value acquisition) Indication Error Offset (191) Error neutralCT (194), Error A/Dconv. (181) LED "ERROR" "Error Board BG1...7" (183 ... 189) and if applicable Error A/D-conv.. (181) Failure I (162) Current symmetry External (power system or current transformer) Indication Broken Conductor External (power system or current transformer) Indication Voltage sum Internal (measured value acquisition) Indication Voltage symmetry External (power system or voltage transformer) Indication Voltage phase sequence External (power system or connection) Indication Voltage failure, 3phase"Fuse-FailureMonitor" 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Fail I balance (163) Fail Conductor (195) Fail U Ph-E (165) Fail U balance (167) Fail Ph. Seq. (171) VT FuseFail>10s (169), VT FuseFail (170) as allocated DOK2) drops DOK2) drops as allocated as allocated as allocated as allocated as allocated as allocated as allocated 311 Functions 2.19 Monitoring Functions Monitoring Possible Causes Malfunction Response Voltage failure, 1-/2phase"Fuse-FailureMonitor" External (voltage transformers) Indication VT FuseFail>10s (169), Distance protection is blocked, VT FuseFail (170) Undervoltage protection is blocked, Weak-infeed tripping is blocked, Frequency protection is blocked, and Direction determination of the earth fault protection is blocked as allocated Voltage failure, 3-phase External (power system or connection) Indication Fail U absent (168) 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 as allocated Trip Circuit Monitoring Indication as allocated External (trip circuit or control voltage) 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 2.19.1.6 Indication (No.) FAIL: Trip cir. (6865) Output 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 I THRESHOLD determines the limit current above which the current sum monitoring is activated (absolute portion, only relative to N). The relative portion (relative to the maximum phase current) for 312 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions activating the current sum monitoring is set at 2907 I FACTOR. These settings can only be changed via DIGSI at Display Additional Settings. i NOTE Current sum monitoring can operate properly only when the residual current of the protected line is fed to the fourth current input (4) 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 transformers, 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 quantities required for measurement of the positive sequence power. The angles set in address 2941 A and 2942 B must be at least 3 apart. Incorrect parameter settings cause the indication 132 Set wrong to be output. 2.19.1.7 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 secondary nominal current of the current transformer. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 313 Functions 2.19 Monitoring Functions Addr. Parameter 2901 C Setting Options Default Setting Comments 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 I THRESHOLD 1A 0.05 .. 2.00 A 0.10 A 5A 0.25 .. 10.00 A 0.50 A Summated Current Monitoring Threshold 2907A I FACTOR 0.00 .. 0.95 0.10 Summated Current Monitoring 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 5A 0.25 .. 5.00 A 0.50 A Maximum Current Threshold I< 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 5A 0.25 .. 5.00 A 0.50 A Delta Current Threshold (3phase) 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 A 0 .. 359 200 Limit setting PhiA 2942 B 2943 I1> 2944 U1> 2.19.1.8 Information List No. Information Type of Information Comments 130 (PQ Pos. Seq.) OUT Load angle Phi(PQ Positive sequence) 131 (PQ Pos) block OUT Load angle Phi(PQ) blocked 132 Set wrong OUT Setting error: |PhiA - PhiB| < 3 161 Fail I Superv. OUT Failure: General Current Supervision 162 Failure I OUT Failure: Current Summation 163 Fail I balance OUT Failure: Current Balance 314 0 .. 359 340 Limit setting PhiB 1A 0.05 .. 2.00 A 0.05 A Minimum value I1> 5A 0.25 .. 10.00 A 0.25 A 2 .. 70 V 20 V Minimum value U1> SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions No. Information Type of Information Comments 164 Fail U Superv. OUT Failure: General Voltage Supervision 165 Fail 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 2.19.2 Trip circuit supervision 2.19.2.1 Functional Description Trip Circuit Supervision The 7SA522 incorporates an integrated trip circuit supervision function. Depending on the number of available 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 315 Functions 2.19 Monitoring Functions [prinzip-ausloesekrueb-2-be-wlk-010802, 1, en_GB] Figure 2-163 TR CB TC Aux1 Aux2 U-CTR U-BI1 U-BI2 Principle of the trip circuit supervision with two binary inputs Trip relay contact Circuit breaker Circuit breaker trip coil Circuit breaker auxiliary contact (NO contact) Circuit breaker auxiliary contact (NC contact) Control voltage (trip voltage) Input voltage of 1st binary input 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 transition 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 mechanism. 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 4 closed OFF open closed L H TR has tripped successfully Malfunction 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 316 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions 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 TR CB TC Aux1 Aux2 U-CTR U-BI R UR Principle of the trip circuit supervision with one binary input Trip relay contact Circuit breaker Circuit breaker trip coil Circuit breaker auxiliary contact (NO contact) Circuit breaker auxiliary contact (NC contact) Control voltage for trip circuit Input voltage of binary input Bypass resistor 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"). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 317 Functions 2.19 Monitoring Functions 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 2.19.2.2 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. 2.19.2.3 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 2.19.2.4 Information List No. Information Type of Information 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 318 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.19 Monitoring Functions No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 319 Functions 2.20 Function Control and Circuit Breaker Test 2.20 Function Control and Circuit Breaker Test 2.20.1 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, * * * * 2.20.1.1 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 corresponding 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 2-167 320 Logic diagram of the manual closing procedure SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test 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 automatically 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 CB TC CBaux Manual closure with internal automatic reclosure Circuit breaker Circuit breaker close coil 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 CB TC CBaux Manual closure with external automatic reclosure Circuit breaker Circuit breaker close coil Circuit breaker auxiliary contact SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 321 Functions 2.20 Function Control and Circuit Breaker Test 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 detection 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. Therefore, 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 PoleOpenVoltage) 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 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 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 energization, 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. 322 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test [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 configuration. 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. 2.20.1.2 Detection of the Circuit Breaker Position For Protection Purposes Information regarding the circuit breaker position is required by various protection and supplementary functions 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-tofault 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 323 Functions 2.20 Function Control and Circuit Breaker Test 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. 324 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test [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 automatic 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.: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 325 Functions 2.20 Function Control and Circuit Breaker Test * * * * * 2.20.1.3 >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 protection and monitoring functions can respond. The following figure shows the logic structure of an Open Pole Detector. 326 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test [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 - SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 327 Functions 2.20 Function Control and Circuit Breaker Test 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 available 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. 2.20.1.4 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 segregated 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 indications (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": PU Time: TRIP Time: dist =: 328 Protection function that picked up; Operating time from the general pickup to the dropout of the device, in ms; the operating time from general pickup to the first trip command of the device, in ms; Distance to fault in kilometers or miles derived by the distance to fault locator function (if possible). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test 2.20.1.5 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 function 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 functions 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 indications 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 O, i.e. single-pole tripping in the leading phase or 1pole lagging O, i.e. single-pole tripping in the lagging phase. Standard setting is 3pole tripping in the event of two-phase faults (default setting). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 329 Functions 2.20 Function Control and Circuit Breaker Test Table 2-11 Single-pole and three-pole trip depending on fault type Type of Fault (from Protection Function) L1 Parameter Trip2phFlt (any) L2 TRIP 1p. L1 L1 L2 L3 E (any) E (any) E (any) 3pole L2 L1 L2 1pole leading O L1 L2 1pole lagging O L2 L3 3pole L2 L3 1pole leading O L2 L3 1pole lagging O L1 L3 3pole L1 L3 1pole leading O L1 L3 1pole lagging O L2 L1 TRIP 1p.pol L3 Relay TRIP 3ph. X (any) L1 L2 TRIP 1p. L2 X (any) L3 L1 Output signals for trip X X X X X X X X X X X X X E (any) X L3 E (any) X L3 E (any) X L1 L2 L3 L1 L2 L3 (any) X 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 duration 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 330 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test 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- SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 331 Functions 2.20 Function Control and Circuit Breaker Test 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 userdefined 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. 332 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test [schalterfall-meldeunterdrueck-ablauf-wlk-020802, 1, en_GB] Figure 2-176 Breaker tripping alarm suppression -- sequence examples 2.20.2 Circuit breaker trip test The 7SA522 distance protection relay allows for convenient testing of the trip circuits and the circuit breakers. 2.20.2.1 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 procedure 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 333 Functions 2.20 Function Control and Circuit Breaker Test Table 2-12 Serial No. Circuit breaker test programs Test Programs Circuit Breaker Output Indications (No.) 1 1-pole TRIP/CLOSE-cycle phase L1 CB1-TESTtrip L1 (7325) 2 1-pole TRIP/CLOSE-cycle phase L2 CB1-TESTtrip L2 (7326) 3 1-pole TRIP/CLOSE-cycle phase L3 4 3-pole TRIP/CLOSE-cycle CB1-TESTtrip 123 (7328) Associated close command CB1-TEST CLOSE (7329) CB 1 CB1-TESTtrip L3 (7327) [ein-aus-pruefzyklus-wlk-170902, 1, en_GB] Figure 2-177 2.20.2.2 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". 2.20.2.3 Information List No. Information Type of Information 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 2.20.3 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. 334 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test 2.20.3.1 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 indications 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 335 Functions 2.20 Function Control and Circuit Breaker Test 2.20.3.2 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. 2.20.3.3 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 indications 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. 2.20.3.4 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 2.20.3.5 Information List No. Information Type of Information 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 1 336 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.20 Function Control and Circuit Breaker Test No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 337 Functions 2.20 Function Control and Circuit Breaker Test No. Information Type of Information 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 2.20.4 Ethernet EN100-Module 2.20.4.1 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 protocols. 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 environments. In addition to the process control integration of the device, this interface can also be used for communication with DIGSI and for interrelay communication via GOOSE messaging. 2.20.4.2 Setting Notes Interface selection No settings are required for operation of the Ethernet system interface module (IEC 61850 Ethernet EN100Modul). If the device is equipped with such a module (see MLFB), the module is automatically configured to the interface available for it. 2.20.4.3 Information List No. Information Type of Information 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) 338 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions 2.21 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. 2.21.1 Commissioning Aids 2.21.1.1 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 identify 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 339 Functions 2.21 Auxiliary Functions [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. 340 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions [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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 341 Functions 2.21 Auxiliary Functions 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 calculated 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 2.21.1.2 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 interface. 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 ***.***.***.***. 2.21.2 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: 2.21.2.1 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 342 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions * * * * 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 selfcheck 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 information 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 indications 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 L2 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 statistics, 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 343 Functions 2.21 Auxiliary Functions 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 identification 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 indications 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 344 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions 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 available 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: Uberlauf. 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 Description. 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. 2.21.3 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 345 Functions 2.21 Auxiliary Functions 2.21.3.1 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. 2.21.3.2 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 INDICATIONS -> STATISTICS by overwriting the counter values displayed. 2.21.3.3 Information List No. Information Type of Information 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 IL1 = VI Accumulation of interrupted current L1 1028 IL2 = VI Accumulation of interrupted current L2 1029 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 346 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions No. Information Type of Information 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 2.21.4 Measurement 2.21.4.1 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 EE, Y and P only the one which is connected to current measuring input 4 can apply. Phase-to-earth voltages can only be measured if the phase-to-earth voltage inputs are connected. The displacement voltage 3U0 is e-n-voltage multiplied 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 cos. 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 intervals of approx. 0.5 s Table 2-13 Operational measured values of the local device Measured Values primary secondary % referred to L1, L2, L3 Phase currents A A Rated operational current 1) EE Sensitive earth current A mA Rated operational current 3)1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 347 Functions 2.21 Auxiliary Functions Measured Values primary secondary % referred to 30 - calculated Earth current A A Rated operational current 1) 30 - measured Earth current A A Rated operational current 3)1) 1, 2 Positive and negative sequence compo- A nent of currents A Rated operational current 1) Y, P Transformer 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) 3U0 Displacement Voltage kV V Rated operational voltage / 32) U0 Zero-sequence voltage kV V Rated operational voltage / 32) U1, U2 Positive and negative sequence compo- kV nent of voltages V Rated operational voltage / 32) UX, Uen Voltage at measuring input U4 - V - Usy2 Voltage at measuring input U4 kV 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, Operational resistance of all loops - Operational reactance of all loops - Apparent, active and reactive power MVA, MW, MVAR - 3*UN*N operational rated quan- RL3-E, RL1-L2, RL1-L2, RL3-L1 XL1-E, XL2-E, XL3-E,XL1-L2, XL2-L3, XL3-L1 S, P, Q tities 1)2) f Frequency Hz Hz Rated system frequency cos Power factor (abs) (abs) - Usy1, Usy2, Udiff Measured voltage values (for synchronism check) kV - - fsy1, fsy2, fdiff Measured voltage values (for synchronism check) (fur Synchronkontrolle) Hz - - diff Betrag der Phasenwinkeldifferenz zwischen den Messstellen Usy1 und Usy2 - - (fur Synchronkontrolle) 1) according to address 1104 2) according to address 1103 3) considering 4) according 5) considering 348 factor 221 I4/Iph CT to address 212 Usy2 connection factor 215 Usy1/Usy2 ratio SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions 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) L1, L2, L3 remote Phase currents of the remote device A L1, L2, L3 local Phase currents of the local device A (L1), (L2), (L3) remote Phase angle of the phase currents of the remote device referred to the local voltage UL1-E (L1), (L2), (L3) 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 (UL1), (UL2) (UL3) Phase angle of the phase voltages of the remote device referred to the local voltage UL1-E Phase angle of the phase voltages of the local device referred to the local voltageUL1-E remote (UL1), (UL2) (UL3) local 2.21.4.2 Information List No. Information Type of Information 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 349 Functions 2.21 Auxiliary Functions No. Information Type of Information 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 -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 2.21.5 Oscillographic Fault Records 2.21.5.1 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", "tripping" are also represented. 350 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions 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. 2.21.5.2 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 reference 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. 2.21.5.3 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 351 Functions 2.21 Auxiliary Functions 2.21.5.4 Information List No. Information Type of Information Comments - FltRecSta IntSP Fault Recording Start 4 >Trig.Wave.Cap. SP >Trigger Waveform Capture 30053 Fault rec. run. OUT Fault recording is running 2.21.6 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. 2.21.6.1 Long-Term Average Values The long-term average values of the three phase currents Lx, the positive sequence component 1 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. 2.21.6.2 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 measured 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. 2.21.6.3 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 352 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions 2.21.6.4 Information List No. Information Type of Information 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 2.21.7 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. 2.21.7.1 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. 2.21.7.2 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. 2.21.7.3 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 2.21.7.4 Information List No. Information Type of Information Comments - ResMinMax IntSP_Ev Reset Minimum and Maximum counter SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 353 Functions 2.21 Auxiliary Functions No. Information Type of Information 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 354 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions No. Information Type of Information 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 2.21.8 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. 2.21.8.1 Limit value monitoring Set points can be set for the following measured and metered values: * * * * * * L1dmd>: Exceeding a preset maximum average value in Phase L1. L2dmd>: Exceeding a preset maximum average value in Phase L2. L3dmd>: Exceeding a preset maximum average value in Phase L3. 1dmd>: 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 355 Functions 2.21 Auxiliary Functions * * 2.21.8.2 Sdmd>: Exceeding a preset maximum average value of the apparent power. |cos|< 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. 2.21.8.3 Information List No. Information Type of Information 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 cos alarm OUT Power factor alarm 2.21.9 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 transferred to a central master station via the system interface. 2.21.9.1 Energy Metering 7SA522 integrates the calculated power as a function of time and then provides the results under the measured 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 Wp+ 356 Active power, output Primary kWh, MWh, GWh SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.21 Auxiliary Functions Measured values 2.21.9.2 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). 2.21.9.3 Information List No. Information Type of Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 357 Functions 2.22 Command Processing 2.22 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. 2.22.1 Control Authorization 2.22.1.1 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, communicating 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, - 2.22.1.2 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 358 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.22 Command Processing conditions can be configured separately for each device. The actual execution of the command is also monitored 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 initiated 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, * 2.22.1.3 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 359 Functions 2.22 Command Processing 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 parameter 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 positive 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. 