Preface Open Source Software Table of Contents SIPROTEC 4 Introduction Overcurrent Time Protection 7SJ80 Functions Mounting and Commissioning V4.7 Technical Data Ordering Information and Accessories Manual Terminal Assignments Connection Examples Current Transformer Requirements Default Settings and Protocol-dependent Functions Functions, Settings, Information Literature Glossary Index E50417-G1140-C343-A8 1 2 3 4 A B C D E F i NOTE For your own safety, observe the warnings and safety instructions contained in this document, if available. Disclaimer of Liability Copyright This document has been subjected to rigorous technical review before being published. It is revised at regular intervals, and any modifications and amendments are included in the subsequent issues. The content of this document has been compiled for information purposes only. Although Siemens AG has made best efforts to keep the document as precise and up-to-date as possible, Siemens AG shall not assume any liability for defects and damage which result through use of the information contained herein. This content does not form part of a contract or of business relations; nor does it change these. All obligations of Siemens AG are stated in the relevant contractual agreements. Siemens AG reserves the right to revise this document from time to time. Document version: E50417-G1140-C343-A8.00 Edition: 12.2017 Version of the product described: V4.7 Copyright (c) Siemens AG 2017. All rights reserved. The disclosure, duplication, distribution and editing of this document, or utilization and communication of the content are not permitted, unless authorized in writing. All rights, including rights created by patent grant or registration of a utility model or a design, are reserved. Registered Trademarks SIPROTEC(R), DIGSI(R), SIGUARD(R), SIMEAS(R), and SICAM(R) are registered trademarks of Siemens AG. Any unauthorized use is illegal. All other designations in this document can be trademarks whose use by third parties for their own purposes can infringe the rights of the owner. Preface Purpose of the Manual This manual describes the functions, operation, installation, and commissioning of devices 7SJ80. 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. 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. Scope This manual applies to: SIPROTEC 4 Overcurrent Time Protection 7SJ80; Firmware-Version V4.7. 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 Directive in agreement with the generic standards EN 61000-6-2 and EN 61000-6-4 for 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 standards of the series IEC 60255 and the German standard VDE 0435. Additional Standards IEEE Std C37.90 (see Chapter 4 "Technical Data") This product is UL-certified according to the Technical Data. file E194016 [ul-schutz-7sx80-100310, 1, --_--] SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 3 Preface Additional Support For questions about the system, please contact your Siemens sales partner. Support Our Customer Support Center provides a 24-hour service. Phone: Fax: E-Mail: +49 (180) 524-7000 +49 (180) 524-2471 support.energy@siemens.com Training Courses Inquiries regarding individual training courses should be addressed to our Training Center: Siemens AG Siemens Power Academy TD Humboldtstrae 59 90459 Nurnberg Germany Phone: Fax: E-Mail: Internet: +49 (911) 433-7415 +49 (911) 433-7929 poweracademy@siemens.com www.siemens.com/poweracademy 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 DANGER means that death or severe injury will result if the measures specified are not taken. ! Comply with all instructions, in order to avoid death or severe injuries. 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. 4 Comply with all instructions, in order to avoid moderate or minor injuries. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Preface NOTICE NOTICE means that property damage can result if the measures specified are not taken. i Comply with all instructions, in order to avoid property damage. NOTE Important information about the product, product handling or a certain section of the documentation which must be given particular attention. Qualified Electrical Engineering Personnel Only qualified electrical engineering personnel may commission and operate the equipment (module, device) described in this document. Qualified electrical engineering personnel in the sense of this manual are people who can demonstrate technical qualifications as electrical technicians. These persons may commission, isolate, ground and label devices, systems and circuits according to the standards of safety engineering. Proper Use The equipment (device, module) may be used only for such applications as set out in the catalogs and the technical description, and only in combination with third-party equipment recommended and approved by Siemens. Problem-free and safe operation of the product depends on the following: * Proper transport * * Proper storage, setup and installation Proper operation and maintenance When electrical equipment is operated, hazardous voltages are inevitably present in certain parts. If proper action is not taken, death, severe injury or property damage can result: * The equipment must be grounded at the grounding terminal before any connections are made. * * All circuit components connected to the power supply may be subject to dangerous voltage. * Operation of equipment with exposed current-transformer circuits is prohibited. Before disconnecting the equipment, ensure that the current-transformer circuits are short-circuited. * The limiting values stated in the document must not be exceeded. This must also be considered during testing and commissioning. Hazardous voltages may be present in equipment even after the supply voltage has been disconnected (capacitors can still be charged). 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. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 5 Preface 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 ON and OFF 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 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) 6 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Preface 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 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 7 8 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Open Source Software The product contains, among other things, Open Source Software developed by third parties. The Open Source Software used in the product and the license agreements concerning this software can be found in the Readme_OSS. These Open Source Software files are protected by copyright. Your compliance with those license conditions will entitle you to use the Open Source Software as foreseen in the relevant license. In the event of conflicts between Siemens license conditions and the Open Source Software license conditions, the Open Source Software conditions shall prevail with respect to the Open Source Software portions of the software. The Open Source Software is licensed royalty-free. Insofar as the applicable Open Source Software License Conditions provide for it you can order the source code of the Open Source Software from your Siemens sales contact - against payment of the shipping and handling charges - for a period of at least 3 years since purchase of the Product. We are liable for the Product including the Open Source Software contained in it pursuant to the license conditions applicable to the Product. Any liability for the Open Source Software beyond the program flow intended for the Product is explicitly excluded. Furthermore any liability for defects resulting from modifications to the Open Source Software by you or third parties is excluded. We do not provide any technical support for the Product if it has been modified. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 9 10 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Table of Contents Preface.......................................................................................................................................................... 3 Open Source Software..................................................................................................................................9 1 2 Introduction................................................................................................................................................19 1.1 Overall Operation..............................................................................................................20 1.2 Application Scope............................................................................................................. 22 1.3 Characteristics.................................................................................................................. 24 Functions.................................................................................................................................................... 29 2.1 General.............................................................................................................................30 2.1.1 2.1.1.1 2.1.1.2 2.1.1.3 Functional Scope......................................................................................................... 