360 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.22 Command Processing [standardveriegelungen-wlk-020802, 1, en_GB] Figure 2-189 1) (NAH FERN Standard interlockings Source of Command REMOTE includes LOCAL. Command using substation controller Command via telecontrol station to power system management and from power system management 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 (abbreviation) Display Control Authority SV S System Interlocking AV A Bay Interlocking BI F SET = ACTUAL (switch direction check) S 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 361 Functions 2.22 Command Processing [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). 2.22.1.4 Information List No. Information Type of Information Comments - ModeREMOTE IntSP Controlmode REMOTE - Cntrl Auth IntSP Control Authority - ModeLOCAL IntSP Controlmode LOCAL 2.22.2 Control Device 2.22.2.1 Information List No. Information Type of Information 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= 362 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions 2.22 Command Processing No. Information Type of Information Comments 31008 Q8 OpCnt= VI Q8 operationcounter= 31009 Q9 OpCnt= VI Q9 operationcounter= 2.22.3 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 tripping and closing the switchgear or for raising and lowering transformer taps and detailed information are described in the SIPROTEC 4 System Description. 2.22.3.1 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 responseTime 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. 2.22.3.2 Information List No. Information Type of Information Comments - >Door open SP >Cabinet door open - >CB wait SP >CB waiting for Spring charged SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 363 Functions 2.22 Command Processing No. Information Type of Information 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 2.22.4 Protocol 2.22.4.1 Information List No. Information Type of Information Comments - SysIntErr. IntSP Error Systeminterface 364 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 3 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 365 Mounting and Commissioning 3.1 Mounting and Connections 3.1 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. 3.1.1 Trouble free and safe use of this device depends on proper transport, storage, installation, and application of the device according to the warnings in this instruction manual. Of 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 transformer 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 compensation) 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. 366 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections For an additional connection of an e-n-winding of a set of voltage transformers, the address 210 U4 transformer = 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 paragraph. 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 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 corresponds 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 367 Mounting and Commissioning 3.1 Mounting and Connections [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 TR CB TC Aux1 Aux2 U-CTR U-BI 368 Principle of the trip circuit supervision with one binary input Trip relay contact Circuit breaker Circuit breaker trip coil Circuit breaker auxiliary contact (NO contact) Circuit breaker auxiliary contact (NC contact) Control voltage for trip circuit Input voltage of binary input SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections R UR Bypass resistor 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] BI (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: BI (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 (system / trip circuit) ULSS (LOW) 2 V (system / trip circuit) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 369 Mounting and Commissioning 3.1 Mounting and Connections [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 k is selected; the power is: [beispiel-leistungvonr-150502-kn, 1, en_GB] 3.1.2 Hardware Modifications 3.1.2.1 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 370 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections Control Voltage for Binary Inputs When the device is delivered from the factory, the binary inputs are set to operate with a voltage that corresponds 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". NOTE i 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". 3.1.2.2 Disassembly Work on the Printed Circuit Boards i NOTE It is assumed for the following steps that the device is not operative. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 371 Mounting and Commissioning 3.1 Mounting and Connections ! 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. Where 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. When handling plug connectors, electrostatic discharges may emerge. These must be avoided by previously touching an earthed metal surface Do 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. 372 * Disconnect the plug connector of the ribbon cable between the front cover and the processor board CCPU- 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections [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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 373 Mounting and Commissioning 3.1 Mounting and Connections [frontansicht-geh-einein-o-frontkappe7sa522-251102-wlk, 1, en_GB] Figure 3-4 3.1.2.3 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. 374 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections Table 3-2 Jumper Jumper settings of the nominal voltage of the integrated Power Supply of the input/output board C-I/O-1. Nominal Voltage DC 60/110/125 V DC 110/125/220/250 V AC 115 V X51 1-2 2-3 X52 1-2 and 3-4 2-3 X53 1-2 2-3 Jumpers X51 to X52 1-2 and 3-4 2-3 X53 are not used interchangeable cannot be changed T2H250V T4H250V Fuse Table 3-3 DC 24/48 V 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) X40 1-2 Closed in quiescent state Factory Setting (NC) 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Module Open in quiescent state (NO) Closed in quiescent state Factory Setting (NC) 375 Mounting and Commissioning 3.1 Mounting and Connections [ein-ausgabebgr-c-io-1-160502-wlk, 1, en_GB] Figure 3-5 376 Input/output board C-I/O-1 with representation of the jumper settings required for checking configuration settings SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections [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 Jumper 19 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 377 Mounting and Commissioning 3.1 Mounting and Connections Binary Inputs slot Jumper 19 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 Binareingange Jumper 19 V Threshold1) 88 V Threshold5) 176 V Threshold9) BI17 X21/X22 L M H BI10 BI18 X23/X24 L M H 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 Slot 33 left side Slot 19 right side Slot 19 left side BI1 BI9 BI2 BI3 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 378 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 Insert location Slot 19 left side Slot 19 right side X71 H L X72 L L X73 H H SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections 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) BI17 X21 L M H BI18 X23 L M H BI11 BI19 X25 L M H 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 Slot 33 left side Slot 19 right side Slot 19 left side BI1 BI9 BI2 BI10 BI3 BI4 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 379 Mounting and Commissioning 3.1 Mounting and Connections Binary Inputs Slot 33 left side Slot 19 right side Slot 19 left side BI8 BI16 BI24 1) Factory 19 V Threshold1) 88 V Threshold5) 176 V Threshold9) X35 L M H 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 3-9 380 Jumper 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections 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 overview 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 381 Mounting and Commissioning 3.1 Mounting and Connections 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. 382 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections [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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 383 Mounting and Commissioning 3.1 Mounting and Connections 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 fur 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 individually 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 BO8, BO11, BO12 configured as single connected to relays (BO9, BO10 without function) common potential 1) X80 1-2, 3-4 2-3, 4-5 X81 1-2, 3-4 2-3, 4-5 2-3 1-2 X82 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 3-15 384 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 385 Mounting and Commissioning 3.1 Mounting and Connections Table 3-16 Device 7SA522*-* 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 Circuit Board for U Platz 19 links Jumper Open in quiescent state (NO) Closed in quiescent state (NC) Factory Setting 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 3-19 386 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.4 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 Geraten im Einbaugehause moglich. Gerate im Aufbaugehause konnen nur im Werk umgerustet werden. * Es konnen nur Schnittstellenmodule eingesetzt werden, mit denen das Gerat auch entsprechend dem Bestellschlussel werkseitig bestellbar ist (siehe auch Anhang A Ordering Information and AccessoriesOrdering Information). * Die Terminierung der busfahigen Schnittstellen gema Randtitel "RS485-Schnittstelle" muss ggf. sichergestellt werden. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 387 Mounting and Commissioning 3.1 Mounting and Connections Table 3-20 Austauschmodule fur Schnittstellen Schnittstelle Einbauplatz/Port Austauschmodul Systemschnittstelle B Serviceschnittstelle C nur Schnittstellenmodule mit denen das Gerat entsprechend dem Bestellschlussel werkseitig bestellbar ist (siehe Anhang A Ordering Information and AccessoriesOrdering Information) Wirkschnittstelle 1 D Wirkschnittstelle 2 E FO5, FO6; FO17 to FO19, FO30 Die Bestellnummern der Austauschmodule finden Sie im Anhang unter Abschnitt A Ordering Information and AccessoriesOrdering Information Zubehor. 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 associated 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 halfduplex 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). 388 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections 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 interface 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 busfahigen Schnittstellen ist beim jeweils letzten Gerat am Bus eine Terminierung notwendig, d.h. es mussen Abschlusswiderstande zugeschaltet werden. Beim 7SA522 betrifft dies die Varianten mit RS485- oder Profibus-/DNP-Schnittstellen. Die Abschlusswiderstande 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 389 Mounting and Commissioning 3.1 Mounting and Connections 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 fur die Profibus-Schnittstelle in Figure 3-14 dargestellt. Es mussen stets beide Brucken fur die Konfiguration der Abschlusswiderstande eines Moduls gleichsinnig gesteckt sein. Im Lieferzustand sind die Brucken so gesteckt, dass die Abschlusswiderstande ausgeschaltet sind. Eine Realisierung von Abschlusswiderstanden kann auch extern erfolgen (z.B. am Anschlussmodul), wie in Figure 3-15 dargestellt. In diesem Fall mussen die auf dem RS485- bzw. Profibus-Schnittstellenmodul befindlichen Abschlusswiderstande ausgeschaltet sein. [externe-terminierung-020313-kn, 1, en_GB] Figure 3-15 3.1.2.5 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. 3.1.3 Mounting 3.1.3.1 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. 390 * 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections * 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 391 Mounting and Commissioning 3.1 Mounting and Connections [schalttafeleinbau-gehaeuse-4zeilig-display-ein-st-040403, 1, en_GB] Figure 3-17 3.1.3.2 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. 392 * 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. * 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. 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.1 Mounting and Connections [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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 393 Mounting and Commissioning 3.1 Mounting and Connections [montage-gehaeuse-4zeilig-display-ein-st-040403, 1, en_GB] Figure 3-19 3.1.3.3 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. * 394 * 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.2 Checking Connections 3.2 Checking Connections 3.2.1 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 Information 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 395 Mounting and Commissioning 3.2 Checking Connections * * 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 Pin No. The assignments of the D-subminiature and RJ45 connector for the various interfaces Operator interface RS232 RS485 PROFIBUS FMS Slave, RS485 2 RxD RxD - - 3 TxD TxD A/A' (RxD/TxD-N) 4 - - - 5 GND GND 6 - - 7 RTS 8 9 DNP3.0 RS485 PROFIBUS DP Slave, RS485 1 Shield (with shield ends electrically connected) Ethernet EN 100 Tx+ - Tx- B/B' (RxD/TxD-P) A Rx+ CNTR-A (TTL) RTS (TTL level) - C/C' (GND) C/C' (GND) GND1 - - +5 V (max. load < 100 mA) VCC1 Rx- RTS - 1) - - - CTS CTS B/B' (RxD/TxD-P) A/A' (RxD/TxD-N) B - - - - - - Non Existent 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. D-subminiature connector assignment of the time synchronization interface Table 3-23 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 8 P_TSYNC 1) Input 24 V 1) 9 SHIELD Shield potential 1) Assigned, 396 but cannot be used SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.2 Checking Connections 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. For the protection data communication, refer to the following section. The transmission via fiber optics is particularly insensitive to electromagnetic interference and thus ensures or galvanic isolation of the connection. Transmit and receive connections are shown with the symbols 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. 3.2.2 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. Do 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 397 Mounting and Commissioning 3.2 Checking Connections 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). 3.2.3 ! Checking the System Connections WARNING Warning of dangerous voltages Non-observance of the following measures can result in death, personal injury or substantial property damage. Therefore, 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. Do 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. * * 398 Check the continuity of all current and voltage transformer connections against the system and connection 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 4 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 isolation 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". SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.2 Checking Connections * 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 399 Mounting and Commissioning 3.3 Commissioning 3.3 ! 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 property damage. Only 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. Before making any connections, the device must be earthed at the protective conductor terminal. Hazardous voltages can exist in the power supply and at the connections to current transformers, voltage transformers, and test circuits. Hazardous voltages can be present in the device even after the power supply voltage has been removed (capacitors can still be charged). After 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. The 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. Short-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. 400 Primary 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.). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning 3.3.1 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 functions" 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. 3.3.2 Checking the Time Synchronisation Interface If external time synchronization sources are used, the data of the time source (antenna system, time generator) are checked (see Section 4 under Time Synchronization"). A correct function (IRIG B, DCF77) is recognized in such a way that 3 minutes after the startup of the device the clock status is displayed as synchronized, 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 1 -- -- -- -- 2 - - - - - - ST 3 - - - - ER - - 4 - - - - ER ST 5 - - NS ER - - 6 - - NS - - - - Legend: - - NS - - - - - - - - ER - - - - - - - - ST 3.3.3 Status synchronized not synchronized 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 401 Mounting and Commissioning 3.3 Commissioning ! 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 operating 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. i Equipment 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. 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 3-22 402 System interface test with dialog box: Generating indications - Example SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning Changing the operating state On clicking one of the buttons in the column Action you will be prompted for the password No. 6 (for hardware 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 indicated to the control centre with this procedure. The function of the actual binary inputs is tested separately. 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. 3.3.4 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 disconnectors will be switched in this way! Non-observance of the following measure will result in death, severe personal injury or substantial property damage. i Equipment 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. 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: SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 403 Mounting and Commissioning 3.3 Commissioning * * * 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 Scheduled 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 404 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning 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 password 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 illuminated 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. 3.3.5 Checking the Communication Topology General The communication topology can be checked from the PC using DIGSI. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 405 Mounting and Commissioning 3.3 Commissioning 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 communication 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). 406 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning [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! Before 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. * 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 interface 1, 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. - Address 4602 CONNEC. 2 OVER = F.optic direct, when you are testing protection data interface. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 407 Mounting and Commissioning 3.3 Commissioning * * 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 interchanging)? - 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. 408 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning * 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 inconsistent "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 indicationRingtopology 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 409 Mounting and Commissioning 3.3 Commissioning 3.3.6 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 protection 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 Teststateis 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. i 3.3.7 * * The send signals are transmitted to the remote end with the attribute"Test mode". * 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. 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). 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 operated 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. First 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. 410 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning 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 3pole trip are possible. The pole discrepancy check of the device or the actual breaker may lead to 3-pole tripping 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 indications). 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 indications). 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 indications). 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 indications). 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 indications). 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 411 Mounting and Commissioning 3.3 Commissioning 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. 3.3.8 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 operational 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. 412 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning If synchronism check is used and if the assigned VT mcb auxiliary contact is connected to the device, its function 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. 3.3.9 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*N. 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 413 Mounting and Commissioning 3.3 Commissioning 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. 3.3.10 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 function. 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 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 measuring 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. 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. 414 * 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. * * The programAR SYNC-CHECK = YES (address 3515) is set for synchronism check. Then the circuit breaker is closed while the line isolator is open (see Figure 3-28). Both voltage transformers therefore measure the same voltage. Via binary input (No.2906 >Sync. Start AR) initiate the measuring request. The synchronism check must release closing (message Sync. release, No.2951). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning [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. 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. -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 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. * 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). 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. 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. 3.3.11 Polarity Check for the Current Input 4 If the standard connection of the device is used whereby current input 4 is connected in the starpoint of the set of current transformers (refer also to the connection circuit diagram in the Appendix C Connection Examples), then the correct polarity of the earth current path in general automatically results. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 415 Mounting and Commissioning 3.3 Commissioning If, however, the current 4 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 4 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. Short-circuit the current transformer secondary circuits before current connections to the device are opened. 4 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. 416 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning [polaritaetspruefung-i4-holmgreen-250702-kn, 1, en_GB] Figure 3-29 i Polarity check for 4, example with current transformer configured in a Holmgreen connection NOTE If parameters were changed for this test, they must be returned to their original state after completion of the test! 4 from Parallel Line If 4 is the current measured on a parallel line, the above procedure is done with the set of current transformers 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 shortcircuiting of the current transformer secondary circuits, the connections must be checked and rectified. Subsequently the measurement must be repeated. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 417 Mounting and Commissioning 3.3 Commissioning [polaritaetspruefung-parallelleitung-250702-kn, 1, en_GB] Figure 3-30 Polarity check of 4, example with earth current of a parallel line 4 from a Power Transformer Starpoint If 4 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! 418 Zero 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning ! 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. Primary 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 4, 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 4 is present. If the wrong direction is indicated, the earth current connection 4 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 NOTE If parameters were changed for this test, they must be returned to their original state after completion of the test ! 3.3.12 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 419 Mounting and Commissioning 3.3 Commissioning 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 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 3.3.13 Testing of the Teleprotection System with Distance Protection 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 420 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning Telep. Dis. 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 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 somewhere 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 assignment 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 corresponding 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 transmission 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 corresponding 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 transmitting 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"! SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 421 Mounting and Commissioning 3.3 Commissioning 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 Teleprotection 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. 3.3.14 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 determined 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 consequence 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 consequently 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 assignment of the echo signals to the transmit outputs. 422 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning 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 corresponding 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 corresponding 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. 3.3.15 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 423 Mounting and Commissioning 3.3 Commissioning 3.3.16 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 transmission 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 Permissive 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. 3.3.17 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. 3.3.18 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 separately 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 auxiliary 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. 3.3.19 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. 424 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.3 Commissioning 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. 3.3.20 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 energized. 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 425 Mounting and Commissioning 3.3 Commissioning [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. 426 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Mounting and Commissioning 3.4 Final Preparation of the Device 3.4 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! 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 427 428 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 4 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 429 Technical Data 4.1 General 4.1 General 4.1.1 Analogue Inputs and Outputs Nominal Frequency fN 50 Hz or 60 Hz N 1 A or 5 A (adjustable) Current Inputs Nominal current Power Consumption per Phase and Earth Path - at N = 1 A Approx. 0.05 VA - at N = 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 * N 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 UN 80 V to 125 V Power consumption per phase at100 V 0.1 VA (adjustable) Voltage Overload Capability in Voltage Path per Input - thermal (rms) 4.1.2 230 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/ DC 110 V/125 V/ 125 V 220 V/250 V Permissible voltage ranges DC 19 V to 58 V DC 48 V to 150 V Superimposed AC ripple voltage, Peak to peak DC 220 V/250 V DC 88 V to 300 V DC 176 V to 300 V 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 430 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.1 General 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 auxiliary voltage 4.1.3 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 DC 110 V/125 V/220 V/250 V Uhigh DC 88 V - for rated voltages Ulow DC 10 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 431 Technical Data 4.1 General Binary Outputs Signalling / Command Relays (see also terminal assignments in the Appendix) Quantity and Data Order Variant According to the Order Variant (configurable) UL listed NO Contact (normal) 1) NO Contact (fast) 1) NO/NC (selectable) 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 - x - 18 3 7SA522*-*W Switching capability 10 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 Permissible current per contact ( continuous) 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 fur 0.5 s Operating time, approx. Alarm relay 8 ms 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) 5 ms 8 ms 1 ms With 1 NC contact or 1 NO contact (switchable) 1) Switching capability 200 V (max.) 5A UL-listed with the following rated data: 4.1.4 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" 432 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.1 General 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 = 820 nm Laser Class 1 according to EN 60825-1/-2 when using glass fiber 50 m/125 m or when using glass fiber 62,5 m/125 m Permissible Optical Link Signal Attenua- max. 8 dB, bei Glasfaser 62,5 m/125 m tion 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 fur Datentransfer zu einer Leitstelle RS232 Connection for flush-mounted housing rear panel, slot "B", 9-pole D-subminiature female connector SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 433 Technical Data 4.1 General 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 = 820 nm Laser class 1 according to EN 60825-1/-2 Using glass fiber 50/125 m or Using glass fibre 62.5/125 m Permissible optical signal attenuation Max. 8 dB, with glass fibre 62.5/125 m 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 separate 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 = 820 nm 434 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.1 General Laser class 1 according to EN 60825-1/-2 Using glass fiber 50/125 m or Using glass fibre 62.5/125 m Permissible optical signal attenuation Max. 8 dB, with glass fibre 62.5/125 m 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 = 820 nm Laser class 1 according to EN60825-1/-2 Using glass fibre 50/125 m or Using glass fibre 62.5/125 m Permissible optical signal attenuation max. 8 dB, with glass fibre 62.5/125 m 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) fur 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 = 1350 nm Optical wavelength 100 MBit/s Laser class 1 according to EN60825-1/-2 Using glass fibre 50 m/125 m or Using glass fibre 62,5 m/125 m Permissible optical signal attenuation max. 5 dB, with glass fibre 62,5 m/125 m Transmission distance max. 800 m SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 435 Technical Data 4.1 General 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 5V 12 V 24 V UIHigh 6.0 V 15.8 V 31 V UILow 1.0 V at ILow = 0.25 mA 1.4 V at ILow = 0.25 mA 1.9 V at ILow = 0.25 mA IHigh 4.5 mA to 9.4 mA 4.5 mA to 9.3 mA 4.5 mA to 8.7 mA RI 890 at UI = 4 V 1930 at UI = 8.7 V 3780 at UI = 17 V 640 at UI = 6 V 1700 at UI = 15.8 V 3560 at UI = 31 V 4.1.5 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) 5 kV (peak), 1.2/50 s, 0.5 Ws, 3 positive and 3 negative All Circuits Except Communication and Time Synchroni- impulses at intervals of 5 s zation Interfaces, Class III EMC Tests for Interference Immunity (Type Tests) Standards: 436 IEC 60255-6 and -22, (product standards) EN 61000-6-2 (generic standard) VDE 0435 part 301DIN VDE 0435-110 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.1 General High frequency test IEC 60255-22-1, Class III and VDE 0435 Teil 303, Class III 2.5 kV (Peak); 1 MHz; = 15 s; 400 surges per s; test duration 2 s; Ri = 200 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 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 ; test duration 1 min High energy surge voltages (SURGE), IEC 61000-4-5 installation Class 3 - Auxiliary voltage Pulse: 1.2 s/50 s common mode: 2 kV; 12 ; 9 F diff. mode: 1 kV; 2 ; 18 F - Analog measuring inputs, binary inputs, relay outputs common mode: 2 kV; 42 ; 0,5 F diff. mode: 1 kV; 42 ; 0,5 F 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; = 15 s; 400 Surges per s; test duration 2 s; Ri = 200 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 ; 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 437 Technical Data 4.1 General 4.1.6 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 4.1.7 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 -20 C to +70 C or -4 F to +158 F (legibility of display may be 96 h) 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 438 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.1 General 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 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) 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. Condensation 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 fluctuations in temperature that may cause condensation to occur. 4.1.8 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 equipment, 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. 4.1.9 Certifications UL recognition UL listing 7SA522*-*A***-**** 7SA522*-*J***-**** 7SA522*-*C***-**** 7SA522*-*L***-**** 7SA522*-*D***-**** Models with threaded terminals 7SA522*-*M***-**** Models with plug-in terminals 7SA522*-*U***-**** 7SA522*-*W***-**** 4.1.10 Construction Housing 7XP20 Dimensions See dimensional drawings, Section4.23 Dimensions Device (for maximum number of components) For panel flush mounting For panel surface mounting SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Size Weight 1/ 2 6 kg 1/ 1 10 kg 1/ 2 11 kg 1 19 kg 1/ 439 Technical Data 4.1 General 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 440 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.2 Distance Protection 4.2 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 K0 0.000 to 4.000 PHI (K0) -135.00 to +135.00 Increments 0.o01 Separate for first and higher zones The matching factors for earth impedance are valid also for fault locating. Mutual Impedance Ratio RM/RL 0.00 to 8.00 Increments 0.01 XM/XL 0.00 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 current30> for N = 1 A 0.05 A to 4.00 A for N = 5 A 0.25 A to 20.00 A Earth voltage 3U0> 1 V to 100 V; Dropout to pickup ratio ca. 0.95 Measuring tolerances for sinusoidal measured values 5% Increments 0.01 A Increments 1 V Distance Measurement Charakteristic Polygonal or MHO characteristic; 6 independent zones and 1 controlled zone Setting ranges polygon: IPh> = min. current, phases SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 for IN = 1 A 0.05 A to 4.00 A for IN = 5 A 0.25 A to 20.00 A Increments 0.01 A 441 Technical Data 4.2 Distance Protection X = reactance reach R = resistance tolerance phase-phase RE = resistance tolerance phase-earth for IN = 1 A 0.050 to 600.000 for IN = 5 A 0.010 to 120.000 for IN = 1 A 0.050 to 600.000 for IN = 5 A 0.010 to 120.000 for IN = 1 A 0.050 to 600.000 for IN = 5 A 0.010 to 120.000 Increments 0.001 Increments 0.001 Increments 0.001 Line = line angle 10 to 89 Increments 1 Dist = angle of distance protection characteristic 30 to 90 Increments 1 Pol = 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 Zr = impedance range for IN = 1 A 0.05 A to 4.00 A for IN = 5 A 0.25 A to 20.00 A for IN = 1 A 0.050 to 200.000 for IN = 5 A 0.010 to 40.000 Increments 0.01 A Increments 0.001 Line = line angle 10 to 89 Increments 1 Dist = 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 to 600.000 ; for IN = 5 A 0.010 to 120.000 ; Load = maximum load angle 20 to 60 Increments 0.001 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 442 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.2 Distance Protection Stage timers 0.00 s to 30.00 s; for all zones; separate time setting possibilities for singlephase and multiphase faults for the zones Z1, Z2, and Z1B Time expiry tolerances 1 % of setting value or 10 ms Increments 0.01 s 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" SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 443 Technical Data 4.3 Power Swing Detection (with impedance pickup) (optional) 4.3 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 444 Trip following instable power swings (out-of-step) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.4 Distance Protection Teleprotection Schemes 4.4 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 Ubergreifzone 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 445 Technical Data 4.5 Earth Fault Protection (optional) 4.5 Earth Fault Protection (optional) Characteristics Definite time stages 3 0>>>, 3 0>>, 3 0> Inverse time stage (IDMT) 3 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 3 0>>> for N = 1 A 0.05 A to 25.00 A for N = 5 A 0.25 A to 125.00 A Delay T30>>> 0.00 s to 30.00 s or (ineffective) Dropout ratio Approx. 0.95 for / N 0.5 Pickup time (fast relays/high-speed relays) Approx. 30 ms/25 ms Dropout time Approx. 30 ms Tolerances Increments 0.01 A Increments 0.01 s 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 3 0>> for N = 1 A 0.05 A to 25.00 A for N = 5 A 0.25 A to 125.00 A Delay T30>> 0.00 s to 30.00 s oder (ineffective) Dropout ratio Approx. 0.95 for / N 0.5 Pickup time (fast relays/high-speed relays) Approx. 30 ms/25 ms Dropout time Increments0.01 A Increments0.01 s 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 0.05 A to 25.00 A or 0.003 A to 25.000 A Increments 0.01 A 0.25 A to 125.00 A or 0.015 A to 125.000 A Increments 0.01 A Delay T30> 0.00 s to 30.00 s oder (ineffective) Increments 0.01 s Dropout ratio Approx. 0.95 for / N 0.5 Pickup value 3 0> for N = 1 A for N = 5 A 446 Increments 0.001 A Increments 0.001 A SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.5 Earth Fault Protection (optional) 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) 0.05 A to 25.00 A or 0.003 A to 25.000 A Increments 0.01 A 0.25 A to 125.00 A or 0.015 A to 125.000 A Increments 0.01 A Time factor T30P 0.05 s to 3.00 s or (ineffective) Increments 0.01 s Additional time delayT30P verz 0.00 s to 30.00 s or (ineffective) Increments 0.01 s Characteristics see Figure 4-1 Pickup value 3 0P for N = 1 A for N = 5 A Increments 0.001 A Increments 0.001 A Tolerances Pickup and dropout thresholds 3 0p 3 % of setting value, or 1 % nominal current Pickup time for /3 0P 20 and T3I0P 1 s 5 % of set value 15 ms Defined times v Inverse Current Stage (ANSI) 0.05 A to 25.00 A oder 0.003 A to 25.000 A Increments0.01 A 0.25 A to 125.00 A or 0.015 A to 125.000 A Increments0.01 A Time factor D30P 0.50 s to 15.00 s or (ineffective) Increments0.01 s Additional time delay T30P verz 0.00 s to 30.00 s or (ineffective) Increments0.01 s Characteristics see Figure 4-2 and Figure 4-3 Pickup value 3 0P for N = 1 A for N = 5 A Increments0.001 A Increments0.001 A Tolerances Pickup and dropout thresholds 3 0p 3 % of set value, or 1 % nominal current Pickup time for 2 /3 0P 20 and D3I0P 1 s 5 % of set value 15 ms Defined times 1 % of set value or 10 ms SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 447 Technical Data 4.5 Earth Fault Protection (optional) Inverse Current Stage (logarithmic inverse) 0.05 A to 25.00 A or 0.003 A to 25.000 A Increments 0.01 A 0.25 A to 125.00 A or 0.015 A to 125.000 A Increments 0.01 A Start current factor3 0P FAKTOR 1.0 to 4.0 Increments 0.1 Time factor T30P 0.05 s to 15.00 s; Increments 0.01 s Maximum time T30P max 0.00 s to 30.00 s Increments 0.01 s Minimum time T30P min 0.00 s to 30.00 s Increments 0.01 s Additional time delay T30P verz 0.00 s to 30.00 s or (ineffective) Increments 0.01 s Characteristics see Figure 4-4 Pickup value 3 0P for N = 1 A for N = 5 A Increments 0.001 A Increments 0.001 A Tolerances Pickup and dropout thresholds 3 0p 3 % of set value, or 1 % nominal current Pickup time for 2 /3 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) 0.05 A to 25.00 A or 0.003 A to 25.000 A Increments 0.01 A 0.25 A to 125.00 A or 0.015 A to 125.000 A Increments 0.01 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 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 Pickup value 3 0P for N = 1 A for N = 5 A Additional time delay Increments 0.001 A Increments 0.001 A Characteristics see Figure 4-5 Tolerances times 1 % of setting value or 10 ms Dropout ratio Strom Approx. 0.95 for / N 0.5 Spannung Approx. 0.95 for 3U 0 1 V Zero Sequence Output Stage (power stage) Pickup value 3 0P 0.05 A to 25.00 A or 0.003 A to 25.000 A Increments 0.01 A 0.25 A to 125.00 A or 0.015 A to 125.000 A Increments 0.01 A for N = 1 A 0.1 VA to 10.0 VA Increments 0.1 VA for N = 5 A 0.5 VA to 50.0 VA for N = 1 A for N = 5 A Pickup value S FORWARD Additional time delay T3OPverz 448 0.00 s to 30.00 s; Increments 0.001 A Increments 0.001 A Increments 0.01 s SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.5 Earth Fault Protection (optional) 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 N = 1 A 0.50 A to 25.00 A for N = 5 A 2.50 A to 125.00 A Increments 0.01 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 E (= 3 0) and 3 U0 and Y or 2 and U2 with E (= 3 0) and 3 U0 and Y with E (= 3 0) and Y ((starpoint current of a power transformer) with 2 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 Increments 0.01 A Starpoint current of a power transformer Y> for N = 1 A 0.05 A to 1.00 A for N = 5 A 0.25 A to 5.00 A Negative sequence current 32> for N = 1 A 0.05 A to 1.00 A for N = 5 A 0.25 A to 5.00 A Negative sequence voltage 3U2> Increments 0.01 A 0.5 V to 10.0 V Increments 0.1 V 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 changeUmorientierungszeit bei Fehlerwechsel Approx. 30 ms "Forward" angle SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 449 Technical Data 4.5 Earth Fault Protection (optional) [td-kennl-amz-n-iec-oz-060802, 1, en_GB] Figure 4-1 450 Trip time characteristics of inverse time overcurrent stage, acc. IEC (phases and earth) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.5 Earth Fault Protection (optional) [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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 451 Technical Data 4.5 Earth Fault Protection (optional) [td-kennl-amz-n-ansi-2-oz-060802, 1, en_GB] Figure 4-3 452 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.5 Earth Fault Protection (optional) [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 characteristic Logarithmic inverse t = T30Pmax -- T30P*n(/3I0P) Note: For /3I0P > 35 the time for /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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 453 Technical Data 4.5 Earth Fault Protection (optional) [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 T3OPAdd.T_DELAY = 0 s. 454 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.6 Earth Fault Protection Teleprotection Schemes (optional) 4.6 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 transmission 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 SendesignalverlangerungSend 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 455 Technical Data 4.7 Weak-infeed Tripping (classical) 4.7 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 Dropout to pickup ratio Approx. 1.1 Pickup tolerance 5 % of setting value, or 0.5 V Increments1 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 456 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.8 Weak-infeed Tripping (French Specification) 4.8 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 Dropout/pickup ratio Approx. 1.1 Pickup tolerance 5% Increments 0.01 Times Receive prolongation 0.00 s to 30.00 s Increments 0.01 s Extension time 30> 0.00 s to 30.00 s Increments 0.01 s Alarm time 30> 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 1 s to 60 s Increments 1 s Pickup tolerance 1 % of setting value or 10 ms SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 457 Technical Data 4.9 Protection Data Interface and Communication Topology (optional) 4.9 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 connections 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 = 820 nm Fibre Type Multimode 62.5 m /125 m Transmit output (peak) min. Type max. 62.5 m /125 m, 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 m /125 m , NA = 0.21) 0.21) 50 m /125 m, NA = min. 8 dB for 62.5 m /125 m , NA = 0.2751) Laser class 1 according to EN 60825-1/-2 Using glass fibre 62.5 m /125 m and 50 m /125 m Reach for multimode optical fibre, an optical signal attenuation of 3 dB/km is used for calculating light with a wavelength of = 820 nm Attenuators required no 1) Numeric opening (NA = sin (coupling angle) FO6 Distance, maximum 3.5 km Connector Type ST connector Optical wavelength = 820 nm Fibre Type Multimode 62.5 m /125 m Transmit output (avg) 50 m /125 m, NA = 0.21) 62.5 m /125 m, NA = 0.2751) min. Typ -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 m /125 m , NA = 0.21) min. 16.0 B for 62.5 m /125 m , NA = 0.2751) Laser class 1 according to EN 60825-1/-2 Using glass fibre 62.5 m /125 m and 50 m /125 m Reach for multimode optical fibre, an optical signal attenuation of 3 dB/km is used for calculating light with a wavelength of = 820 nm 458 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.9 Protection Data Interface and Communication Topology (optional) Attenuators required 1) Numeric no opening (NA = sin (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 = 1300 nm Fibre Type Monomode 9 m /125 m 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 m /125 m Reach for multimode optical fibre, an optical signal attenuation of 0.3 dB/km is used for calculating light with a wavelength of = 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 = 1300 nm Fibre Type Monomode 9 m /125 m 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 m /125 m Reach for multimode optical fibre, an optical signal attenuation of 0.3 dB/km is used for calculating light with a wavelength of = 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 459 Technical Data 4.9 Protection Data Interface and Communication Topology (optional) Receiver interfacing AC Optical wavelength = 1550 nm Fibre Type Monomode 9 m /125 m 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 m /125 m Reach for multimode optical fibre, an optical signal attenuation of 0.2 dB/km is used for calculating light with a wavelength of = 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 460 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.10 External Direct and Remote Tripping 4.10 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) Time expiry tolerances 1 % of setting value or 10 ms Increments 0.01 s The set times are pure delay times SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 461 Technical Data 4.11 Time Overcurrent Protection 4.11 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>>>, 30>>>, Ph>>, 30>>, Ph>, 30> Inverse time stages (IDMT) P, 30P; 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 valuePh>> (phases) Pickup value 30>> (earth) for N = 1 A 0.10 A to 25.00 A or (ineffective) for N = 5 A 0.50 A to 125.00 A or (ineffective) for N = 1 A 0.05 A to 25.00 A or (ineffective) for N = 5 A 0.25 A to 125.00 A or (ineffective) Increments 0.01 A Increments 0.01 A Delay TPh>> (phases) 0.00 s to 30.00 s or (ineffective) Increments 0.01 s Delay T30>> (earth) 0.00 s to 30.00 s or (ineffective) Increments 0.01 s Dropout ratio Approx. 0.95 for /N 0.5 Pickup times (fast relays/high-speed relays) Approx. 25 ms/20 ms Dropout times Tolerances Approx. 