30 Functional Description........................................................................................... 30 Setting Notes......................................................................................................... 30 Settings................................................................................................................. 32 2.1.2 2.1.2.1 2.1.2.2 2.1.2.3 2.1.2.4 Device, General Settings.............................................................................................. 34 Functional Description........................................................................................... 34 Setting Notes......................................................................................................... 34 Settings................................................................................................................. 35 Information List..................................................................................................... 36 2.1.3 2.1.3.1 2.1.3.2 2.1.3.3 2.1.3.4 Power System Data 1................................................................................................... 37 Functional Description........................................................................................... 37 Setting Notes......................................................................................................... 38 Settings................................................................................................................. 43 Information List..................................................................................................... 46 2.1.4 2.1.4.1 2.1.4.2 2.1.4.3 2.1.4.4 Oscillographic Fault Records........................................................................................ 46 Functional Description........................................................................................... 47 Setting Notes......................................................................................................... 48 Settings................................................................................................................. 48 Information List..................................................................................................... 48 2.1.5 2.1.5.1 2.1.5.2 2.1.5.3 2.1.5.4 Settings Groups........................................................................................................... 49 Functional Description........................................................................................... 49 Setting Notes......................................................................................................... 49 Settings................................................................................................................. 49 Information List..................................................................................................... 49 2.1.6 2.1.6.1 2.1.6.2 2.1.6.3 2.1.6.4 Power System Data 2................................................................................................... 50 Functional Description........................................................................................... 50 Setting Notes......................................................................................................... 50 Settings................................................................................................................. 53 Information List..................................................................................................... 54 2.1.7 2.1.7.1 2.1.7.2 2.1.7.3 EN100-Module............................................................................................................ 55 Functional Description........................................................................................... 55 Setting Notes......................................................................................................... 55 Information List..................................................................................................... 55 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 11 Table of Contents 2.2 General ...................................................................................................................... 56 2.2.2 Definite Time, High-set Elements 50-3, 50-2, 50N-3, 50N-2..........................................57 2.2.3 Definite Time Overcurrent Elements 50-1, 50N-1......................................................... 59 2.2.4 Inverse Time Overcurrent Elements 51, 51N ................................................................62 2.2.5 Inverse Time Overcurrent Protection 51V (Voltage-controlled / Voltagerestraint)...........65 2.2.6 Dynamic Cold Load Pickup Function............................................................................. 67 2.2.7 Inrush Restraint .......................................................................................................... 68 2.2.8 Pickup Logic and Tripping Logic................................................................................... 69 2.2.9 Two-phase Overcurrent Protection (Only Non-Directional) ...........................................70 2.2.10 Fast Busbar Protection Using Reverse Interlocking ....................................................... 71 2.2.11 Setting Notes...............................................................................................................72 2.2.12 Settings.......................................................................................................................77 2.2.13 Information List........................................................................................................... 79 2.3 Directional Overcurrent Protection 67, 67N....................................................................... 82 2.3.1 General....................................................................................................................... 82 2.3.2 Definite Time Directional High-set Elements 67-2, 67N-2, 67-3, 67N-3......................... 84 2.3.3 Definite Time, Directional Time Overcurrent Elements 67-1, 67N-1...............................85 2.3.4 Inverse Time, Directional Overcurrent Elements 67-TOC, 67N-TOC............................... 88 2.3.5 Interaction with Fuse Failure Monitor (FFM).................................................................89 2.3.6 Dynamic Cold Load Pickup Function............................................................................. 90 2.3.7 Inrush Restraint........................................................................................................... 90 2.3.8 Determination of Direction.......................................................................................... 90 2.3.9 Reverse Interlocking for Double End Fed Lines..............................................................94 2.3.10 Setting Notes...............................................................................................................95 2.3.11 Settings.....................................................................................................................101 2.3.12 Information List......................................................................................................... 104 2.4 Dynamic Cold Load Pickup...............................................................................................106 2.4.1 Functional Description............................................................................................... 106 2.4.2 Setting Notes.............................................................................................................108 2.4.3 Settings.....................................................................................................................109 2.4.4 Information List......................................................................................................... 111 2.5 Single-Phase Overcurrent Protection................................................................................112 2.5.1 Functional Description............................................................................................... 112 2.5.2 High-impedance Ground Fault Unit Protection........................................................... 113 2.5.3 Tank Leakage Protection............................................................................................ 115 2.5.4 Setting Notes.............................................................................................................116 2.5.5 Settings.....................................................................................................................121 2.5.6 Information List......................................................................................................... 121 2.6 12 Overcurrent Protection 50, 51, 50N, 51N.......................................................................... 56 2.2.1 Voltage Protection 27, 59................................................................................................122 2.6.1 Measurement Principle.............................................................................................. 