30 ms Currents 3 % of setting value or 1 % nominal current Times 1 % of setting value or 10 ms for N = 1 A 0.10 A to 25.00 A or (ineffective) for N = 5 A 0.50 A to 125.00 A or (ineffective) for N = 1 A 0.05 A to 25.00 A or (ineffective) for N = 5 A 0.25 A to 125.00 A or (ineffective) The set times are pure delay times Overcurrent Stages Pickup value Ph> (phases) Pickup value 30> (earth) Delay TPh> (phases) 462 0.00 s to 30.00 s or (ineffective) Increments 0.01 A Increments 0.01 A Increments 0.01 s SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.11 Time Overcurrent Protection Delay T30> (earth) 0.00 s to 30.00 s or (ineffective) Dropout ratio Approx. 0.95 for /N 0.5 Pickup times (fast relays/high-speed relays) Approx. 25 ms/20 ms Dropout times Approx. 30 ms Tolerances Increments 0.01 s 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 Ph (phases) Pickup value 30P (earth) Time multipliers Additional time delays for N = 1 A 0.10 A to 4.00 A or (ineffective) for N = 5 A 0.50 A to 20.00 A or (ineffective) for N = 1 A 0.05 A to 4.00 A or (ineffective) for N = 5 A 0.25 A to 20.00 A or (ineffective) TP (phases) 0.05 s to 3.00 s or (ineffective) Increments 0.01 s T30P (earth) 0.05 s to 3.00 s or (ineffective) Increments 0.01 s TP delayed (phases) 0.00 s to 30.00 s Increments 0.01 s T30P delayed (earth) 0.00 s to 30.00 s Increments 0.01 s Characteristics Increments 0.01 A Increments 0.01 A see Figure 4-1 Tolerances Pickup/dropout thresholds p, 30p 3% of set value, or 1% nominal current Pickup time for 2 /P 20 and TIP 1 s 5% of set value 15 ms 5% of set value 15 ms Pickup time for 2 /30P 20 and T3I0P 1 s Defined times 1 % of setting value or 10 ms Inverse Time Stages (ANSI) Pickup value Ph (phases) Pickup value 30P (earth) Time multipliers Additional time delays Characteristics SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 for N = 1 A 0.10 A to 4.00 A or (ineffective) Increments 0.01 A for N = 5 A 0.50 A to 20.00 A or (ineffective) for N = 1 A 0.05 A to 4.00 A or (ineffective) for N = 5 A 0.25 A to 20.00 A or (ineffective) DP (phases) 0.50 s to 15.00 s or (ineffective) Increments 0.01 s D30P (earth) 0.50 s to 15.00 s or (ineffective) Increments 0.01 s TP delayed (phases) 0.00 s to 30.00 s Increments 0.01 s T30P delayed (earth) 0.00 s to 30.00 s Increments 0.01 s Increments 0.01 A see Figure 4-2 and Figure 4-3 463 Technical Data 4.11 Time Overcurrent Protection Tolerances Pickup/dropout thresholds p, 30p 3% of set value, or 1% nominal current Pickup time for 2 /P 20 and DIP 1 s 5% of set value 15 ms 5% of set value 15 ms Pickup time for 2 /30P 20 and D3I0P 1 s Defined times 1 % of setting value or 10 ms Stub Fault Protection Pickup value Ph>>>(phases) Pickup value 30 >>>(earth) Delays for N = 1 A 0.10 A to 25.00 A or (ineffective) Increments 0.01 A for N = 5 A 0.50 A to 125.00 A or (ineffective) for N = 1 A 0.05 A to 25.00 A or (ineffective) for N = 5 A 0.25 A to 125.00 A or (ineffective) TPh>>> 0.00 s to 30.00 s or (ineffective) Increments 0.01 s T30>>> 0.00 s to 30.00 s or (ineffective) Increments 0.01 s Increments 0.01 A Dropout to pickup ratio Approx. 0.95 for /N 0.5 Pickup times (fast relays/high-speed relays) Approx. 25 ms/20 ms Dropout times Tolerance currents Approx. 30 ms Currents 3 % of setting value or 1 % nominal current Times 1 % of setting value or 10 ms The set times are pure delay times. 464 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.12 Instantaneous High-current Switch-onto-fault Protection 4.12 Instantaneous High-current Switch-onto-fault Protection Pickup Pickup value >>> for N = 1 A 1.00 A to 25.00 A for N = 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 N Increments 0.01 A Times Shortest trip time SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Approx. 13 ms for fast relays Approx. 8 ms for high-speed relays 465 Technical Data 4.13 Automatic Reclosure (optional) 4.13 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 466 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.14 Synchronism and Voltage Check (optional) 4.14 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 conditions 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<) U measurement Voltage difference 1.0 V to 60.0 V (phase-to-phase) Tolerance 1V Dropout to pickup ratio Approx. 1,05 Increments 0,1 V Synchronous power conditions measurement 2 to 80 Increments 1 Tolerance 2 f measurement 0.03 Hz to 2.00 Hz Tolerance 15 mHz Enable delay 0,00 s to 30,00 s Increments 0.01 s f measurement 0.03 Hz to 2.00 Hz Increments 0,01 Hz Tolerance 15 mHz Max. angle error 5 for f 1 Hz Increments 0,01 Hz Asynchronous power conditions 10 for f > 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; Tolerance of all timers 1 % of setting value or 10 ms SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Increments 0.01 s 467 Technical Data 4.15 Voltage Protection (optional) 4.15 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 Tolerances approx. 30 ms 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 Tolerances approx. 30 ms 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 Tolerances Approx. 30 ms 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 468 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.15 Voltage Protection (optional) 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 Tolerances approx. 30 ms (50 Hz) 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 Tolerances Approx. 30 ms 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 469 Technical Data 4.15 Voltage Protection (optional) 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 470 Voltages 3 % of set value or 1 V Times 1 % of setting value or 10 ms SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.16 Frequency Protection (optional) 4.16 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 f = | 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 471 Technical Data 4.17 Fault Locator 4.17 Fault Locator Start With trip command or drop-off Setting range reactance (secondary), miles or km for N = 1 A 0.0050 /km to 9.5000 /km for N = 5 A 0.0010 /km to 1.9000 /km for N = 1 A 0.0050 /mile to 15.0000 /mile for N = 5 A 0.0010 /mile to 3.0000 /mile Increments 0.001 /km Increments 0.001 / 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 primary and secondary, in km or miles line length1) in % of the line length1) Measuring tolerances with sinusoidal quantities 2.5 % vom Fehlerort bei 30 k 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; 1) Output 472 Increments 0.01 s of the fault distance in km, miles, and % requires homogeneous lines SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.18 Circuit Breaker Failure Protection (optional) 4.18 Circuit Breaker Failure Protection (optional) Circuit breaker monitoring Current flow monitoring Zero sequence current monitoring for N = 1 A 0.05 A to 20.00 A for N = 5 A 0.25 A to 100.00 A for N = 1 A 0.05 A to 20.00 A for N = 5 A 0.25 A to 100.00 A Increments 0.01 A Increments 0.01 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; Tolerance 1 % of setting value or 10 ms Increments 0.01 s End fault protection With signal transmission to the opposite line end Time delay 0.00 s to 30.00 s; Tolerance 1 % of setting value or 10 ms Increments 0.01 s Pole discrepancy supervision Initiation criterion Not all poles are closed or open Monitoring time 0.00 s to 30.00 s; Tolerance 1 % of setting value or 10 ms SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Increments 0.01 s 473 Technical Data 4.19 Monitoring Functions 4.19 Monitoring Functions Measured values Current sum F = | L1 + L2 + L3 + k * E | > SUM.I Threshold * N + SUM.FACTOR * | | for N = 1 A 0.05 A to 2.00 A Increments 0.01 A for N = 5 A 0.25 A to 10.00 A Increments 0.01 A - SUM.FACTOR 0.00 to 0.95 Increments 0.01 Voltage sum UF = | UL1 + UL2 + UL3 + kU * UEN | > 25 V Current Symmetry | min |/| max | < BAL.FACTOR. - SUM.Limit as long as max/N > BAL.LIMIT/N 0.10 to 0.95 Increments 0.01 for N = 1 A 0.10 A to 1.00 A Increments 0.01 A for N = 5 A 0.50 A to 5.00 A Increments 0.01 A T BAL.LIMIT 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 - BAL.FACTOR. BAL.LIMIT 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 * 0 < FFM < and 3 * 2 < FFM < - FFM U> - FFM < 10 V to 100 V Increments 1 V for N = 1 A 0.10 A to 1.00 A Increments 0.01 A for N = 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 Ph < FFM delta and all Ph > (Ph> (Dist.)) - FFM UMEAS < 2 V to 100 V Increments 1 V for N = 1 A 0.05 A to 1.00 A Increments 0.01 A for N = 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 A and B - A, B 0 to 259 - FFM delta 474 Increments 1 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.19 Monitoring Functions for N = 1 A 0.05 A to 2.00 A Increments 0.01 A for N = 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 - 1 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Increments 1 s 475 Technical Data 4.20 Transmission of Binary Information (optional) 4.20 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 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 Drop-off times, total approx. 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 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 Drop-off times, total approx. 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. 476 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.21 User-defined Functions (CFC) 4.21 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 Annunciation - 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 477 Technical Data 4.21 User-defined Functions (CFC) 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 indication 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 indication 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 400 (number of unequal information items of the left border per task level) 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 When the limit is exceeded, an error indication is output by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. 478 350 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.21 User-defined Functions (CFC) Device-specific Limits Description Limit Maximum number of concurrent changes to planned inputs 50 per task level Chart inputs per task level Maximum number of chart outputs per task level 150 Comments When the limit is exceeded, an error indication is output by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. Additional Limits Additional limits 1) for the following 4 CFC blocks: Task Level TIMER 2) 3) TIMER_SHORT2) 3) CMD_CHAIN D_FF_MEMO 20 350 MW_BEARB PLC1_BEARB 15 PLC_BEARB 30 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) 1) When 10 000 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 Number of TICKS Individual Element 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 479 Technical Data 4.21 User-defined Functions (CFC) 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 8 480 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.22 Additional Functions 4.22 Additional Functions Measured values Operational measured values for currents L1; L2; L3; 30; 1; 2; Y; P; EE; in A primary and secondary and in % Nperation Tolerance 0.5 % of measured value or 0.5 % o N 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 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 * N Tolerance 1 % of SN at/N and U/UN in range 50 to 120 % 1 % of PN at /N and U/UN in range 50 to 120 % and ABS(cos ) in range 0.7 to 1 1 % of QN at /N and U/UN in range 50 to 120 % and ABS(cos ) in range 0.7 to 1 Operating measured value for power factor cos 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 > 0,5 N, U > 0,5 UN and | cos | 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 primar fsy1; fsy2; fdiff in Hz; diff in Long-term mean value L1dmd; L2dmd; L3dmd; 1dmd; Pdmd; Pdmd Forw, Pdmd Rev; Qdmd; Qdmd Forw; Qdmd Rev; Sdmd In primary values SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 481 Technical Data 4.22 Additional Functions Minimum and maximum values L1; L2; L3; 1; L1d; L2d; L3d; 1d; 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 Pos; cos Neg; f In primary values Remote measured values for currents L1; L2; L3 of remote end in A primary (L1); (L2); (L3), referred to the local voltage UL1-E in Remote measured values for voltages UL1; UL2; UL3 of remote end in kV primary (UL1); (UL2); (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- Availability in %/min and %/h tion data interface 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 482 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.22 Additional Functions 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 manufacturer has to be consulted to define the requirements that ensure that the application functions safely. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 483 Technical Data 4.23 Dimensions 4.23 Dimensions 4.23.1 Housing for Panel Flush Mounting or Cubicle Mounting (Size1/2) [massbild-schrankeinbau-gr-1-2-7sa522-050802, 1, en_GB] Figure 4-7 484 Dimensions of a device for panel flush mounting or cubicle installation (size 1/2) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Technical Data 4.23 Dimensions 4.23.2 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 485 Technical Data 4.23 Dimensions 4.23.3 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) 4.23.4 Dimensions of a device for panel surface mounting (size 1/1) [massbild-schalttafelaufbau-gr-1-1-oz-050802, 1, en_GB] Figure 4-10 486 Dimensions of a device for panel surface mounting (size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 A Ordering Information and AccessoriesOrdering Information A.1 Ordering Information 488 A.2 Accessories 492 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 487 Ordering Information and AccessoriesOrdering Information A.1 Ordering Information A.1 Ordering Information 7 Numerical Distance Protection (position 1 to 9) 7 S A 5 2 2 8 9 10 11 12 - 13 14 15 16 - + L/M/N Measuring Inputs (4 x U, 4 x ) Pos. 7 ph = 1 A, e = 1 A (min. = 0.05 A) 1 ph = 1 A, e = sensitive (min. = 0.003 A) 2 ph = 5 A, e = 5 A (min. = 0.25 A) 5 ph = 5 A, e = sensitive (min. = 0.003 A) 6 Auxiliary Voltage (Power Supply, Pickup Threshold of Binary Inputs) DC 24 V to 48 V, binary input threshold 19 V DC 60 V to 125 V 1), Pos. 8 2 2) binary input threshold 19 V 4 2) 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 6 2) Housing / Number of Binary Inputs (BI) and Outputs (BO) Pos. 9 2 x 19", 8 BI, 16 BO A 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 screwed terminals, 1/ Flush mounting housing with screwed terminals, 1/ 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 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 screwed terminals, Flush mounting housing with plug-in terminals, 1/ U 1 x 19", 24 BI, 32 BO (thereof 10 with high-speed relay) W Flush mounting housing with screwed terminals, x 19", 22 BI, 44 BO 1/ 1 Flush mounting housing with screwed terminals, 1) with 2) for plug-in jumper one of the 2 voltage ranges can be selected each binary input one of 3 pickup threshold ranges can be selected with plug-in jumper 7 Numerical Distance Protection (position 10 to 16) 488 T x 19", 24 BI, 32 BO (thereof 5 with high-speed relay) 1 1/ 7 S A 5 2 2 8 - 9 10 11 12 13 14 15 16 - + L/M/N SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Ordering Information and AccessoriesOrdering Information A.1 Ordering Information Pos. 10 Region-specific Default/Language Settings and Function Versions1) 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 Numerical Distance Protection (position 10 to 16) 7 S A 5 2 2 8 9 10 11 12 - 13 14 15 16 - + 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 820nm, 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 Numerical Distance Protection (Stelle 21 bis 22) 7 S A 5 2 2 8 9 10 11 12 - Additional information L, further protocols port B System port, Profibus DP slave, electrical RS485 13 14 15 16 - + L Pos. 21, 22 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 489 Ordering Information and AccessoriesOrdering Information A.1 Ordering Information 7 Numerical Distance Protection (Stelle 23 bis 24) 7 S A 5 2 2 8 9 10 11 12 - 13 14 15 16 - + Additional information M, port C M 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). 8 7 Numerical Distance Protection (Stelle 10 bis 16) 7 S A 5 2 2 - 9 10 11 12 13 14 15 16 - + Functions 1 L/M/N 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 M Distance pickup Z<, Polygon, with power swing option, with parallel line compensation Distance pickup Z<, MHO, with power swing option, with parallel line compensation 1) 1) only 490 1) 1) N Q available with "1" or "5" on position 7 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Ordering Information and AccessoriesOrdering Information A.1 Ordering Information Functions 3 Pos. 15 Automatic Reclosure Synchro-Chec Breaker Failure Protection Voltage Protection Frequency Protection without without without without 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 A 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 Numerical Distance Protection (Stelle 25 bis 26) 7 S A 5 2 2 8 - 9 10 11 12 13 14 15 16 - + Additional Specification N, Functions 1 N 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 Optical 820 nm, 2-ST connector, length of optical fibre up to 1.5 km for multimode-fibre Pos. 26 (FO5);A) Optical 820 nm, 2-ST-connector, length of optical fibre up to 3.5 km for multimode-fibre (FO6) or B) Optical 1300 nm, 2-LC connector, length of optical fibre up to 24 km for monomode fibre (FO17) A B A) A) Optical 1300 nm, 2-LC connector, length of optical fibre up to 60 km for monomode fibre (FO18) A) 1) Optical 1550 nm, 2-LC connector, length of optical fibre up to 100 km for monomode fibre (FO19) A) 1) 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) G H J 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). SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 491 Ordering Information and AccessoriesOrdering Information A.2 Accessories A.2 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- 7XV5662-0AD00 G703 for two FO channels and RS232 interface (G703 with 512 kBits/s) 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 492 Name Order number 1 set of optical attenuators (2 pcs) 7XV5107-0AA00 Fibre-optic cables1) 6XV8100 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Ordering Information and AccessoriesOrdering Information A.2 Accessories 1) Fibre-optic cables with different connectors, in different lengths and designs. More information will be available 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 493 Ordering Information and AccessoriesOrdering Information A.2 Accessories 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, MSWINDOWS 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 7XV5100-4 9-pin male/female connectors 494 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 B Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 496 B.2 Housing for Panel Surface Mounting 505 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 495 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting B.1 Panel Flush Mounting or Cubicle Mounting 7SA522*-*A/J [schrankeinbau-7sa522-a-j-wlk-261102, 1, en_GB] Figure B-1 496 General diagram 7SA522*-*A/J (panel flush mounting or cubicle mounting; size 1/2) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 497 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 7SA522*-*N/S [schrankeinbau-7sa522-n-s-wlk-261102, 1, en_GB] Figure B-3 498 General diagram 7SA522*-*N/S (panel flush mounting or cubicle mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 499 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 7SA522*-*P/T [schrankeinbau-7sa522-p-t-wlk-261102, 1, en_GB] Figure B-5 500 General diagram 7SA522*-*P/T (panel flush mounting or cubicle mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 7SA522*-*U [schrankeinbau-mit-c-i-o-bausteine-st-140404, 1, en_GB] SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 501 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting [schrankeinbau-mit-c-i-o-bausteine-seite2-st-140404, 1, en_GB] Figure B-6 502 General diagram 7SA522*-*U (panel flush mounting or cubicle mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting 7SA522*-*W [schrankeinbau-7sa522-w-wlk-040421, 1, en_GB] SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 503 Terminal Assignments B.1 Panel Flush Mounting or Cubicle Mounting [schrankeinbau-7sa522-w-seite2-wlk-040421, 1, en_GB] Figure B-7 504 General diagram 7SA522*-*W (panel flush mounting or cubicle mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.2 Housing for Panel Surface Mounting B.2 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 505 Terminal Assignments B.2 Housing for Panel Surface Mounting 7SA522*-*E (up to development state /DD) [schalttafelaufbau-7sa522-e-dd-wlk-261102, 1, en_GB] Figure B-9 506 General diagram 7SA522*-*E up to development state /DD (panel surface mounting; size 1/2) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.2 Housing for Panel Surface Mounting 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 507 Terminal Assignments B.2 Housing for Panel Surface Mounting 7SA522*-*G [schalttafelaufbau-7sa522-g-wlk-261102, 1, en_GB] Figure B-11 508 General diagram 7SA522*-*G (panel surface mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.2 Housing for Panel Surface Mounting 7SA522*-*Q [schalttafelaufbau-7sa522-q-wlk-261102, 1, en_GB] Figure B-12 General diagram 7SA522*-*Q (panel surface mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 509 Terminal Assignments B.2 Housing for Panel Surface Mounting 7SA522*-*H [schalttafelaufbau-7sa522-h-wlk-261102, 1, en_GB] Figure B-13 510 General diagram 7SA522*-*H (panel surface mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.2 Housing for Panel Surface Mounting 7SA522*-*R [schalttafelaufbau-7sa522-r-wlk-261102, 1, en_GB] Figure B-14 General diagram 7SA522*-*R (panel surface mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 511 Terminal Assignments B.2 Housing for Panel Surface Mounting 7SA522*-*G/H/Q/R (up to development state /DD) [schrankeinbau-7sa522-ghqr-dd-wlk-261102, 1, en_GB] Figure B-15 512 General diagram 7SA522*-*G/H/Q/R up to development state /DD (panel surface mounting; size 1/1) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Terminal Assignments B.2 Housing for Panel Surface Mounting 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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 513 514 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C Connection Examples C.1 Current Transformer Examples 516 C.2 Voltage Transformer Examples 520 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 515 Connection Examples C.1 Current Transformer Examples C.1 Current Transformer Examples [anschl-beisp-3stromwandl-sternpkt-oz-291102, 1, en_GB] Figure C-1 516 Current connections to three current transformers and starpoint current (normal circuit layout) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Connection Examples C.1 Current Transformer Examples [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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 517 Connection Examples C.1 Current Transformer Examples [anschl-beisp-3stromw-erdstrom-v-sternpkt-2-oz-291102, 1, en_GB] Figure C-3 518 Current connections to three current transformers and earth current from the star-point connection of a parallel line (for parallel line compensation) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Connection Examples C.1 Current Transformer Examples [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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 519 Connection Examples C.2 Voltage Transformer Examples C.2 Voltage Transformer Examples [anschl-beisp-spgw-anschl-normalanschl-oz-291102, 1, en_GB] Figure C-5 520 Voltage connections to three wye-connected voltage transformers (normal circuit layout) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Connection Examples C.2 Voltage Transformer Examples [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) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 521 Connection Examples C.2 Voltage Transformer Examples [anschl-beisp-spgw-anschl-und-ss-spg-2-oz-291102, 1, en_GB] Figure C-7 522 Voltage connections to three wye-connected voltage transformers and additionally to a busbar voltage (for overvoltage protection or synchronism check) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 D 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 523 Default Settings and Protocol-dependent Functions D.1 LEDs D.1 LEDs Table D-1 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 Relay TRIP 511 Relay GENERAL TRIP command1) Relay TRIP 3ph. 515 Relay TRIP command Phases L1232) 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) 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. 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. Dis.TripZ2/1p 3816 Distance TRIP single-phase Z22) Dis.TripZ2/3p 3817 Distance TRIP 3phase in Z2 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 LED6 LED7 LED8 LED9 LED10 LED11 1) only 524 LED Indication Presettings devices with three-pole tripping only 2) only devices with single-pole and three-pole tripping 3) only devices with automatic reclosure function SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Default Settings and Protocol-dependent Functions D.2 Binary Input D.2 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 525 Default Settings and Protocol-dependent Functions D.3 Binary Output D.3 Binary Output Table D-3 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) 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) 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) 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) DisTRIP3p. Z1sf 3823 DisTRIP 3phase in Z1 with single-ph Flt.3) DisTRIP3p.Z1Bsf 3825 DisTRIP 3phase in Z1B with single-ph Flt3) 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) 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) Relay TRIP 1pL3 514 Relay TRIP command - Only Phase L33) Relay TRIP 3ph. 515 Relay TRIP command Phases L1233) BO5 BO6 BO9 BO10 BO11 BO14 BO15 1) only 526 Output relay presettings for all devices and ordering variants devices with three-pole tripping 2) only devices with single-pole and three-pole tripping 3) only devices with automatic reclosure function SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Default Settings and Protocol-dependent Functions D.4 Function Keys D.4 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 527 Default Settings and Protocol-dependent Functions D.5 Default Display D.5 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: PU Time=: Trip time=: Fault locator 528 A message indicating the protective function that picked up first Elapsed time from pick-up until drop-off Elapsed time from pick-up until the first trip command of a protection function Fault distance d in km or miles SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Default Settings and Protocol-dependent Functions D.6 Pre-defined CFC Charts D.6 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 529 Default Settings and Protocol-dependent Functions D.7 Protocol-dependent Functions D.7 Protocol-dependent Functions Protocoll IEC 60870-5-103 IEC 61850 Ethernet (EN-100) Profibus FMS Profibus DP DNP3.0 Additional Service Interface (optional) Operational measured 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 interface No. Only via additional service interface Yes Remote protection setting No. Only via addi- Yes tional service with DIGSI via interface Ethernet Yes with DIGSI via PROFIBUS No. Only via additional service interface No. Only via additional service interface Yes User-defined annunciations and switching objects Yes Yes Yes Predefined Predefined Yes "User-defined "User-defined Alarms" in CFC Alarms" in CFC Time synchronisation 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 - Yes Yes Yes Yes Yes Function Messages with time Yes stamp 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 530 RS232 RS485 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 E Functions, Settings, Information E.1 Functional Scope 532 E.2 Settings 534 E.3 Information List 558 E.4 Group Alarms 620 E.5 Measured Values 621 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 531 Functions, Settings, Information E.1 Functional Scope E.1 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 overcurr. 532 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.1 Functional Scope 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 533 Functions, Settings, Information E.2 Settings E.2 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 secondary nominal current of the current transformer. Addr. Parameter Function 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 Usy2-Usy1 P.System Data 1 0 .. 360 0 Angle adjustment Usy2Usy1 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 534 C SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 239 T-CB close 240A Setting Options Default Setting Comments P.System Data 1 0.01 .. 0.60 sec 0.06 sec Closing (operating) time of CB 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 testautoreclosure 302 CHANGE Change Group Group A Group B Group C Group D Binary Input Protocol Group A Change to Another Setting Group 402A WAVEFORMTRIGGER 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 Waveform 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 /km 0.1500 /km x' - Line Reactance per length unit 5A 0.0010 .. 1.9000 /km 0.0300 /km 0.1 .. 1000.0 km 100.0 km 1111 Line Length P.System Data 2 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C Line Length 535 Functions, Settings, Information E.2 Settings Addr. Parameter Function C Setting Options Default Setting Comments 1112 P.System Data 2 1A 0.0050 .. 15.0000 /mi 0.2420 /mi x' - Line Reactance per length unit 5A 0.0010 .. 3.0000 /mi 0.0484 /mi 0.1 .. 650.0 Miles 62.1 Miles Line Length 1A 0.000 .. 100.000 F/km 0.010 F/km c' - capacit. per unit line len. F/km 5A 0.000 .. 500.000 F/km 0.050 F/km 1A 0.000 .. 160.000 F/mi 0.016 F/mi 5A 0.000 .. 800.000 F/mi 0.080 F/mi x' 1113 Line Length P.System Data 2 1114 c' P.System Data 2 1115 c' P.System Data 2 c' - capacit. per unit line len. F/mile 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 5A 0.25 .. 5.00 A 0.50 A Pole Open Current Threshold 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 536 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 1136 P.System Data 2 OpenPoleDetect. 1140A I-CTsat. Thres. P.System Data 2 C Setting Options Default Setting Comments OFF Current AND CB w/ measurement w/ measurement open pole detector 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 (Einstellmoglichnone keiten anwendungsabhangig) 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 O 1pole lagging O 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 5A 0.25 .. 20.00 A 0.50 A Phase Current threshold for dist. meas. 1A 0.05 .. 4.00 A 0.10 A 5A 0.25 .. 20.00 A 0.50 A 1203 3I0> Threshold Dis. General 3I0 threshold for neutral current pickup 1204 3U0> Threshold Dis. General 1 .. 100 V; 5V 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 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 SER-COMP. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 537 Functions, Settings, Information E.2 Settings Addr. Parameter Function 1220 Setting Options Default Setting Comments 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 2phe faults 1221A 2Ph-E faults Dis. General Block leading O Block lagging O All loops O-O loops only O-E loops only Block leading O 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 (O-E) Dis. General PHASE PREF.2phe 1242 load (O-E) Dis. General 1243 R load (O-O) Dis. General C 1A 0.100 .. 600.000 ; 5A 0.020 .. 120.000 ; 20 .. 60 45 1A 0.100 .. 600.000 ; 5A 0.020 .. 120.000 ; R load, minimum Load Impedance (ph-e) PHI load, maximum Load Angle (ph-e) R load, minimum Load Impedance (ph-ph) 1244 load (O-O) 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) O-O Dis. Quadril. 1A 0.050 .. 600.000 1.250 5A 0.010 .. 120.000 0.250 R(Z1), Resistance for phph-faults 1303 X(Z1) Dis. Quadril. 1A 0.050 .. 600.000 2.500 X(Z1), Reactance 5A 0.010 .. 120.000 0.500 1304 RE(Z1) O-E Dis. Quadril. 1A 0.050 .. 600.000 2.500 5A 0.010 .. 120.000 0.500 1305 538 T1-1phase Dis. General Dis. Quadril. Dis. MHO 0.00 .. 30.00 sec; 0.00 sec RE(Z1), Resistance for phe faults T1-1phase, delay for single phase faults SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings 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 5A 0.25 .. 100.00 A 1.00 A Minimum current for Z1 only Iph>(Z1) Forward Reverse Non-Directional Inactive Forward Operating mode Z2 1A 0.050 .. 600.000 2.500 5A 0.010 .. 120.000 0.500 R(Z2), Resistance for phph-faults 1A 0.050 .. 600.000 5.000 X(Z2), Reactance 5A 0.010 .. 120.000 1.000 1A 0.050 .. 600.000 5.000 5A 0.010 .. 120.000 1.000 1311 Op. mode Z2 Dis. Quadril. 1312 R(Z2) O-O Dis. Quadril. 1313 X(Z2) Dis. Quadril. 1314 RE(Z2) O-E Dis. Quadril. 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) O-O Dis. Quadril. 1A 0.050 .. 600.000 5.000 5A 0.010 .. 120.000 1.000 R(Z3), Resistance for phph-faults 1A 0.050 .. 600.000 10.000 X(Z3), Reactance 5A 0.010 .. 120.000 2.000 1A 0.050 .. 600.000 10.000 5A 0.010 .. 120.000 2.000 1323 1324 X(Z3) RE(Z3) O-E Dis. Quadril. Dis. Quadril. RE(Z2), Resistance for phe faults RE(Z3), Resistance for phe faults 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) O-O Dis. Quadril. 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 R(Z4), Resistance for phph-faults 1333 X(Z4) Dis. Quadril. 1A 0.050 .. 600.000 12.000 X(Z4), Reactance 5A 0.010 .. 120.000 2.400 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 539 Functions, Settings, Information E.2 Settings Addr. Parameter Function C Setting Options Default Setting Comments 1334 Dis. Quadril. 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 RE(Z4), Resistance for phe faults RE(Z4) O-E 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) O-O Dis. Quadril. 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 R(Z5), Resistance for phph-faults 1343 X(Z5)+ Dis. Quadril. 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 1A 0.050 .. 600.000 12.000 5A 0.010 .. 120.000 2.400 1344 RE(Z5) O-E Dis. Quadril. 1345 T5 DELAY Dis. General Dis. Quadril. Dis. MHO 1346 X(Z5)- Dis. Quadril. X(Z5)+, Reactance for Forward direction RE(Z5), Resistance for phe faults 0.00 .. 30.00 sec; 0.90 sec T5 delay 1A 0.050 .. 600.000 4.000 5A 0.010 .. 120.000 0.800 X(Z5)-, Reactance for Reverse direction Forward Reverse Non-Directional Inactive Forward Operating mode Z1B (overrreach zone) 1A 0.050 .. 600.000 1.500 5A 0.010 .. 120.000 0.300 R(Z1B), Resistance for phph-faults 1A 0.050 .. 600.000 3.000 X(Z1B), Reactance 5A 0.010 .. 120.000 0.600 1A 0.050 .. 600.000 3.000 5A 0.010 .. 120.000 0.600 1351 Op. mode Z1B Dis. Quadril. 1352 R(Z1B) O-O Dis. Quadril. 1353 X(Z1B) Dis. Quadril. 1354 RE(Z1B) O-E Dis. Quadril. 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) O-O Dis. Quadril. 1A 0.050 .. 600.000 15.000 5A 0.010 .. 120.000 3.000 R(Z6), Resistance for phph-faults 1A 0.050 .. 600.000 15.000 5A 0.010 .. 120.000 3.000 1363 540 X(Z6)+ Dis. Quadril. RE(Z1B), Resistance for ph-e faults X(Z6)+, Reactance for Forward direction SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function C Setting Options Default Setting Comments 1364 Dis. Quadril. 1A 0.050 .. 600.000 15.000 5A 0.010 .. 120.000 3.000 RE(Z6), Resistance for phe faults RE(Z6) O-E 1365 T6 DELAY Dis. General Dis. Quadril. Dis. MHO 1366 X(Z6)- Dis. Quadril. 1401 Op. mode Z1 Dis. MHO 1402 ZR(Z1) Dis. MHO 1411 Op. mode Z2 Dis. MHO 1412 ZR(Z2) Dis. MHO 1421 Op. mode Z3 Dis. MHO 1422 ZR(Z3) Dis. MHO 1431 Op. mode Z4 Dis. MHO 1432 ZR(Z4) Dis. MHO 1441 Op. mode Z5 Dis. MHO 1442 ZR(Z5) Dis. MHO 1451 Op. mode Z1B Dis. MHO 1452 ZR(Z1B) Dis. MHO 1461 Op. mode Z6 Dis. MHO 1462 ZR(Z6) Dis. MHO 0.00 .. 30.00 sec; 1.50 sec T6 delay 1A 0.050 .. 600.000 4.000 5A 0.010 .. 120.000 0.800 X(Z6)-, Reactance for Reverse direction Forward Reverse Inactive Forward Operating mode Z1 1A 0.050 .. 200.000 2.500 ZR(Z1), Impedance Reach 5A 0.010 .. 40.000 0.500 Forward Reverse Inactive Forward Operating mode Z2 1A 0.050 .. 200.000 5.000 ZR(Z2), Impedance Reach 5A 0.010 .. 40.000 1.000 Forward Reverse Inactive Reverse Operating mode Z3 1A 0.050 .. 200.000 5.000 ZR(Z3), Impedance Reach 5A 0.010 .. 40.000 1.000 Forward Reverse Inactive Forward Operating mode Z4 1A 0.050 .. 200.000 10.000 ZR(Z4), Impedance Reach 5A 0.010 .. 40.000 2.000 Forward Reverse Inactive Inactive Operating mode Z5 1A 0.050 .. 200.000 10.000 ZR(Z5), Impedance Reach 5A 0.010 .. 40.000 2.000 Forward Reverse Inactive Forward Operating mode Z1B (extended zone) 1A 0.050 .. 200.000 3.000 5A 0.010 .. 40.000 0.600 ZR(Z1B), Impedance Reach Forward Reverse Inactive Inactive Operating mode Z6 1A 0.050 .. 200.000 15.000 ZR(Z6), Impedance Reach 5A 0.010 .. 40.000 3.000 1471A Mem.Polariz.PhE Dis. MHO 0.0 .. 100.0 % 15.0 % Voltage Memory polarization (phase-e) 1472A CrossPolarizPhE Dis. MHO 0.0 .. 100.0 % 15.0 % Cross polarization (phasee) 1473A Mem.Polariz.P-P Dis. MHO 0.0 .. 100.0 % 15.0 % Voltage Memory polarization (ph-ph) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 541 Functions, Settings, Information E.2 Settings Addr. Parameter Function 1474A CrossPolarizP-P 2002 Setting Options Default Setting Comments Dis. MHO 0.0 .. 100.0 % 15.0 % Cross polarization (phasephase) 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 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 SOTFO/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 Release Delay C 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. Weak Infeed 1 .. 60 sec 5 sec Time constant Tau 542 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 2512A Rec. Ext. 2513A T 3I0> Ext. 2514 3I0> Threshold Weak Infeed 2515 TM Weak Infeed 2516 TT 2517 1pol. Trip 2518 C Setting Options Default Setting Comments Weak Infeed 0.00 .. 30.00 sec 0.65 sec Reception extension Weak Infeed 0.00 .. 30.00 sec 0.60 sec 3I0> exceeded extension 1A 0.05 .. 1.00 A 0.50 A 5A 0.25 .. 5.00 A 2.50 A 3I0 threshold for neutral current pickup 0.00 .. 30.00 sec 0.40 sec WI delay single pole Weak Infeed 0.00 .. 30.00 sec 1.00 sec WI delay multi pole Weak Infeed ON OFF ON Single pole WI trip allowed 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 2612 3I0>> PICKUP Back-Up O/C 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 2622 3I0> Back-Up O/C 0.00 .. 30.00 sec; 0.30 sec T Iph>> Time delay 1A 0.05 .. 25.00 A; 0.50 A 3I0>> Pickup 5A 0.25 .. 125.00 A; 2.50 A 0.00 .. 30.00 sec; 0.50 sec T Iph> Time delay 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 2632 3I0> STUB Back-Up O/C SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 0.00 .. 30.00 sec; 0.30 sec T Iph STUB Time delay 1A 0.05 .. 25.00 A; 0.20 A 3I0> STUB Pickup 5A 0.25 .. 125.00 A; 1.00 A 543 Functions, Settings, Information E.2 Settings 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 Intervals 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 544 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter 2901 Function C MEASURE. SUPERV Measurem.Superv Setting Options Default Setting Comments ON OFF ON Measurement Supervision 2902A BALANCE U-LIMIT Measurem.Superv 10 .. 100 V 50 V Voltage Threshold for Balance Monitoring 2903A BAL. FACTOR U Measurem.Superv 0.58 .. 0.95 0.75 Balance Factor for Voltage Monitor 2904A BALANCE I LIMIT Measurem.Superv 1A 0.10 .. 1.00 A 0.50 A Current Balance Monitor 5A 0.50 .. 5.00 A 2.50 A 0.10 .. 0.95 0.50 Balance Factor for Current Monitor 1A 0.05 .. 2.00 A 0.10 A 5A Summated Current Monitoring Threshold 2905A BAL. FACTOR I Measurem.Superv 2906A I THRESHOLD Measurem.Superv 0.25 .. 10.00 A 0.50 A 2907A I FACTOR Measurem.Superv 0.00 .. 0.95 0.10 Summated Current Monitoring Factor 2908A T BAL. U LIMIT Measurem.Superv 5 .. 100 sec 5 sec T Balance Factor for Voltage Monitor 2909A T BAL. I LIMIT Measurem.Superv 5 .. 100 sec 5 sec T Current Balance Monitor 2910 Measurem.Superv ON OFF ON Fuse Failure Monitor 2911A FFM U>(min) Measurem.Superv 10 .. 100 V 30 V Minimum Voltage Threshold U> 2912A FFM I< (max) Measurem.Superv 1A 0.05 .. 1.00 A 0.10 A 5A 0.25 .. 5.00 A 0.50 A Maximum Current Threshold I< 2913A FFM U<max (3ph) Measurem.Superv 2 .. 100 V 15 V Maximum Voltage Threshold U< (3phase) 2914A FFM Idelta (3p) Measurem.Superv 1A 0.05 .. 1.00 A 0.10 A 5A 0.25 .. 5.00 A 0.50 A Delta Current Threshold (3phase) 2915 Measurem.Superv w/ CURR.SUP w/ I> & CBaux OFF w/ CURR.SUP Voltage Failure Supervision 2916A T V-Supervision Measurem.Superv 0.00 .. 30.00 sec 3.00 sec Delay Voltage Failure Supervision 2921 T mcb Measurem.Superv 0 .. 30 ms 0 ms VT mcb operating time 2941 A Measurem.Superv 0 .. 359 200 Limit setting PhiA 2942 B Measurem.Superv 0 .. 359 340 Limit setting PhiB 2943 I1> Measurem.Superv 1A 0.05 .. 2.00 A 0.05 A Minimum value I1> 5A 0.25 .. 10.00 A 0.25 A FUSE FAIL MON. V-Supervision 2944 U1> Measurem.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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 545 Functions, Settings, Information E.2 Settings Addr. Parameter 3103 Function Setting Options Default Setting Comments YES NO YES Block E/F for 1pole Dead time 0 .. 30 % 10 % Stabilisation Slope with Iphase 1A 0.01 .. 1.00 A 0.50 A 5A 0.05 .. 5.00 A 2.50 A 3Io-Min threshold for Teleprot. schemes 1A 0.003 .. 1.000 A 0.500 A 5A 0.015 .. 5.000 A 2.500 A BLOCK 1pDeadTim Earth Fault O/C 3104A Iph-STAB. Slope Earth Fault O/C 3105 Earth Fault O/C 3105 C 3IoMin Teleprot 3IoMin Teleprot Earth Fault O/C 3Io-Min threshold for Teleprot. schemes 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 546 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function C Setting Options Default Setting Comments 3131 Earth Fault O/C 1A 0.05 .. 25.00 A 1.00 A 3I0> Pickup 5A 0.25 .. 125.00 A 5.00 A 1A 0.003 .. 25.000 A 1.000 A 5A 0.015 .. 125.000 A 5.000 A 3I0> 3131 3I0> Earth Fault O/C 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 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 5A 0.015 .. 125.000 A 5.000 A 3141 3I0p PICKUP 3I0> Pickup 3I0p Pickup 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 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 5.80 sec 547 Functions, Settings, Information E.2 Settings Addr. Parameter Function 3150 3I0p InrushBlk 3151 C Setting Options Default Setting Comments Earth Fault O/C Earth Fault O/C Earth Fault O/C Earth Fault O/C NO YES NO Inrush Blocking 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-characteristic 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 5A 0.25 .. 5.00 A 0.25 A Min. earth current IY for polarizing 0.5 .. 10.0 V 0.5 V Min. neg. seq. polarizing voltage 3U2 1A 0.05 .. 1.00 A 0.05 A 5A 0.25 .. 5.00 A 0.25 A Min. neg. seq. polarizing current 3I2 0 .. 360 255 3166 3U2> Earth Fault O/C 3167 3I2> Earth Fault O/C 3168 548 PHI comp Earth Fault O/C Compensation angle PHI comp. for Sr SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function C Setting Options Default Setting Comments 3169 Earth Fault O/C 1A 0.1 .. 10.0 VA 0.3 VA 5A 0.5 .. 50.0 VA 1.5 VA Forward direction power threshold 10 .. 45 % 15 % 2nd harmonic ratio for inrush restraint 1A 0.50 .. 25.00 A 7.50 A 5A 2.50 .. 125.00 A 37.50 A Max.Current, overriding inrush restraint S forward 3170 2nd InrushRest Earth Fault O/C 3171 Imax InrushRest Earth Fault O/C 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 0.000 5A 0.000 .. 120.000 0.000 Reactance X of series capacitor 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 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 Release Delay SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 549 Functions, Settings, Information E.2 Settings Addr. Parameter Function 3406 EV. FLT. RECOG. 3407 Setting Options Default Setting Comments Autoreclosure with PICKUP with TRIP with TRIP Evolving fault recognition 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 protection 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 tripping 3423 AR w/ EF-O/C Autoreclosure YES NO YES AR with earth fault overcurrent 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 overcurrent 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 synchrocheck 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 550 C SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 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 synchrocheck 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 synchrocheck 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C Setting Options Default Setting Comments 551 Functions, Settings, Information E.2 Settings Addr. Parameter Function 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 synchrocheck 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 synchrocheck 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 5V 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 (Einstellmoglichnone keiten anwendungsabhangig) 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 difference 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 difference 552 C Setting Options Default Setting Comments SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 3515A AR SYNC-CHECK 3516 Setting Options Default Setting Comments Sync. Check YES NO YES AR at Usy2>, Usy1>, and Synchr. 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 difference 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 difference 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C 553 Functions, Settings, Information E.2 Settings Addr. Parameter Function 3631 O/U FREQ. f4 3632 3633 Setting Options Default Setting Comments Frequency Prot. ON: Alarm only ON: with Trip OFF ON: Alarm only Over/Under Frequency Protection stage f4 f4 PICKUP Frequency Prot. 45.50 .. 54.50 Hz 51.00 Hz f4 Pickup 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 overvoltage 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 554 C SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 3734 U1>> 3735 T U1>> 3736 3737 Setting Options Default Setting Comments Voltage Prot. 2.0 .. 220.0 V; 175.0 V U1>> Pickup Voltage Prot. 0.00 .. 100.00 sec; 1.00 sec T U1>> Time Delay U1> Compound Voltage Prot. OFF ON OFF U1> with Compounding 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 overvoltage 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 (Uphe) 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 (Uphph) 3769A Uphph<(<) RESET Voltage Prot. 1.01 .. 1.20 1.05 Uph-ph<(<) Reset ratio 3771 Voltage Prot. OFF Alarm Only ON U<Alarm U<<Trip OFF Operating mode U1 undervoltage prot. U1<(<) SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C 555 Functions, Settings, Information E.2 Settings Addr. Parameter Function 3772 U1< 3773 T U1< 3774 C Setting Options Default Setting Comments Voltage Prot. 1.0 .. 100.0 V; 0 30.0 V U1< Pickup Voltage Prot. 0.00 .. 100.00 sec; 2.00 sec T U1< Time Delay 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 YES 3903 1p-RETRIP (T1) Breaker Failure NO 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 Pole Discrepancy supervision 3932 T-PoleDiscrep. Breaker Failure 0.00 .. 30.00 sec; 2.00 sec 556 OFF Trip delay with pole discrepancy SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.2 Settings Addr. Parameter Function 4001 FCT TripSuperv. 4002 Setting Options Default Setting Comments TripCirc.Superv ON OFF OFF TRIP Circuit Supervision is 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 interface 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 permissible 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 interface 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 permissible 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 C 557 Functions, Settings, Information E.3 Information List E.3 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": lower case notation "on/off": *: <blank>: definitely set, not allocatable preset, allocatable not preset, allocatable neither preset nor allocatable In the column "Marked in Oscill. Record" the following applies: Type information number Data Unit General Interrogation IntS O * P N OF F * LED BO 12 8 21 1 Yes - Stop data transmission (DataStop) Device IntS O * P N OF F * LED BO 12 8 20 1 Yes - Reset LED (Reset LED) Device IntS O P 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 * - Hardware Test Mode (HWTestMod) Device IntS O * P N OF F * LED BO - Error FMS FO 1 (Error FMS1) Device OUT O * N OF F * LED BO 558 Chatter Suppression Device Relay Test mode (Test mode) Function Key - * Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. LED definitely set, not allocatable preset, allocatable not preset, allocatable neither preset nor allocatable Marked in Oscill. Record UPPER CASE NOTATION "M": lower case notation "m": *: <blank>: BI SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List Typ Log Buffers e of Info rma tion - Error FMS FO 2 (Error FMS2) Device OUT O * N OF F - Disturbance CFC (Distur.CFC) Device OUT On * Of f - Breaker OPENED (Brk OPENED) Device IntS * P * - Feeder EARTHED (FdrEARTHED) Device IntS * P - Setting Group A is active (P-GrpA act) - Configurable in Matrix IEC 60870-5-103 BO * * LED BO Change Group IntS O * P N OF F * LED BO 12 8 23 1 Yes Setting Group B is active (P-GrpB act) Change Group IntS O * P N OF F * LED BO 12 8 24 1 Yes - Setting Group C is active (P-GrpC act) Change Group IntS O * P N OF F * LED BO 12 8 25 1 Yes - Setting Group D is active (P-GrpD act) Change Group IntS O * P N OF F * LED BO 12 8 26 1 Yes - Fault Recording Start (FltRecSta) Osc. Fault Rec. IntS On * P Of f m LED BO - Reset Minimum and Maximum counter (ResMinMax) Min/Max meter IntS O P_E N v * - CB1-TEST trip/close - Only Testing L1 (CB1tst L1) - * * - CB1-TEST trip/close - Only Testing L2 (CB1tst L2) - * * - CB1-TEST trip/close - Only Testing L3 (CB1tst L3) - * * - CB1-TEST trip/close Testing Phases L123 (CB1tst 123) - * * - Controlmode REMOTE (ModeREMOTE) IntS On * P Of f LED BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Cntrl Authority Chatter Suppression LED Relay * Function Key BO Binary Input LED Trip (Fault) Log ON/OFF BO Event Log ON/OFF General Interrogation LED Data Unit * information number * Type LED Function Marked in Oscill. Record Description Ground Fault Log ON/OFF No. 559 information number Data Unit General Interrogation BO 10 1 85 1 Yes - Controlmode LOCAL (ModeLOCAL) Cntrl Authority IntS On * P Of f LED BO 10 1 86 1 Yes - Breaker (Breaker) Control Device CF_ On * D12 Of f BO 24 0 16 0 20 - Breaker (Breaker) Control Device DP CB 24 0 16 0 1 - Disconnect Switch (Disc.Swit.) Control Device CF_ On * D2 Of f 24 0 16 1 20 - Disconnect Switch (Disc.Swit.) Control Device DP CB 24 0 16 1 1 - Earth Switch (EarthSwit) Control Device CF_ On * D2 Of f 24 0 16 4 20 - Earth Switch (EarthSwit) Control Device DP CB 24 0 16 4 1 - 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 Control Open (E Sw Open) Device IntS * P * * - Interlocking: Earth switch Control Close (E Sw Cl.) Device IntS * P * * - Q2 Open/Close (Q2 Op/Cl) Control Device CF_ On * D2 Of f 24 0 16 2 20 - Q2 Open/Close (Q2 Op/Cl) Control Device DP CB 24 0 16 2 1 On * Of f BI BO On * Of f BI BO On * Of f On * Of f BI BO BI Chatter Suppression LED Relay IntS On * P Of f Function Key Cntrl Authority Binary Input Control Authority (Cntrl Auth) LED - 560 Configurable in Matrix IEC 60870-5-103 Marked in Oscill. Record Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Type Functions, Settings, Information E.3 Information List Yes Yes Yes Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List CF_ On * D2 Of f - Fan ON/OFF (Fan ON/ OFF) Control Device DP - Unlock data transmission Control via BI (UnlockDT) Device IntS * P - >Cabinet door open (>Door open) Process Data - >CB waiting for Spring charged (>CB wait) - BO On * Of f BI 24 0 16 3 20 CB 24 0 16 3 1 24 0 17 5 20 CB 24 0 17 5 1 Yes General Interrogation Control Device Data Unit Fan ON/OFF (Fan ON/ OFF) BI information number - On * Of f Type DP BO Chatter Suppression Q9 Open/Close (Q9 Op/Cl) Control Device Relay - Function Key CF_ On * D2 Of f Binary Input Q9 Open/Close (Q9 Op/Cl) Control Device LED - Configurable in Matrix IEC 60870-5-103 Marked in Oscill. Record Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Yes * * SP On * Of f * LED BI BO CB 10 1 1 1 Yes 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 Temperature (>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 O P_E N v - Error Systeminterface (SysIntErr.) Protocol IntS On * P Of f SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 * LED BO 561 Functions, Settings, Information E.3 Information List Device SP 2 Function Not Available (Non Existent) Device SP 3 >Synchronize Internal Real Time Clock (>Time Synch) Device SP * 4 >Trigger Waveform Capture (>Trig.Wave.Cap.) Osc. Fault Rec. 5 >Reset LED (>Reset LED) 7 >Setting Group Select Bit 0 (>Set Group Bit0) 8 >Setting Group Select Bit 1 (>Set Group Bit1) BI FK BO TO NL IN E CB * * LED BI BO SP On * m LED BI BO Device SP * * * LED BI BO Change Group SP * * * LED BI BO Change Group SP * * * LED BI BO 009.01 Failure EN100 Modul 00 (Failure Modul) EN100Modul 1 IntS On P Of f * LED BO 009.01 Failure EN100 Link 01 Channel 1 (Ch1) (Fail Ch1) EN100Modul 1 IntS On P Of f * LED BO 009.01 Failure EN100 Link 02 Channel 2 (Ch2) (Fail Ch2) EN100Modul 1 IntS On P Of f * LED BO 11 >User defined annunciation 1 (>Annunc. 1) Device SP * * * * LED BI BO 12 8 27 1 Yes 12 >User defined annunciation 2 (>Annunc. 2) Device SP * * * * LED BI BO 12 8 28 1 Yes 13 >User defined annunciation 3 (>Annunc. 3) Device SP * * * * LED BI BO 12 8 29 1 Yes 14 >User defined annunciation 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) SP * * LED BI BO 13 5 54 1 Yes 562 Device * Ground Fault Log ON/OFF LED Trip (Fault) Log ON/OFF * Event Log ON/OFF General Interrogation No Function configured (Not configured) Data Unit 1 information number IntS O * P N OF F Type Thresh.Switch Chatter Suppression Threshold Value 1 (ThreshVal1) Relay - Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Binary Input Function LED Description Marked in Oscill. Record No. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation * LED BO 13 5 81 1 Yes 52 At Least 1 Protection Funct. is Active (ProtActive) Device IntS O * P 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 O _Ev 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 Chatter Suppression OUT O * N OF F Relay Device is Operational and Device Protecting (Device OK) Function Key 51 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 563 Type information number Data Unit General Interrogation IntS O * P N OF F * LED BO 127 Auto Reclose ON/OFF (via Device system port) (AR ON/OFF) IntS O * P N OF F * LED BO 128 Teleprot. ON/OFF (via system port) (TelepONoff) IntS O * P N OF F * LED BO 130 Load angle Phi(PQ PosiMeasOUT * tive sequence) ((PQ Pos. urem.Super Seq.)) v * * LED BO 131 Load angle Phi(PQ) MeasOUT * blocked ((PQ Pos) block) urem.Super v * * LED BO 132 Setting error: |PhiA - PhiB| MeasOUT * < 3 ( Set wrong) urem.Super v * * 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.) MeasOUT * urem.Super v * * LED BO 12 8 32 1 Yes 162 Failure: Current Summation (Failure I) MeasOUT O * urem.Super N v OF F * LED BO 13 5 18 2 1 Yes 163 Failure: Current Balance (Fail I balance) MeasOUT O * urem.Super N v OF F * LED BO 13 5 18 3 1 Yes 164 Failure: General Voltage Supervision (Fail U Superv.) MeasOUT * urem.Super v * LED BO 12 8 33 1 Yes 564 * Chatter Suppression Device Relay Protection ON/OFF (via system port) (ProtON/ OFF) Function Key LED 126 Device Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation LED BO 13 5 18 4 1 Yes 167 Failure: Voltage Balance (Fail U balance) MeasOUT O * urem.Super N v OF F * LED BO 13 5 18 6 1 Yes 168 Failure: Voltage absent (Fail U absent) MeasOUT O * urem.Super N v OF F * LED BO 13 5 18 7 1 Yes 169 VT Fuse Failure (alarm >10s) (VT FuseFail>10s) MeasOUT O * urem.Super N v OF F * LED BO 13 5 18 8 1 Yes 170 VT Fuse Failure (alarm instantaneous) (VT FuseFail) MeasOUT O * urem.Super N v OF F * LED BO 171 Failure: Phase Sequence (Fail Ph. Seq.) MeasOUT O * urem.Super N v 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 Device A/D-conv.) OUT O * N OF F * LED BO 13 5 17 8 1 Yes 183 Error Board 1 (Error Board Device 1) OUT O * N OF F * LED BO 13 5 17 1 1 Yes 184 Error Board 2 (Error Board Device 2) OUT O * N OF F * LED BO 13 5 17 2 1 Yes 185 Error Board 3 (Error Board Device 3) OUT O * N OF F * LED BO 13 5 17 3 1 Yes Chatter Suppression * Relay Failure: Voltage summa- MeasOUT O * tion Phase-Earth (Fail U urem.Super N Ph-E) v OF F Function Key 165 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 565 Type information number Data Unit General Interrogation * LED BO 13 5 17 4 1 Yes 187 Error Board 5 (Error Board Device 5) OUT O * N OF F * LED BO 13 5 17 5 1 Yes 188 Error Board 6 (Error Board Device 6) OUT O * N OF F * LED BO 13 5 17 6 1 Yes 189 Error Board 7 (Error Board Device 7) OUT O * N OF F * LED BO 13 5 17 7 1 Yes 190 Error Board 0 (Error Board Device 0) 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 Device adjustment invalid (Alarm adjustm.) OUT O * N OF F * LED BO 13 5 18 1 1 Yes 194 Error: Neutral CT different Device from MLFB (Error neutralCT) OUT O * N OF F * LED BO 13 5 18 0 1 Yes 195 Failure: Broken Conductor MeasOUT O * (Fail Conductor) urem.Super N v OF F * LED BO 13 5 19 5 1 Yes 196 Fuse Fail Monitor is switched OFF (Fuse Fail M.OFF) * LED BO 13 5 19 6 1 Yes 566 Chatter Suppression OUT O * N OF F Relay Error Board 4 (Error Board Device 4) Function Key 186 MeasOUT O * urem.Super N v OF F Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List Type information number Data Unit General Interrogation Chatter Suppression BO Relay LED Function Key * Binary Input Measurement Supervision MeasOUT O * is switched OFF (MeasSup urem.Super N OFF) v OF F LED 197 Configurable in Matrix IEC 60870-5-103 Marked in Oscill. Record Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. 13 5 19 7 1 Yes 234.21 U<, U> blocked via opera- Voltage 00 tion (U<, U> blk) Prot. IntS On * P 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 (cos Set alarm) 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 ON N OF F * 13 5 23 1 2 Yes 302 Fault Event (Fault Event) P.System Data 2 OUT * * 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 * SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 ON LED BO 567 Type information number Data Unit General Interrogation 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. P.System from external (>Blk Man. Data 2 Close) SP O * N OF F * LED BI BO 15 0 7 1 Yes 361 >Failure: Feeder VT (MCB P.System tripped) (>FAIL:Feeder Data 2 VT) 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,CBTest) (>CB1 Pole L1) P.System Data 2 SP * * * LED BI BO 15 0 66 1 Yes 367 >CB1 Pole L2 (for AR,CBTest) (>CB1 Pole L2) P.System Data 2 SP * * * LED BI BO 15 0 67 1 Yes 368 >CB1 Pole L3 (for AR,CBTest) (>CB1 Pole L3) P.System Data 2 SP * * * LED BI BO 15 0 68 1 Yes 371 >CB1 READY (for AR,CBTest) (>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 Chatter Suppression Device Relay Warn: Limit of Memory Parameter exceeded (Warn Mem. Para.) Function Key LED 321 568 Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Trip (Fault) Log ON/OFF Marked in Oscill. Record LED Binary Input Configurable in Matrix IEC 60870-5-103 380 >CB aux. contact 3pole Open (>CB 3p Open) P.System Data 2 SP * * * LED BI BO 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 / P.System Stages (>Enable ARzones) Data 2 SP O ON N OFF OF F * LED BI BO 385 >Lockout SET (>Lockout SET) P.System Data 2 SP O * N OF F * LED BI 386 >Lockout RESET (>Lockout RESET) P.System Data 2 SP O * N OF F * LED 395 >I MIN/MAX Buffer Reset (>I MinMax Reset) Min/Max meter SP O N * * 396 >I1 MIN/MAX Buffer Reset Min/Max (>I1 MiMaReset) meter SP O N * 397 >U MIN/MAX Buffer Reset Min/Max (>U MiMaReset) meter SP O N 398 >Uphph MIN/MAX Buffer Reset (>UphphMiMaRes) Min/Max meter SP 399 >U1 MIN/MAX Buffer Reset (>U1 MiMa Reset) Min/Max meter 400 Yes BO 15 0 35 1 Yes BI BO 15 0 36 1 Yes LED BI BO * LED BI BO * * LED BI BO O N * * LED BI BO SP O N * * LED BI BO >P MIN/MAX Buffer Reset Min/Max (>P MiMa Reset) meter SP O N * * LED BI BO 401 >S MIN/MAX Buffer Reset Min/Max (>S MiMa Reset) meter SP O N * * LED BI BO 402 >Q MIN/MAX Buffer Reset Min/Max (>Q MiMa Reset) meter SP O N * * LED BI BO 403 >Idmd MIN/MAX Buffer Min/Max Reset (>Idmd MiMaReset) meter SP O N * * LED BI BO 404 >Pdmd MIN/MAX Buffer Reset (>Pdmd MiMaReset) SP O N * * LED BI BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Min/Max meter Chatter Suppression 1 Relay 79 Function Key 15 0 Ground Fault Log ON/OFF General Interrogation Typ Log Buffers e of Info rma tion Data Unit Function information number Description Type No. Event Log ON/OFF Functions, Settings, Information E.3 Information List 569 Trip (Fault) Log ON/OFF Marked in Oscill. Record LED Binary Input Type information number Data Unit General Interrogation 405 >Qdmd MIN/MAX Buffer Reset (>Qdmd MiMaReset) Min/Max meter SP O N * * LED BI BO 406 >Sdmd MIN/MAX Buffer Reset (>Sdmd MiMaReset) 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 Min/Max Buffer Reset (>PF MiMaR- meter eset) 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 P.System PICKUP E) 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 P.System Only Phase L1 (Relay TRIP Data 2 1pL1) OUT * * * LED BO 513 Relay TRIP command P.System Only Phase L2 (Relay TRIP Data 2 1pL2) OUT * * * LED BO 570 * Configurable in Matrix IEC 60870-5-103 Chatter Suppression Typ Log Buffers e of Info rma tion Relay Function Function Key Description Ground Fault Log ON/OFF No. Event Log ON/OFF Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 514 Relay TRIP command P.System Only Phase L3 (Relay TRIP Data 2 1pL3) 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 O ON P N OFF OF F * LED BO 533 Primary fault current IL1 (IL1 =) P.System Data 2 VI * 534 Primary fault current IL2 (IL2 =) P.System Data 2 VI 535 Primary fault current IL3 (IL3 =) P.System Data 2 VI 536 Relay Definitive TRIP (Definitive TRIP) P.System Data 2 OUT O N 545 Time from Pickup to drop P.System out (PU Time) 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 * 561 Manual close signal detected (Man.Clos.Detect) P.System Data 2 562 CB CLOSE command for manual closing (Man.Close Cmd) 563 15 0 17 7 4 No * ON OFF 15 0 17 8 4 No * ON OFF 15 0 17 9 4 No * LED BO 15 0 18 0 2 No ON * LED BO 15 0 21 0 2 No OUT O N * * LED BO 15 0 21 1 1 No P.System Data 2 OUT * * * LED BO 15 0 21 2 1 No 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 ON N OFF OF F m LED BO 591 Single pole open detected P.System in L1 (1pole open L1) Data 2 OUT O ON N OFF OF F m LED BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 ON * Chatter Suppression ON OFF Relay Yes Function Key 1 Binary Input 17 0 Ground Fault Log ON/OFF 15 0 Trip (Fault) Log ON/OFF General Interrogation Configurable in Matrix IEC 60870-5-103 Data Unit LED Typ Log Buffers e of Info rma tion Event Log ON/OFF Function information number Description Type No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List * 571 Type information number Data Unit General Interrogation m LED BO 593 Single pole open detected P.System in L3 (1pole open L3) Data 2 OUT O ON N OFF OF F 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 interrupted current L1 ( IL1 =) Statistics VI 1028 Accumulation of interrupted current L2 ( IL2 =) Statistics VI 1029 Accumulation of interrupted current L3 ( 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- Fault TANCE (Xpri =) 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 Chatter Suppression OUT O ON N OFF OF F Relay Single pole open detected P.System in L2 (1pole open L2) Data 2 Function Key 592 572 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 information number Data Unit General Interrogation 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 Fault K0,angle(K0) Locator (Flt.Loc.ErrorK0) 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%] Fault (BCD d[100%]) Locator OUT * * * LED BO 1152 BCD Fault location valid (BCD dist. VALID) OUT * * * LED BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Chatter Suppression ON OFF Relay VI Function Key Fault Locator Binary Input Flt Locator: Distance [%] to fault (d[%] =) LED 1120 Fault Locator Configurable in Matrix IEC 60870-5-103 Marked in Oscill. Record Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Type Functions, Settings, Information E.3 Information List 573 Type information number Data Unit General Interrogation SP O * N OF F * LED BI BO 16 6 5 1 Yes 1307 >Earth Fault O/C Block Earth Fault 3I0>> (>EF BLOCK 3I0>>) 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- Earth Fault neous trip (>EF InstTRIP) O/C SP O ON N OFF OF F * 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 Teleprot. E/F SP BLOCK (>EF TeleprotBLK) 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 On Of f * LED BI BO 16 6 18 1 Yes 1319 >E/F Carrier RECEPTION, Channel 2 (>EF Rec.Ch2) Teleprot. E/F SP On On Of f * LED BI BO 16 6 19 1 Yes 1320 >E/F Unblocking: UNBLOCK, Channel 1 (>EF UB ub 1) Teleprot. E/F SP O ON N OF F * LED BI BO 16 6 20 1 Yes 1321 >E/F Unblocking: BLOCK, Channel 1 (>EF UB bl 1) Teleprot. E/F SP O ON N OF F * LED BI BO 16 6 21 1 Yes Chatter Suppression >Earth Fault O/C Block Earth Fault 3I0>>> (>EF BLK 3I0>>>) O/C Relay Binary Input 1305 574 Configurable in Matrix IEC 60870-5-103 Function Key LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation Teleprot. E/F SP O ON N OF F * LED BI BO 16 6 22 1 Yes 1323 >E/F Unblocking: BLOCK, Channel 2 (>EF UB bl 2) Teleprot. E/F SP O ON N OF F * LED BI BO 16 6 23 1 Yes 1324 >E/F BLOCK Echo Signal (>EF BlkEcho) Teleprot. E/F SP O ON N OF F * 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 On Of f * 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 On Of f * 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 On Of f * 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 ON N OF F * 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 ON N OF F * 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 ON N OF F * 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 ON N OFF OF F * 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Chatter Suppression >E/F Unblocking: UNBLOCK, Channel 2 (>EF UB ub 2) Relay Binary Input 1322 * Configurable in Matrix IEC 60870-5-103 Function Key LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 575 Configurable in Matrix IEC 60870-5-103 1335 Earth fault protection Trip Earth Fault is blocked (EF TRIP O/C BLOCK) OUT O ON N OFF OF F * 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 1354 E/F 3I0>>> PICKED UP (EF Earth Fault 3I0>>>Pickup) 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 1359 E/F picked up REVERSE (EF Earth Fault reverse) O/C OUT * ON * 1361 E/F General TRIP command (EF Trip) Earth Fault O/C OUT * * 1362 Earth fault protection: Earth Fault Trip 1pole L1 (E/F Trip L1) O/C OUT * 1363 Earth fault protection: Earth Fault Trip 1pole L2 (E/F Trip L2) O/C 1364 58 2 No LED BO 16 6 59 2 No * LED BO 16 6 61 2 No ON m LED BO 16 6 62 2 Yes OUT * ON m LED BO 16 6 63 2 Yes Earth fault protection: Earth Fault Trip 1pole L3 (E/F Trip L3) 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 576 Chatter Suppression 16 6 Relay BO Function Key Yes Binary Input 2 Ground Fault Log ON/OFF 45 Trip (Fault) Log ON/OFF 16 6 Event Log ON/OFF General Interrogation Typ Log Buffers e of Info rma tion Data Unit LED Function information number Description Type No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List Earth Fault O/C OUT * 1371 E/F Telep. Carrier SEND signal, Phase L1 (EF Tele SEND L1) 1372 No Teleprot. E/F OUT On On * LED BO 16 6 71 1 No 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 O * P 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 Teleprot. E/F OUT * Blocking (EF TeleTransBlk) * 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 * * LED BO 16 6 89 2 No SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 ON On Chatter Suppression 2 Relay 70 Function Key 16 6 Binary Input BO ON OFF Ground Fault Log ON/OFF LED Trip (Fault) Log ON/OFF * Event Log ON/OFF General Interrogation E/F Inrush picked up (EF InrushPU) Data Unit 1370 Configurable in Matrix IEC 60870-5-103 information number Typ Log Buffers e of Info rma tion Type Function LED Description Marked in Oscill. Record No. 577 Functions, Settings, Information E.3 Information List EF Tele.Carrier RECEPTION, L1, Device1 (EF Rec.L1 Dev1) 1392 EF Tele.Carrier RECEPTION, L2, Device1 (EF Rec.L2 Dev1) Teleprot. E/F OUT On On Of f * LED BO 1393 EF Tele.Carrier RECEPTION, L3, Device1 (EF Rec.L3 Dev1) Teleprot. E/F OUT On On Of f * LED BO 1394 EF Tele.Carrier RECEPTION, L1, Device2 (EF Rec.L1 Dev2) Teleprot. E/F OUT On On Of f * LED BO 1395 EF Tele.Carrier RECEPTION, L2, Device2 (EF Rec.L2 Dev2) Teleprot. E/F OUT On On Of f * LED BO 1396 EF Tele.Carrier RECEPTION, L3, Device2 (EF Rec.L3 Dev2) Teleprot. E/F OUT On On Of f * LED BO 1397 EF Tele.Carrier RECEPTION, L1, Device3 (EF Rec.L1 Dev3) Teleprot. E/F OUT On On Of f * LED BO 1398 EF Tele.Carrier RECEPTION, L2, Device3 (EF Rec.L2 Dev3) Teleprot. E/F OUT On On Of f * LED BO 1399 EF Tele.Carrier RECEPTION, L3, Device3 (EF Rec.L3 Dev3) Teleprot. E/F OUT On On Of f * 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 1404 >BF Activate 3I0> threshold (>BFactivate3I0>) Breaker Failure SP O * N OF F * LED BI BO 578 Relay BO Function Key LED Binary Input * Ground Fault Log ON/OFF Teleprot. E/F OUT On On Of f Trip (Fault) Log ON/OFF BO Event Log ON/OFF LED General Interrogation 1391 * * Data Unit E/F Tele.Blocking: Send Teleprot. E/F OUT * signal with jump (EF Tele BL Jump) information number 1390 Configurable in Matrix IEC 60870-5-103 Type Typ Log Buffers e of Info rma tion Chatter Suppression Function LED Description Marked in Oscill. Record No. 16 6 90 2 No 16 6 10 3 1 Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation Breaker Failure SP O * N OF F * LED BI BO 1424 >BF: Start only delay time Breaker T2 (>BF STARTonlyT2) Failure SP O ON N OFF OF F * LED BI BO 1432 >BF: External release (>BF Breaker release) 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. Breaker ON/OFF via BI (BkrFailON/ Failure offBI) IntS O * P N OF F * LED BO 1451 Breaker failure is switched Breaker OFF (BkrFail OFF) Failure OUT O * N OF F * LED BO 16 6 15 1 1 Yes 1452 Breaker failure is Breaker BLOCKED (BkrFail BLOCK) Failure OUT O ON N OFF OF F * 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 Breaker started (BF Start) Failure OUT * ON OFF * LED BO 16 6 16 1 2 Yes Chatter Suppression Binary Input >BF: External start 3pole (>BF Start 3pole) Relay LED 1415 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 579 OUT * ON * LED BO 1473 BF Trip T1 (local trip) Breaker only phase L2 (BF T1-TRIP Failure 1pL2) OUT * ON * LED BO 1474 BF Trip T1 (local trip) Breaker only phase L3 (BF T1-TRIP Failure 1pL3) 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 defective 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 1495 BF Trip End fault stage (BF Breaker EndFlt TRIP) Failure OUT * ON * LED BO 1496 BF Pole discrepancy Breaker pickup (BF CBdiscrSTART) 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 ON N OFF OF F * LED 2701 >AR: Switch on autoAutorecloreclose function (>AR on) sure SP * * * LED 2702 >AR: Switch off autoAutorecloreclose function (>AR off) sure SP * * * 2703 >AR: Block auto-reclose function (>AR block) Autoreclosure SP O * N OF F 2711 >External start of internal AutorecloAuto reclose (>AR Start) sure SP * 2712 >AR: External trip L1 for AR start (>Trip L1 AR) SP * 580 BO 12 8 37 1 Yes BI BO 40 1 1 No LED BI BO 40 2 1 No * LED BI BO 40 3 1 Yes ON * LED BI BO 40 11 2 Yes ON * LED BI BO 40 12 2 Yes Chatter Suppression No Relay 2 Function Key 85 Binary Input 12 8 Ground Fault Log ON/OFF General Interrogation BF Trip T1 (local trip) Breaker only phase L1 (BF T1-TRIP Failure 1pL1) Data Unit 1472 Autoreclosure Configurable in Matrix IEC 60870-5-103 information number LED Typ Log Buffers e of Info rma tion Trip (Fault) Log ON/OFF Function Type Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Trip (Fault) Log ON/OFF Marked in Oscill. Record LED Binary Input Type information number Data Unit General Interrogation 2713 >AR: External trip L2 for AR start (>Trip L2 AR) Autoreclosure SP * ON * LED BI BO 40 13 2 Yes 2714 >AR: External trip L3 for AR start (>Trip L3 AR) Autoreclosure SP * ON * LED BI BO 40 14 2 Yes 2715 >AR: External 1pole trip for AR start (>Trip 1pole AR) Autoreclosure SP * ON * LED BI BO 40 15 2 Yes 2716 >AR: External 3pole trip for AR start (>Trip 3pole AR) Autoreclosure SP * ON * LED BI BO 40 16 2 Yes 2727 >AR: Remote Close signal Autoreclo(>AR RemoteClose) sure SP * ON * LED BI BO 40 22 2 Yes 2731 >AR: Sync. release from ext. sync.-check (>Sync.release) Autoreclosure SP * * * LED BI BO 40 31 2 Yes 2737 >AR: Block 1pole AR-cycle Autoreclo(>BLOCK 1pole AR) sure SP O * N OF F * LED BI BO 40 32 1 Yes 2738 >AR: Block 3pole AR-cycle Autoreclo(>BLOCK 3pole AR) sure SP O * N OF F * LED BI BO 40 33 1 Yes 2739 >AR: Block 1phase-fault AR-cycle (>BLK 1phase AR) Autoreclosure SP O * N OF F * LED BI BO 40 34 1 Yes 2740 >AR: Block 2phase-fault AR-cycle (>BLK 2phase AR) Autoreclosure SP O * N OF F * LED BI BO 40 35 1 Yes 2741 >AR: Block 3phase-fault AR-cycle (>BLK 3phase AR) Autoreclosure SP O * N OF F * LED BI BO 40 36 1 Yes 2742 >AR: Block 1st AR-cycle (>BLK 1.AR-cycle) Autoreclosure SP O * N OF F * LED BI BO 40 37 1 Yes 2743 >AR: Block 2nd AR-cycle (>BLK 2.AR-cycle) Autoreclosure SP O * N OF F * LED BI BO 40 38 1 Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Chatter Suppression Typ Log Buffers e of Info rma tion Relay Function Function Key Description Ground Fault Log ON/OFF No. Event Log ON/OFF Functions, Settings, Information E.3 Information List 581 Type information number Data Unit General Interrogation Autoreclosure SP O * N OF F * LED BI BO 40 39 1 Yes 2745 >AR: Block 4th and higher AutorecloAR-cycles (>BLK 4.-n. AR) sure SP O * N OF F * LED BI BO 40 40 1 Yes 2746 >AR: External Trip for AR start (>Trip for AR) Autoreclosure SP * ON * LED BI BO 40 41 2 Yes 2747 >AR: External pickup L1 for AR start (>Pickup L1 AR) Autoreclosure SP * ON * LED BI BO 40 42 2 Yes 2748 >AR: External pickup L2 for AR start (>Pickup L2 AR) Autoreclosure SP * ON * LED BI BO 40 43 2 Yes 2749 >AR: External pickup L3 for AR start (>Pickup L3 AR) Autoreclosure SP * ON * LED BI BO 40 44 2 Yes 2750 >AR: External pickup 1phase for AR start (>Pickup 1ph AR) Autoreclosure SP * ON * LED BI BO 40 45 2 Yes 2751 >AR: External pickup 2phase for AR start (>Pickup 2ph AR) Autoreclosure SP * ON * LED BI BO 40 46 2 Yes 2752 >AR: External pickup 3phase for AR start (>Pickup 3ph AR) Autoreclosure SP * ON * LED BI BO 40 47 2 Yes 2781 AR: Auto-reclose is switched off (AR off) Autoreclosure OUT O * N OF F * LED BO 40 81 1 Yes 2782 AR: Auto-reclose is switched on (AR on) Autoreclosure IntS * P * * LED BO 12 8 16 1 Yes 2783 AR: Auto-reclose is blocked (AR is blocked) Autoreclosure OUT O * N OF F * LED BO 40 83 1 Yes 2784 AR: Auto-reclose is not ready (AR not ready) Autoreclosure OUT * ON * LED BO 12 8 13 0 1 Yes 2787 AR: Circuit breaker not ready (CB not ready) Autoreclosure OUT * * * LED BO 40 87 1 No Chatter Suppression Binary Input >AR: Block 3rd AR-cycle (>BLK 3.AR-cycle) Relay LED 2744 582 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 LED Configurable in Matrix IEC 60870-5-103 2788 AR: CB ready monitoring window expired (AR TCBreadyExp) Autoreclosure OUT * ON * LED BO 2796 AR: Auto-reclose ON/OFF via BI (AR on/off BI) Autoreclosure IntS * P * * LED BO 2801 AR: Auto-reclose in Autorecloprogress (AR in progress) sure OUT * ON * LED 2809 AR: Start-signal moniAutoreclotoring time expired (AR T- sure Start Exp) OUT * ON * 2810 AR: Maximum dead time expired (AR TdeadMax Exp) Autoreclosure OUT * ON 2818 AR: Evolving fault recognition (AR evolving Flt) Autoreclosure OUT * 2820 AR is set to operate after 1p trip only (AR Program1pole) Autoreclosure 2821 AR dead time after evolving fault (AR Td. evol.Flt) 2839 10 1 2 Yes LED BO 40 17 4 2 No * LED BO 40 17 5 2 No ON * LED BO 40 11 8 2 Yes OUT * * * LED BO 40 14 3 1 No Autoreclosure OUT * ON * LED BO 40 19 7 2 No AR dead time after 1pole trip running (AR Tdead 1pTrip) Autoreclosure OUT * ON * LED BO 40 14 8 2 Yes 2840 AR dead time after 3pole trip running (AR Tdead 3pTrip) Autoreclosure OUT * ON * LED BO 40 14 9 2 Yes 2841 AR dead time after 1phase fault running (AR Tdead 1pFlt) Autoreclosure OUT * ON * LED BO 40 15 0 2 Yes 2842 AR dead time after 2phase fault running (AR Tdead 2pFlt) Autoreclosure OUT * ON * LED BO 40 15 1 2 Yes 2843 AR dead time after 3phase fault running (AR Tdead 3pFlt) Autoreclosure OUT * ON * LED BO 40 15 4 2 Yes 2844 AR 1st cycle running (AR 1stCyc. run.) Autoreclosure OUT * ON * LED BO 40 15 5 2 Yes 2845 AR 2nd cycle running (AR Autoreclo2ndCyc. run.) sure OUT * ON * LED BO 40 15 7 2 Yes 2846 AR 3rd cycle running (AR 3rdCyc. run.) Autoreclosure OUT * ON * LED BO 40 15 8 2 Yes 2847 AR 4th or higher cycle Autoreclorunning (AR 4thCyc. run.) sure OUT * ON * LED BO 40 15 9 2 Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Chatter Suppression 40 Relay BO Function Key No Binary Input 2 Ground Fault Log ON/OFF 88 Trip (Fault) Log ON/OFF 40 Event Log ON/OFF General Interrogation Typ Log Buffers e of Info rma tion Data Unit Function information number Description Type No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 583 Type information number Data Unit General Interrogation ON * LED BO 40 13 0 2 Yes 2851 AR: Close command (AR CLOSE Cmd.) Autoreclosure OUT * ON m LED BO 12 8 12 8 2 No 2852 AR: Close command after Autoreclo1pole, 1st cycle (AR sure Close1.Cyc1p) OUT * * * LED BO 40 15 2 1 No 2853 AR: Close command after Autoreclo3pole, 1st cycle (AR sure Close1.Cyc3p) OUT * * * LED BO 40 15 3 1 No 2854 AR: Close command 2nd cycle (and higher) (AR Close 2.Cyc) Autoreclosure OUT * * * LED BO 12 8 12 9 1 No 2857 AR: RDT Close command after TDEADxTRIP (AR CLOSE RDT TD) Autoreclosure OUT * * * LED BO 2861 AR: Reclaim time is running (AR T-Recl. run.) Autoreclosure OUT * * * LED BO 40 16 1 1 No 2862 AR successful (AR successful) Autoreclosure OUT * * * LED BO 40 16 2 1 No 2864 AR: 1pole trip permitted Autorecloby internal AR (AR 1p Trip sure Perm) OUT * * * LED BO 40 16 4 1 Yes 2865 AR: Synchro-check request (AR Sync.Request) Autoreclosure OUT * * * LED BO 40 16 5 2 Yes 2871 AR: TRIP command 3pole (AR TRIP 3pole) Autoreclosure OUT * ON * LED BO 40 17 1 2 Yes 2889 AR 1st cycle zone exten- Autoreclosion release (AR 1.CycZo- sure neRel) OUT * * * LED BO 40 16 0 1 No 2890 AR 2nd cycle zone exten- Autoreclosion release (AR 2.CycZo- sure neRel) OUT * * * LED BO 40 16 9 1 No 2891 AR 3rd cycle zone exten- Autoreclosion release (AR 3.CycZo- sure neRel) OUT * * * LED BO 40 17 0 1 No 2892 AR 4th cycle zone exten- Autoreclosion release (AR 4.CycZo- sure neRel) OUT * * * LED BO 40 17 2 1 No 2893 AR zone extension (general) (AR Zone Release) OUT * * * LED BO 40 17 3 1 Yes 584 Chatter Suppression OUT * Relay AR cycle is running in ADT Autoreclomode (AR ADT run.) sure Function Key 2848 Autoreclosure Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List OUT * 2895 No. of 1st AR-cycle CLOSE Statistics commands,1pole (AR #Close1./1p=) VI 2896 No. of 1st AR-cycle CLOSE Statistics commands,3pole (AR #Close1./3p=) VI 2897 No. of higher AR-cycle Statistics CLOSE commands,1p (AR #Close2./1p=) VI 2898 No. of higher AR-cycle Statistics CLOSE commands,3p (AR #Close2./3p=) VI 2901 >Switch on synchro-check Sync. Check SP function (>Sync. on) 2902 >Switch off synchrocheck function (>Sync. off) 2903 LED BI BO Sync. Check SP * * * LED BI BO >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 Sync. Check SP line / Sync (>Sync. synch) * * * 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 O * P N OF F * LED SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Relay * Function Key * Binary Input * Ground Fault Log ON/OFF LED Trip (Fault) Log ON/OFF * Event Log ON/OFF ON BO General Interrogation Autoreclosure Data Unit AR Remote close signal send (AR Remote Close) information number 2894 Configurable in Matrix IEC 60870-5-103 Type Typ Log Buffers e of Info rma tion Chatter Suppression Function LED Description Marked in Oscill. Record No. 40 12 9 2 No BO 585 Type information number Data Unit General Interrogation LED BO 41 31 1 Yes 2932 Synchro-check is BLOCKED (Sync. BLOCK) Sync. Check OUT O ON N OFF OF F * 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 supervision time expired (Sync.Tsup.Exp) Sync. Check OUT O N ON * LED BO 41 35 1 No 2936 Synchro-check request by Sync. Check OUT O control (Sync. req.CNTRL) N ON * LED BO 41 36 1 No 2941 Synchronization is running (Sync. running) Sync. Check OUT O ON N OF F * LED BO 41 41 1 Yes 2942 Synchro-check override/ bypass (Sync.Override) Sync. Check OUT O ON N OF F * 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 Sync. Check OUT O ON than limit (Sync. Udiff>) N OFF OF F * LED BO 41 47 1 Yes Chatter Suppression * Relay Synchro-check is Sync. Check OUT O * switched OFF (Sync. OFF) N OF F Function Key 2931 586 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation * LED BO 41 48 1 Yes 2949 Sync. Angle diff. greater than limit (Sync. -diff>) Sync. Check OUT O ON N OFF OF F * 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 Sync. Check OUT O ON + 3Hz) (SYNC fsy2>>) N OFF OF F * LED BO 2971 SYNC frequency fsy2 < (fn Sync. Check OUT O ON + 3Hz) (SYNC fsy2<<) N OFF OF F * LED BO 2972 SYNC frequency fsy1 > (fn Sync. Check OUT O ON + 3Hz) (SYNC fsy1>>) N OFF OF F * LED BO 2973 SYNC frequency fsy1 < (fn Sync. Check OUT O ON + 3Hz) (SYNC fsy1<<) N OFF OF F * LED BO 2974 SYNC voltage Usy2 >Umax (P.3504) (SYNC Usy2>>) Sync. Check OUT O ON N OFF OF F * LED BO 2975 SYNC voltage Usy2 < U> (P.3503) (SYNC Usy2<<) Sync. Check OUT O ON N OFF OF F * LED BO 2976 SYNC voltage Usy1 >Umax (P.3504) (SYNC Usy1>>) Sync. Check OUT O ON N OFF OF F * LED BO 2977 SYNC voltage Usy1 < U> (P.3503) (SYNC Usy1<<) Sync. Check OUT O ON N OFF OF F * LED BO Chatter Suppression Sync. Check OUT O ON N OFF OF F Relay Sync. Freq. diff. greater than limit (Sync. fdiff>) Function Key 2948 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 587 SYNC Udiff too large (Usy2<Usy1) (SYNC Usy2<Usy1) Sync. Check OUT O ON N OFF OF F * LED BO 2980 SYNC fdiff too large (fsy2>fsy1) (SYNC fsy2>fsy1) Sync. Check OUT O ON N OFF OF F * LED BO 2981 SYNC fdiff too large (fsy2<fsy1) (SYNC fsy2<fsy1) Sync. Check OUT O ON N OFF OF F * LED BO 2982 SYNC PHIdiff too large (PHIsy2>PHIsy1) (SYNC sy2>sy1) Sync. Check OUT O ON N OFF OF F * LED BO 2983 SYNC PHIdiff too large (PHIsy2<PHIsy1) (SYNC sy2<sy1) Sync. Check OUT O ON N OFF OF F * LED BO 3196 Local relay in Teststate (local Teststate) Prot. Interface IntS O ON P N OF F * LED FK BO TO NL IN E 3215 Incompatible Firmware Versions (Wrong Firmware) Prot. Interface OUT O N * * LED BO 3217 Prot Int 1: Own Datas Prot. Interreceived (PI1 Data reflec) face OUT O * N OF F * LED BO 3218 Prot Int 2: Own Datas Prot. Interreceived (PI2 Data reflec) face OUT O * N OF F * LED BO 3227 >Prot Int 1: Transmitter is Prot. Interswitched off (>PI1 light face off) SP * LED 588 BI General Interrogation 2979 Data Unit BO information number LED Type * Chatter Suppression Sync. Check OUT O ON N OFF OF F Relay SYNC Udiff too large (Usy2>Usy1) (SYNC Usy2>Usy1) Function Key 2978 O * N OF F Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation SP O * N OF F * LED BI 3229 Prot Int 1: Reception of faulty data (PI1 Data fault) Prot. Interface OUT O * N OF F * LED BO 93 13 5 1 Yes 3230 Prot Int 1: Total receiption Prot. Interfailure (PI1 Datafailure) 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. Interface OUT O * N OF F * LED BO 93 13 7 1 Yes 3232 Prot Int 2: Total receiption Prot. Interfailure (PI2 Datafailure) face OUT O * N OF F * LED BO 93 13 8 1 Yes 3233 Device table has inconsis- Prot. Intertent numbers (DT incon- face sistent) OUT O * N OF F * LED BO 3234 Device tables are unequal Prot. Inter(DT unequal) face OUT O * N OF F * LED BO 3235 Differences between Prot. Intercommon parameters (Par. face different) OUT O * N OF F * LED BO 3236 Different PI for transmit and receive (PI1<->PI2 error) Prot. Interface OUT O * N OF F * LED BO 3239 Prot Int 1: Transmission delay too high (PI1 TD alarm) Prot. Interface OUT O * N OF F * LED BO 93 13 9 1 Yes 3240 Prot Int 2: Transmission delay too high (PI2 TD alarm) Prot. Interface OUT O * N OF F * LED BO 93 14 0 1 Yes Chatter Suppression >Prot Int 2: Transmitter is Prot. Interswitched off (>PI2 light face off) Relay Binary Input 3228 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Function Key LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List BO 589 information number Data Unit General Interrogation * 3244 Prot Int 2: Connected with relay ID (PI2 with) Prot. Interface VI O * N OF F * 3274 PI1: IEEE C37.94 not supported by module (PI1: C37.94 n/a) Prot. Interface OUT On * Of f * LED BO 3275 PI2: IEEE C37.94 not supported by module (PI2: C37.94 n/a) Prot. Interface OUT On * Of f * LED BO 3457 System operates in a closed Ringtopology (Ringtopology) Prot. Interface OUT O * N OF F * LED BO 93 14 1 1 Yes 3458 System operates in a open Chaintopology (Chaintopology) Prot. Interface OUT O * N OF F * LED BO 93 14 2 1 Yes 3464 Communication topology Prot. Interis complete (Topol face complete) OUT O * N OF F * LED BO 3475 Relay 1 in Logout state (Rel1Logout) Prot. Interface IntS O * P N OF F * LED FK BO TO NL IN E 93 14 3 1 Yes 3476 Relay 2 in Logout state (Rel2Logout) Prot. Interface IntS O * P N OF F * LED FK BO TO NL IN E 93 14 4 1 Yes 3477 Relay 3 in Logout state (Rel3Logout) Prot. Interface IntS O * P N OF F * LED FK BO TO NL IN E 93 14 5 1 Yes Chatter Suppression O * N OF F Relay VI Function Key Prot. Interface Binary Input Prot Int 1: Connected with relay ID (PI1 with) LED 3243 590 Configurable in Matrix IEC 60870-5-103 Marked in Oscill. Record Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Type Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 3484 Local activation of Logout Prot. Interstate (Logout) face IntS O * P N OF F * LED FK BO TO NL IN E 3487 Equal IDs in constellation Prot. Inter(Equal IDs) face OUT O * N OF F * LED BO 3491 Relay 1 in Login state (Rel1 Login) Prot. Interface OUT O * N OF F * LED 3492 Relay 2 in Login state (Rel2 Login) Prot. Interface OUT O * N OF F * 3493 Relay 3 in Login state (Rel3 Login) Prot. Interface OUT O * N OF F 3541 >Remote Command 1 signal input (>Remote CMD 1) Remote Signals SP 3542 >Remote Command 2 signal input (>Remote CMD 2) Remote Signals 3543 >Remote Command 3 signal input (>Remote CMD 3) 3544 19 1 1 Yes LED BO 93 19 2 1 Yes * LED BO 93 19 3 1 Yes On * Of f * LED BI BO SP On * Of f * LED BI BO Remote Signals SP On * Of f * LED BI BO >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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Chatter Suppression 93 Relay BO Function Key Yes Binary Input 1 Ground Fault Log ON/OFF 14 9 Trip (Fault) Log ON/OFF 93 Event Log ON/OFF General Interrogation Typ Log Buffers e of Info rma tion Data Unit LED Function information number Description Type No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 591 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 General Interrogation * Data Unit On * Of f information number SP Type Remote Signals Chatter Suppression Binary Input >Remote Signal 1 input (>Rem. Signal 1) Relay LED 3549 592 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation 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 Chatter Suppression Binary Input >Remote Signal 15 input (>Rem.Signal15) Relay LED 3563 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 593 Type information number Data Unit General Interrogation 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 Remote received (Rem.Sig10recv) Signals OUT On * Of f * LED BO 93 16 7 1 Yes 3583 Remote signal 11 Remote received (Rem.Sig11recv) Signals OUT On * Of f * LED BO 93 16 8 1 Yes 3584 Remote signal 12 Remote received (Rem.Sig12recv) Signals OUT On * Of f * LED BO 93 16 9 1 Yes 3585 Remote signal 13 Remote received (Rem.Sig13recv) Signals OUT On * Of f * LED BO 93 17 0 1 Yes 3586 Remote signal 14 Remote received (Rem.Sig14recv) Signals OUT On * Of f * LED BO 93 17 1 1 Yes 3587 Remote signal 15 Remote received (Rem.Sig15recv) Signals OUT On * Of f * LED BO 93 17 2 1 Yes 3588 Remote signal 16 Remote received (Rem.Sig16recv) Signals OUT On * Of f * LED BO 93 17 3 1 Yes 3589 Remote signal 17 Remote received (Rem.Sig17recv) Signals OUT On * Of f * LED BO 93 17 4 1 Yes 3590 Remote signal 18 Remote received (Rem.Sig18recv) Signals OUT On * Of f * LED BO 93 17 5 1 Yes Chatter Suppression Remote Signals Relay Remote signal 5 received (Rem.Sig 5recv) Function Key LED 3577 594 Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation * LED BO 93 17 6 1 Yes 3592 Remote signal 20 Remote received (Rem.Sig20recv) Signals OUT On * Of f * LED BO 93 17 7 1 Yes 3593 Remote signal 21 Remote received (Rem.Sig21recv) Signals OUT On * Of f * LED BO 93 17 8 1 Yes 3594 Remote signal 22 Remote received (Rem.Sig22recv) Signals OUT On * Of f * LED BO 93 17 9 1 Yes 3595 Remote signal 23 Remote received (Rem.Sig23recv) Signals OUT On * Of f * LED BO 93 18 0 1 Yes 3596 Remote signal 24 Remote received (Rem.Sig24recv) Signals OUT On * Of f * LED BO 93 18 1 1 Yes 3603 >BLOCK Distance protection (>BLOCK Distance) * * LED BI BO 3611 >ENABLE Z1B (with setted Dis. General SP Time Delay) (>ENABLE Z1B) O * N OF F * LED BI BO 28 11 1 Yes 3613 >ENABLE Z1B instantanous (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 Dis. General SP (>BLOCK Z4 Ph-E) O * N OF F * LED BI BO 28 19 1 Yes 3620 >BLOCK Z5 for ph-e loops Dis. General SP (>BLOCK Z5 Ph-E) O * N OF F * LED BI BO 28 20 1 Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 * Chatter Suppression OUT On * Of f Relay Remote signal 19 Remote received (Rem.Sig19recv) Signals Function Key 3591 Dis. General SP Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 595 Type information number Data Unit General Interrogation Dis. General SP O * N OF F * LED BI BO 28 41 1 Yes 3622 >BLOCK Z6 for ph-e loops Dis. General SP (>BLOCK Z6 Ph-E) 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 ON N OFF OF F * 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) (DisErrorK0(>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 Chatter Suppression >BLOCK Z6-Trip (>BLOCK Z6-Trip) Relay Binary Input 3621 596 Configurable in Matrix IEC 60870-5-103 Function Key LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation 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 Dis. General OUT * selected reverse (Dis.Loop L1-E r) ON OFF * LED BO 3708 Distance Loop L2E Dis. General OUT * selected reverse (Dis.Loop L2-E r) ON OFF * LED BO Chatter Suppression Dis. General OUT * Relay Distance Pickup L12 (Dis.Pickup L12) Function Key 3685 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 597 Type information number Data Unit General Interrogation * LED BO 3710 Distance Loop L12 Dis. General OUT * selected reverse (Dis.Loop L1-2 r) ON OFF * LED BO 3711 Distance Loop L23 Dis. General OUT * selected reverse (Dis.Loop L2-3 r) ON OFF * LED BO 3712 Distance Loop L31 Dis. General OUT * selected reverse (Dis.Loop L3-1 r) 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 Chatter Suppression ON OFF Relay Distance Loop L3E Dis. General OUT * selected reverse (Dis.Loop L3-E r) Function Key 3709 598 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation * * LED BO 3747 Distance Pickup Z1B, Loop Dis. General OUT * L1E (Dis. Z1B L1E) * * LED BO 3748 Distance Pickup Z1B, Loop Dis. General OUT * L2E (Dis. Z1B L2E) * * LED BO 3749 Distance Pickup Z1B, Loop Dis. General OUT * L3E (Dis. Z1B L3E) * * LED BO 3750 Distance Pickup Z1B, Loop Dis. General OUT * L12 (Dis. Z1B L12) * * LED BO 3751 Distance Pickup Z1B, Loop Dis. General OUT * L23 (Dis. Z1B L23) * * LED BO 3752 Distance Pickup Z1B, Loop Dis. General OUT * L31 (Dis. Z1B L31) * * 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 Chatter Suppression Dis. General OUT * Relay Distance Pickup Z1, Loop L31 (Dis. Z1 L31) Function Key 3746 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 599 Type information number Data Unit General Interrogation * LED BO 28 20 2 2 No 3803 Distance TRIP command - Dis. General OUT * Only Phase L2 (Dis.Trip 1pL2) ON * LED BO 28 20 3 2 No 3804 Distance TRIP command - Dis. General OUT * Only Phase L3 (Dis.Trip 1pL3) ON * LED BO 28 20 4 2 No 3805 Distance TRIP command Dis. General OUT * Phases L123 (Dis.Trip 3p) ON * LED BO 28 20 5 2 No 3811 Distance TRIP singlephase Z1 (Dis.TripZ1/1p) Dis. General OUT * * * LED BO 28 21 1 2 No 3813 Distance TRIP singlephase Z1B (Dis.TripZ1B1p) Dis. General OUT * * * LED BO 28 21 3 2 No 3816 Distance TRIP singlephase 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 Dis. General OUT * single-ph Flt. (DisTRIP3p. Z1sf) * * LED BO 28 22 4 2 No 3824 DisTRIP 3phase in Z1 with Dis. General OUT * multi-ph Flt. (DisTRIP3p. Z1mf) * * 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- Dis. General OUT * tection scheme (DisTRIP Z1B Tel) * * LED BO 28 25 1 2 No Chatter Suppression ON Relay Distance TRIP command - Dis. General OUT * Only Phase L1 (Dis.Trip 1pL1) Function Key 3802 600 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Trip (Fault) Log ON/OFF Marked in Oscill. Record LED Binary Input Configurable in Matrix IEC 60870-5-103 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 ON N OFF OF F * LED BI BO 4005 >Dist. teleprotection: Carrier faulty (>Dis.RecFail) Teleprot. Dist. SP On * Of f * LED BI BO 4006 >Dis.Tele. Carrier RECEPTION Channel 1 (>DisTel Rec.Ch1) Teleprot. Dist. SP On On Of f * LED BI 4007 >Dis.Tele.Carrier RECEPTION Channel 1,L1 (>Dis.T.RecCh1L1) Teleprot. Dist. SP On On Of f * LED 4008 >Dis.Tele.Carrier RECEPTION Channel 1,L2 (>Dis.T.RecCh1L2) Teleprot. Dist. SP On On Of f * 4009 >Dis.Tele.Carrier RECEPTION Channel 1,L3 (>Dis.T.RecCh1L3) Teleprot. Dist. SP On On Of f 4010 >Dis.Tele. Carrier RECEPTION Channel 2 (>Dis.T.Rec.Ch2) Teleprot. Dist. SP 4030 >Dis.Tele. Unblocking: UNBLOCK Channel 1 (>Dis.T.UB ub 1) Teleprot. Dist. 4031 >Dis.Tele. Unblocking: BLOCK Channel 1 (>Dis.T.UB bl 1) 4032 Yes BO 29 6 1 Yes BI BO 29 7 1 Yes LED BI BO 29 8 1 Yes * LED BI BO 29 9 1 Yes On On Of f * LED BI BO 29 10 1 Yes SP On On Of f * LED BI BO 29 30 1 Yes Teleprot. Dist. SP On On Of f * LED BI BO 29 31 1 Yes >Dis.Tele. Unblocking: UNBLOCK Ch. 1, L1 (>Dis.T.UB ub1L1) Teleprot. Dist. SP On On Of f * LED BI BO 29 32 1 Yes 4033 >Dis.Tele. Unblocking: UNBLOCK Ch. 1, L2 (>Dis.T.UB ub1L2) Teleprot. Dist. SP On On Of f * LED BI BO 29 33 1 Yes 4034 >Dis.Tele. Unblocking: UNBLOCK Ch. 1, L3 (>Dis.T.UB ub1L3) Teleprot. Dist. SP On On Of f * LED BI BO 29 34 1 Yes 4035 >Dis.Tele. Unblocking: UNBLOCK Channel 2 (>Dis.T.UB ub 2) Teleprot. Dist. SP On On Of f * LED BI BO 29 35 1 Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Chatter Suppression 1 Relay 3 Function Key 29 Ground Fault Log ON/OFF General Interrogation Typ Log Buffers e of Info rma tion Data Unit Function information number Description Type No. Event Log ON/OFF Functions, Settings, Information E.3 Information List 601 Type information number Data Unit General Interrogation Teleprot. Dist. SP On On Of f * LED BI BO 29 36 1 Yes 4040 >Dis.Tele. BLOCK Echo Signal (>Dis.T.BlkEcho) Teleprot. Dist. SP On On Of f * LED BI BO 29 40 1 Yes 4050 Dis. Teleprotection ON/OFF via BI (Dis.T.on/off BI) Teleprot. Dist. IntS O * P N OF F * LED BO 4051 Teleprotection is switched Device ON (Telep. ON) 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 Teleprot. signal, L1 (Dis.T.SEND L1) Dist. OUT * * * LED BO 4058 Dis. Telep. Carrier SEND Teleprot. signal, L2 (Dis.T.SEND L2) Dist. OUT * * * LED BO 4059 Dis. Telep. Carrier SEND Teleprot. signal, L3 (Dis.T.SEND L3) 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 Teleprot. Blocking (Dis.T.Trans.Blk) Dist. OUT * ON * LED BO 29 68 2 No 4070 Dis. Tele.Blocking: carrier Teleprot. STOP signal (Dis.T.BL Dist. STOP) 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 Chatter Suppression Binary Input >Dis.Tele. Unblocking: BLOCK Channel 2 (>Dis.T.UB bl 2) Relay LED 4036 602 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 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 RECEPTION, L1, Device1 (Dis.T.RecL1Dev1) Teleprot. Dist. OUT On On Of f * LED BO 4086 Dis.Tele.Carrier RECEPTION, L2, Device1 (Dis.T.RecL2Dev1) Teleprot. Dist. OUT On On Of f * LED BO 4087 Dis.Tele.Carrier RECEPTION, L3, Device1 (Dis.T.RecL3Dev1) Teleprot. Dist. OUT On On Of f * LED BO 4088 Dis.Tele.Carrier RECEPTION, L1, Device2 (Dis.T.RecL1Dev2) Teleprot. Dist. OUT On On Of f * LED BO 4089 Dis.Tele.Carrier RECEPTION, L2, Device2 (Dis.T.RecL2Dev2) Teleprot. Dist. OUT On On Of f * LED BO 4090 Dis.Tele.Carrier RECEPTION, L3, Device2 (Dis.T.RecL3Dev2) Teleprot. Dist. OUT On On Of f * LED BO 4091 Dis.Tele.Carrier RECEPTION, L1, Device3 (Dis.T.RecL1Dev3) Teleprot. Dist. OUT On On Of f * LED BO 4092 Dis.Tele.Carrier RECEPTION, L2, Device3 (Dis.T.RecL2Dev3) Teleprot. Dist. OUT On On Of f * LED BO 4093 Dis.Tele.Carrier RECEPTION, L3, Device3 (Dis.T.RecL3Dev3) Teleprot. Dist. OUT On On Of f * LED BO 4160 >BLOCK Power Swing detection (>Pow. Swing BLK) Power Swing SP * LED 4163 Power Swing unstable (P.Swing unstab.) Power Swing OUT O N * LED SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 ON BI General Interrogation LED Data Unit * information number * Type OUT * Chatter Suppression Teleprot. Dist. Relay DisTel Blocking: carrier STOP signal, L1 (Dis.T.BL STOPL1) Function Key LED 4082 O ON N OFF OF F Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List BO BO 603 Type information number Data Unit General Interrogation OUT O ON N OFF OF F * LED BO 29 16 4 1 Yes 4166 Power Swing TRIP command (Pow. Swing TRIP) Power Swing OUT O N * LED BO 29 16 6 1 No 4167 Power Swing detected in L1 (Pow. Swing L1) Power Swing OUT O ON N OFF OF F * LED BO 4168 Power Swing detected in L2 (Pow. Swing L2) Power Swing OUT O ON N OFF OF F * LED BO 4169 Power Swing detected in L3 (Pow. Swing L3) Power Swing OUT O ON N OFF OF F * 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 Weak Infeed SP Infeed stage (>BLOCK del. WI) O ON N OFF OF F * LED BI BO 4205 >Reception (channel) for Weak Infeed SP Weak Infeed OK (>WI rec. OK) O ON N OFF OF F * LED BI BO 4206 >Receive signal for Weak Infeed (>WI reception) Weak Infeed SP O ON N OFF OF F * 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 ON N OFF OF F * LED BO 25 22 1 Yes 4223 Weak Infeed is ACTIVE (Weak Inf ACTIVE) Weak Infeed OUT * * LED BO 25 23 1 Yes 604 * * Chatter Suppression Power Swing Relay Power Swing detected (Power Swing) Function Key LED 4164 ON Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 4225 Weak Infeed Zero seq. current detected (3I0 detected) Weak Infeed OUT O ON N OFF OF F * LED BO 4226 Weak Infeed Undervoltg. L1 (WI U L1<) Weak Infeed OUT O ON N OFF OF F * LED BO 4227 Weak Infeed Undervoltg. L2 (WI U L2<) Weak Infeed OUT O ON N OFF OF F * LED BO 4228 Weak Infeed Undervoltg. L3 (WI U L3<) Weak Infeed OUT O ON N OFF OF F * LED BO 4229 WI TRIP with zero Weak Infeed OUT * sequence current (WI TRIP 3I0) * * LED BO 4231 Weak Infeed PICKED UP (WeakInf. PICKUP) Weak Infeed OUT * OFF * LED BO 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 Weak Infeed OUT * command (WeakInfeed TRIP) * * LED 4242 Weak Infeed TRIP command - Only L1 (Weak TRIP 1p.L1) Weak Infeed OUT * ON * 4243 Weak Infeed TRIP command - Only L2 (Weak TRIP 1p.L2) Weak Infeed OUT * ON 4244 Weak Infeed TRIP command - Only L3 (Weak TRIP 1p.L3) Weak Infeed OUT * 4245 Weak Infeed TRIP command L123 (Weak TRIP L123) 4246 ECHO Send SIGNAL (ECHO SIGNAL) 41 2 No LED BO 25 42 2 No * LED BO 25 43 2 No ON * LED BO 25 44 2 No Weak Infeed OUT * ON * LED BO 25 45 2 No Weak Infeed OUT O N ON * LED BO 25 46 2 Yes Chatter Suppression 25 Relay BO Function Key Yes Binary Input 2 Ground Fault Log ON/OFF 31 Trip (Fault) Log ON/OFF 25 Event Log ON/OFF SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 General Interrogation LED Typ Log Buffers e of Info rma tion Data Unit Function information number Description Type No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 605 Type information number Data Unit General Interrogation * LED BO 4248 ECHO Tele.Carrier RECEP- Echo Rec. TION, Device2 (ECHO Rec. ov.PI Dev2) OUT O ON N OF F * LED BO 4249 ECHO Tele.Carrier RECEP- Echo Rec. TION, Device3 (ECHO Rec. ov.PI Dev3) OUT O ON N OF F * LED BO 4253 >BLOCK Instantaneous SOTF Overcurrent (>BLOCK SOTF-O/C) SP * * LED 4271 SOTF-O/C is switched OFF SOTF Over(SOTF-O/C OFF) curr. OUT O * N OF F * LED BO 25 71 1 Yes 4272 SOTF-O/C is BLOCKED (SOTF-O/C BLOCK) SOTF Overcurr. OUT O ON N OFF OF F * LED BO 25 72 1 Yes 4273 SOTF-O/C is ACTIVE (SOTF-O/C ACTIVE) SOTF Overcurr. OUT * * * LED BO 25 73 1 Yes 4281 SOTF-O/C PICKED UP (SOTF-O/C PICKUP) SOTF Overcurr. OUT * OFF * LED BO 25 81 2 Yes 4282 SOTF-O/C Pickup L1 (SOF O/CpickupL1) SOTF Overcurr. OUT * ON * LED BO 25 82 2 Yes 4283 SOTF-O/C Pickup L2 (SOF O/CpickupL2) SOTF Overcurr. OUT * ON * LED BO 25 83 2 Yes 4284 SOTF-O/C Pickup L3 (SOF O/CpickupL3) SOTF Overcurr. OUT * ON * LED BO 25 84 2 Yes 4295 SOTF-O/C TRIP command L123 (SOF O/CtripL123) SOTF Overcurr. 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 606 * BI Chatter Suppression OUT O ON N OF F Relay ECHO Tele.Carrier RECEP- Echo Rec. TION, Device1 (ECHO Rec. ov.PI Dev1) Function Key 4247 SOTF Overcurr. Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation 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 ON N OFF OF F * LED BO 51 22 1 Yes 4432 DTT TRIP command - Only DTT Direct L1 (DTT TRIP 1p. L1) Trip OUT * ON * LED BO 51 32 2 No 4433 DTT TRIP command - Only DTT Direct L2 (DTT TRIP 1p. L2) Trip OUT * ON * LED BO 51 33 2 No 4434 DTT TRIP command - Only DTT Direct L3 (DTT TRIP 1p. L3) 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 Chatter Suppression Binary Input >Direct Transfer Trip INPUT Phase L2 (>DTT Trip L2) Relay LED 4413 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 607 Functions, Settings, Information E.3 Information List Typ Log Buffers e of Info rma tion 5209 >BLOCK frequency protection stage f4 (>BLOCK f4) Frequency Prot. SP 5211 Configurable in Matrix IEC 60870-5-103 BI Frequency protection is Frequency switched OFF (Freq. OFF) Prot. OUT O * N OF F * 5212 Frequency protection is BLOCKED (Freq. BLOCKED) Frequency Prot. OUT O ON N OFF OF F 5213 Frequency protection is ACTIVE (Freq. ACTIVE) Frequency Prot. 5215 Frequency protection undervoltage Blk (Freq UnderV Blk) 5232 LED BO 70 18 1 1 Yes * LED BO 70 18 2 1 Yes OUT O * N OF F * LED BO 70 18 3 1 Yes Frequency Prot. OUT On On Of Off f * LED BO 70 23 8 1 Yes 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 608 Chatter Suppression Yes Relay 1 Function Key 18 0 Ground Fault Log ON/OFF 70 Trip (Fault) Log ON/OFF BO Event Log ON/OFF General Interrogation LED Data Unit * information number O * N OF F Type Binary Input Function LED Description Marked in Oscill. Record No. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List OUT * 6854 >Trip circuit superv. 1: Trip Relay (>TripC1 TripRel) TripCirc.Superv 6855 >Trip circuit superv. 1: Breaker Relay (>TripC1 Bkr.Rel) 6856 LED BI BO TripCirc.Superv SP O * N OF F * LED BI BO >Trip circuit superv. 2: Trip Relay (>TripC2 TripRel) TripCirc.Superv SP O * N OF F * LED BI BO 6857 >Trip circuit superv. 2: Breaker Relay (>TripC2 Bkr.Rel) TripCirc.Superv SP O * N OF F * LED BI BO 6858 >Trip circuit superv. 3: Trip Relay (>TripC3 TripRel) TripCirc.Superv SP O * N OF F * LED BI BO 6859 >Trip circuit superv. 3: Breaker Relay (>TripC3 Bkr.Rel) TripCirc.Superv SP O * N OF F * LED BI BO 6861 Trip circuit supervision OFF (TripC OFF) TripCirc.Superv OUT O * N OF F * LED BO 6865 Failure Trip Circuit (FAIL: Trip cir.) TripCirc.Superv OUT O * N OF F * LED BO 6866 TripC1 blocked: Binary input is not set (TripC1 ProgFAIL) TripCirc.Superv OUT O * N OF F * LED BO 6867 TripC2 blocked: Binary input is not set (TripC2 ProgFAIL) TripCirc.Superv OUT O * N OF F * LED BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Relay * Function Key O * N OF F Binary Input SP Ground Fault Log ON/OFF LED Trip (Fault) Log ON/OFF * Event Log ON/OFF * General Interrogation Frequency Prot. Data Unit Frequency protection: TimeOut Stage f4 (Time Out f4) information number 5243 Configurable in Matrix IEC 60870-5-103 Type Typ Log Buffers e of Info rma tion Chatter Suppression Function LED Description Marked in Oscill. Record No. 12 8 36 1 Yes BO 609 Functions, Settings, Information E.3 Information List TripCirc.Superv OUT O * N OF F 7104 >BLOCK Backup OverCur- Back-Up O/C SP rent I>> (>BLOCK O/C I>>) 7105 BO 64 4 1 Yes >BLOCK Backup OverCur- Back-Up O/C SP rent I> (>BLOCK O/C I>) O * N OF F * LED BI BO 64 5 1 Yes 7106 >BLOCK Backup OverCur- Back-Up O/C SP rent Ip (>BLOCK O/C Ip) O * N OF F * LED BI BO 64 6 1 Yes 7110 >Backup OverCurrent InstantaneousTrip (>O/C InstTRIP) Back-Up O/C SP O ON N OFF OF F * 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- Back-Up O/C SP tion (>I-STUB ENABLE) O ON N OFF OF F * 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 ON N OFF OF F * LED BO 64 52 1 Yes 7153 Backup O/C is ACTIVE (O/C Back-Up O/C OUT * ACTIVE) * * 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 610 Chatter Suppression BI Relay LED Function Key * Binary Input O * N OF F Ground Fault Log ON/OFF LED Trip (Fault) Log ON/OFF * Event Log ON/OFF General Interrogation TripC3 blocked: Binary input is not set (TripC3 ProgFAIL) Data Unit 6868 Configurable in Matrix IEC 60870-5-103 information number Typ Log Buffers e of Info rma tion Type Function LED Description Marked in Oscill. Record No. BO SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation ON * LED BO 64 64 2 Yes 7165 Backup O/C PICKUP EARTH Back-Up O/C OUT * (O/C Pickup E) 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 Back-Up O/C OUT * (O/C PickupL123E) 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 Back-Up O/C OUT * PICKUP I>) ON * LED BO 64 92 2 Yes 7193 Backup O/C Pickup Ip (O/C Back-Up O/C OUT * PICKUP Ip) ON * LED BO 64 93 2 Yes 7201 O/C I-STUB Pickup (I-STUB Back-Up O/C OUT * PICKUP) ON OFF * LED BO 64 10 1 2 Yes Chatter Suppression Back-Up O/C OUT * Relay Backup O/C PICKUP L3 (O/C Pickup L3) Function Key 7164 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 611 Functions, Settings, Information E.3 Information List Back-Up O/C OUT * 7212 2 No Backup O/C TRIP - Only L1 Back-Up O/C OUT * (O/C TRIP 1p.L1) ON * LED BO 64 11 2 2 No 7213 Backup O/C TRIP - Only L2 Back-Up O/C OUT * (O/C TRIP 1p.L2) ON * LED BO 64 11 3 2 No 7214 Backup O/C TRIP - Only L3 Back-Up O/C OUT * (O/C TRIP 1p.L3) 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 - Testing Only L1 (CB1-TESTtrip L1) OUT O * N OF F * LED BO 15 3 25 1 Yes 7326 CB1-TEST TRIP command - Testing Only L2 (CB1-TESTtrip L2) OUT O * N OF F * LED BO 15 3 26 1 Yes 7327 CB1-TEST TRIP command - Testing Only L3 (CB1-TESTtrip L3) 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 612 Chatter Suppression 72 Relay 12 8 Function Key BO Binary Input LED Ground Fault Log ON/OFF * Trip (Fault) Log ON/OFF * Event Log ON/OFF General Interrogation Backup O/C General TRIP command (O/C TRIP) Data Unit 7211 Configurable in Matrix IEC 60870-5-103 information number Typ Log Buffers e of Info rma tion Type Function LED Description Marked in Oscill. Record No. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 CB-TEST canceled due to CB already OPEN (CBTSTstop OPEN) Testing OUT O _Ev N * 7348 CB-TEST canceled due to CB was NOT READY (CBTSTstop NOTr) Testing OUT O _Ev N * 7349 CB-TEST canceled due to CB stayed CLOSED (CBTSTstop CLOS) Testing OUT O _Ev N * 7350 CB-TEST was successful (CB-TST .OK.) Testing OUT O _Ev N * 10201 >BLOCK Uph-e>(>) Over- Voltage volt. (phase-earth) (>Uph- Prot. e>(>) BLK) SP * * * LED BI BO 10202 >BLOCK Uph-ph>(>) Overvolt (phase-phase) (>Uph-ph>(>) BLK) Voltage Prot. SP * * * LED BI BO 10203 >BLOCK 3U0>(>) Overvolt. (zero sequence) (>3U0>(>) BLK) Voltage Prot. SP * * * LED BI BO 10204 >BLOCK U1>(>) Overvolt. Voltage (positive seq.) (>U1>(>) Prot. BLK) SP * * * LED BI BO 10205 >BLOCK U2>(>) Overvolt. Voltage (negative seq.) (>U2>(>) Prot. BLK) 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 Voltage (positive seq.) (>U1<(<) Prot. BLK) SP * * * LED BI BO 10215 Uph-e>(>) Overvolt. is Voltage switched OFF (Uph-e>(>) Prot. OFF) OUT O * N OF F * LED BO General Interrogation 7347 Data Unit * information number OUT O _Ev N Type Testing Chatter Suppression Binary Input CB-TEST canceled due to Power Sys. Fault (CBTSTstop FLT.) Relay LED 7346 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 73 15 1 Yes 613 Type information number Data Unit General Interrogation * LED BO 73 16 1 Yes 10217 Uph-ph>(>) Overvolt. is switched OFF (Uphph>(>) 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 ON N OFF OF F * 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 ON N OFF OF F * 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 ON N OFF OF F * 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 ON N OFF OF F * LED BO 73 24 1 Yes 10225 Uph-e<(<) Undervolt. is Voltage switched OFF (Uph-e<(<) Prot. OFF) OUT O * N OF F * LED BO 73 25 1 Yes 10226 Uph-e<(<) Undervolt. is Voltage BLOCKED (Uph-e<(<) BLK) Prot. OUT O ON N OFF OF F * LED BO 73 26 1 Yes Chatter Suppression OUT O ON N OFF OF F Relay Uph-e>(>) Overvolt. is Voltage BLOCKED (Uph-e>(>) BLK) Prot. Function Key 10216 614 Configurable in Matrix IEC 60870-5-103 Binary Input LED Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation OUT O * N OF F * LED BO 73 27 1 Yes 10228 Uphph<(<) Undervolt. is BLOCKED (Uph-ph<(<) BLK) Voltage Prot. OUT O ON N OFF OF F * 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 ON N OFF OF F * 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>> Voltage Pickup) 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> Voltage TimeOut) Prot. OUT * * * LED BO 10246 Uph-e>> TimeOut (Uphe>> TimeOut) Voltage Prot. OUT * * * LED BO 10247 Uph-e>(>) TRIP command Voltage (Uph-e>(>) TRIP) Prot. OUT * ON * LED BO 73 47 2 Yes 10248 Uph-e> Pickup L1 (Uph-e> Voltage PU L1) Prot. OUT * * * LED BO 73 13 3 2 Yes 10249 Uph-e> Pickup L2 (Uph-e> Voltage PU L2) Prot. OUT * * * LED BO 73 13 4 2 Yes 10250 Uph-e> Pickup L3 (Uph-e> Voltage PU L3) Prot. OUT * * * LED BO 73 13 5 2 Yes 10251 Uph-e>> Pickup L1 (Uphe>> PU L1) OUT * * * LED BO 73 13 6 2 Yes SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Chatter Suppression Voltage Prot. Relay Uph-ph<(<) Undervolt. is switched OFF (Uphph<(<) OFF) Function Key LED 10227 Voltage Prot. Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 615 Type information number Data Unit General Interrogation OUT * * * LED BO 73 13 7 2 Yes 10253 Uph-e>> Pickup L3 (Uphe>> PU L3) Voltage Prot. OUT * * * LED BO 73 13 8 2 Yes 10255 Uph-ph> Pickup (Uphph> Voltage Pickup) 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 Chatter Suppression Voltage Prot. Relay Uph-e>> Pickup L2 (Uphe>> PU L2) Function Key LED 10252 616 Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Type information number Data Unit General Interrogation 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<< Voltage Pickup) 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< Voltage TimeOut) Prot. OUT * * * LED BO Chatter Suppression Voltage Prot. Relay U1> Pickup (U1> Pickup) Function Key LED 10280 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List 617 Type information number Data Unit General Interrogation OUT * * * LED BO 10317 Uph-e<(<) TRIP command Voltage (Uph-e<(<) TRIP) Prot. OUT * ON * LED BO 73 11 7 2 Yes 10318 Uph-e< Pickup L1 (Uph-e< Voltage PU L1) Prot. OUT * * * LED BO 73 14 5 2 Yes 10319 Uph-e< Pickup L2 (Uph-e< Voltage PU L2) Prot. OUT * * * LED BO 73 14 6 2 Yes 10320 Uph-e< Pickup L3 (Uph-e< Voltage PU L3) Prot. OUT * * * LED BO 73 14 7 2 Yes 10321 Uph-e<< Pickup L1 (Uphe<< PU L1) Voltage Prot. OUT * * * LED BO 73 14 8 2 Yes 10322 Uph-e<< Pickup L2 (Uphe<< PU L2) Voltage Prot. OUT * * * LED BO 73 14 9 2 Yes 10323 Uph-e<< Pickup L3 (Uphe<< PU L3) Voltage Prot. OUT * * * LED BO 73 15 0 2 Yes 10325 Uph-ph< Pickup (Uph-ph< Voltage Pickup) Prot. OUT * ON OFF * LED BO 73 12 5 2 Yes 10326 Uph-ph<< Pickup (Uphph<< 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 Chatter Suppression Voltage Prot. Relay Uph-e<< TimeOut (Uphe<< TimeOut) Function Key LED 10316 618 Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. Marked in Oscill. Record Functions, Settings, Information E.3 Information List SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.3 Information List OUT * 14080 E/F 3I0>>> is blocked (E/F Earth Fault 3I0>>>BLOCK) O/C 14081 E/F 3I0>> is blocked (E/F 3I0>> BLOCK) 14082 BO Earth Fault O/C OUT O ON N OFF OF F * LED BO E/F 3I0> is blocked (E/F 3I0> BLOCK) Earth Fault O/C OUT O ON N OFF OF F * LED BO 14083 E/F 3I0p is blocked (E/F 3I0p BLOCK) Earth Fault O/C OUT O ON N OFF OF F * LED BO 30053 Fault recording is running Osc. Fault (Fault rec. run.) 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 * Relay LED Function Key * Binary Input OUT O ON N OFF OF F Ground Fault Log ON/OFF BO Trip (Fault) Log ON/OFF LED Event Log ON/OFF * * General Interrogation Voltage Prot. Data Unit Uph-ph<< Pickup L3-L1 (Uphph<< PU L31) information number 10338 Configurable in Matrix IEC 60870-5-103 Type Typ Log Buffers e of Info rma tion Chatter Suppression Function LED Description Marked in Oscill. Record No. 73 15 6 2 Yes 619 Functions, Settings, Information E.4 Group Alarms E.4 Group Alarms Nr. Bedeutung Nr. Bedeutung 140 Stor-Sammelmel. 144 181 192 194 Storung 5V Storung 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 Storung I Storung Isymm Storung Uphe Storung Usymm Storung Umess Fuse-Failure FFM unverzogert Stor. Ph-Folge Stor Batterie Storung BG1 Storung BG2 Storung BG3 Storung BG4 Storung BG5 Storung BG6 Storung BG7 Storung BG0 Stor. Offset Stor.Abgleichw. >U-Wdl.-Aut. Dis Feh.K0(Z1) Dis Feh.K0(>Z1) 161 Messw.-Uberw.I 162 163 Storung I Storung Isymm 164 Messw.-Uberw.U 165 167 168 Storung Uphe Storung Usymm Storung Umess 620 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Functions, Settings, Information E.5 Measured Values Description Function Data Unit Position CFC Control Display Default Display IEC 60870-5-103 - 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 Type No. Compatibility Measured Values information number E.5 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix 621 No. Description Function Type information number Compatibility Data Unit Position CFC Control Display Default Display Functions, Settings, Information E.5 Measured Values IEC 60870-5-103 Configurable in Matrix 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 (Usy1Usy2) (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 (-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 622 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Description Function Compatibility Data Unit Position CFC Control Display Default Display IEC 60870-5-103 845 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 Min/Max meter (QdMin=) - - - - 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 Type No. information number Functions, Settings, Information E.5 Measured Values SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix 623 Description Function Compatibility Data Unit Position CFC Control Display Default Display IEC 60870-5-103 882 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 Min/Max meter (Qmin Forw=) - - - - CFC CD DD 1045 Reactive Power Maximum Forward Min/Max meter (Qmax Forw=) - - - - CFC CD DD 1046 Reactive Power Minimum Reverse Min/Max meter (Qmin Rev =) - - - - CFC CD DD 1047 Reactive Power Maximum Reverse Min/Max meter (Qmax Rev =) - - - - CFC CD DD Type No. information number Functions, Settings, Information E.5 Measured Values 624 Configurable in Matrix SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Description Function Compatibility Data Unit Position CFC Control Display Default Display IEC 60870-5-103 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 (IL1 =) Measure relay1 - - - - - CFC CD DD 14002 IL2 (primary) (IL2 =) Measure relay1 - - - - - CFC CD DD 14003 Angle IL2 (IL2 =) Measure relay1 - - - - - CFC CD DD 14004 IL3 (primary) (IL3 =) Measure relay1 - - - - - CFC CD DD 14005 Angle IL3 (IL3 =) Measure relay1 - - - - - CFC CD DD 14010 UL1E (primary) (UL1E =) Measure relay1 - - - - - CFC CD DD 14011 Angle UL1E (UL1E =) Measure relay1 - - - - - CFC CD DD Type No. information number Functions, Settings, Information E.5 Measured Values SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Configurable in Matrix 625 Description Function Compatibility Data Unit Position CFC Control Display Default Display IEC 60870-5-103 14012 UL2E (primary) (UL2E =) Measure relay1 - - - - - CFC CD DD 14013 Angle UL2E (UL2E =) Measure relay1 - - - - - CFC CD DD 14014 UL3E (primary) (UL3E =) Measure relay1 - - - - - CFC CD DD 14015 Angle UL3E (UL3E =) Measure relay1 - - - - - CFC CD DD 14020 IL1 (primary) (IL1 =) Measure relay2 - - - - - CFC CD DD 14021 Angle IL1 (IL1 =) Measure relay2 - - - - - CFC CD DD 14022 IL2 (primary) (IL2 =) Measure relay2 - - - - - CFC CD DD 14023 Angle IL2 (IL2 =) Measure relay2 - - - - - CFC CD DD 14024 IL3 (primary) (IL3 =) Measure relay2 - - - - - CFC CD DD 14025 Angle IL3 (IL3 =) Measure relay2 - - - - - CFC CD DD 14030 UL1E (primary) (UL1E =) Measure relay2 - - - - - CFC CD DD 14031 Angle UL1E (UL1E =) Measure relay2 - - - - - CFC CD DD 14032 UL2E (primary) (UL2E =) Measure relay2 - - - - - CFC CD DD 14033 Angle UL2E (UL2E =) Measure relay2 - - - - - CFC CD DD 14034 UL3E (primary) (UL3E =) Measure relay2 - - - - - CFC CD DD 14035 Angle UL3E (UL3E =) Measure relay2 - - - - - CFC CD DD 14040 IL1 (primary) (IL1 =) Measure relay3 - - - - - CFC CD DD 14041 Angle IL1 (IL1 =) Measure relay3 - - - - - CFC CD DD 14042 IL2 (primary) (IL2 =) Measure relay3 - - - - - CFC CD DD 14043 Angle IL2 (IL2 =) Measure relay3 - - - - - CFC CD DD 14044 IL3 (primary) (IL3 =) Measure relay3 - - - - - CFC CD DD 14045 Angle IL3 (IL3 =) Measure relay3 - - - - - CFC CD DD 14050 UL1E (primary) (UL1E =) Measure relay3 - - - - - CFC CD DD 14051 Angle UL1E (UL1E =) Measure relay3 - - - - - CFC CD DD 14052 UL2E (primary) (UL2E =) Measure relay3 - - - - - CFC CD DD 14053 Angle UL2E (UL2E =) Measure relay3 - - - - - CFC CD DD 14054 UL3E (primary) (UL3E =) Measure relay3 - - - - - CFC CD DD 14055 Angle UL3E (UL3E =) Measure relay3 - - - - - CFC CD DD Type No. information number Functions, Settings, Information E.5 Measured Values 626 Configurable in Matrix SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 627 628 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 629 Glossary 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 630 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Glossary 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 electrodes 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 631 Glossary 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 controllers. 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 satellite 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 information 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. 632 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Glossary 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 development stage to the manufacturing stage. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 633 Glossary 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 designation). 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 initialization 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 634 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Glossary 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 635 Glossary 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, visualizes 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. 636 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Glossary 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. SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 637 Glossary 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. 638 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Index Symbols (Fail Conductor) 302 Binary Outputs 342, 432 Blocking 152, 153 Blocking Scheme 130 Buffer battery 300 Busbar tripping 411 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 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 323 639 Index 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> 141 640 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Index Inverse Current IEC-Characteristics 447 Inverse Current Stage with logarithmic inverse Characteristics 448 Inverse Current Stage with mit ANSI-Characteristics 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 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 Protection 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) 641 Index 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 Prufungen 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 482 642 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 Characteristics) 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 Acceleration 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 Index 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 Schaltprufung der projektierten Operating Equipment 424 Series-compensated lines 63 Service / Modem Interface (optional) 433 Service Interface Test 395 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016 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 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 396 643 Index 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 477 644 V Vibration and Shock Resistance during Stationary Operation 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 SIPROTEC 4, 7SA522, Manual C53000-G1176-C155-9, Edition 05.2016