122 2.6.2 Overvoltage Protection 59......................................................................................... 123 2.6.3 Undervoltage Protection 27....................................................................................... 124 2.6.4 Setting Notes.............................................................................................................127 2.6.5 Settings.....................................................................................................................130 2.6.6 Information List......................................................................................................... 131 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Table of Contents 2.7 Negative Sequence Protection 46.................................................................................... 132 2.7.1 Definite Time characteristic .......................................................................................132 2.7.2 Inverse Time characteristic.........................................................................................132 2.7.3 Setting Notes.............................................................................................................135 2.7.4 Settings.....................................................................................................................136 2.7.5 Information List......................................................................................................... 137 2.8 Frequency Protection 81 O/U...........................................................................................138 2.8.1 Functional Description............................................................................................... 138 2.8.2 Setting Notes.............................................................................................................139 2.8.3 Settings.....................................................................................................................140 2.8.4 Information List......................................................................................................... 141 2.9 Undervoltage-controlled reactive power protection (27/Q)...............................................142 2.9.1 Functional Description............................................................................................... 142 2.9.2 Setting Notes.............................................................................................................144 2.9.3 Settings.....................................................................................................................145 2.9.4 Information List......................................................................................................... 146 2.10 Thermal Overload Protection 49...................................................................................... 147 2.10.1 Functional Description............................................................................................... 147 2.10.2 Setting Notes.............................................................................................................149 2.10.3 Settings.....................................................................................................................152 2.10.4 Information List......................................................................................................... 152 2.11 Monitoring Functions......................................................................................................154 2.11.1 2.11.1.1 2.11.1.2 2.11.1.3 2.11.1.4 2.11.1.5 2.11.1.6 2.11.1.7 2.11.1.8 2.11.1.9 Measurement Supervision......................................................................................... 154 General................................................................................................................154 Hardware Monitoring .......................................................................................... 154 Software Monitoring ........................................................................................... 156 Monitoring of the Transformer Circuits................................................................. 157 Measurement Voltage Failure Detection............................................................... 158 Broken Wire Monitoring of Voltage Transformer Circuits....................................... 162 Setting Notes....................................................................................................... 163 Settings............................................................................................................... 164 Information List................................................................................................... 165 2.11.2 2.11.2.1 2.11.2.2 2.11.2.3 2.11.2.4 Trip Circuit Supervision 74TC..................................................................................... 166 Functional Description......................................................................................... 166 Setting Notes....................................................................................................... 169 Settings............................................................................................................... 169 Information List................................................................................................... 170 2.11.3 2.11.3.1 Malfunction Responses of the Monitoring Functions.................................................. 170 Description.......................................................................................................... 170 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s).........................................................172 2.12.1 Ground Fault Detection for cos- / sin- Measurement (Standard Method)..................172 2.12.2 Ground Fault Detection for V0/I0- Measurement.......................................................178 2.12.3 2.12.3.1 2.12.3.2 2.12.3.3 Extended Ground Fault Protection EPTR/TNP.............................................................. 182 General Information.............................................................................................182 Ground-Fault Protection EPTR - B.......................................................................... 183 Transformer Neutral-Point Protection TNP.............................................................184 2.12.4 Ground Fault Location............................................................................................... 184 2.12.5 Setting Notes.............................................................................................................185 2.12.6 Settings.....................................................................................................................193 2.12.7 Settings EPTR, TNP.....................................................................................................195 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 13 Table of Contents 2.12.8 Information List......................................................................................................... 195 2.12.9 Information List EPTR, TNP......................................................................................... 196 2.13 2.13.1 Functional Description............................................................................................... 198 2.13.2 Setting Notes.............................................................................................................201 2.13.3 Settings.....................................................................................................................202 2.13.4 2.14 Information List......................................................................................................... 203 Dir. Intermittent earth fault protection............................................................................ 204 2.14.1 Functional Description............................................................................................... 204 2.14.2 Setting Notes.............................................................................................................207 2.14.3 Settings.....................................................................................................................208 2.14.4 Information List......................................................................................................... 208 2.15 Automatic Reclosing System 79.......................................................................................209 2.15.1 Program Execution.................................................................................................... 209 2.15.2 Blocking.................................................................................................................... 213 2.15.3 Status Recognition and Monitoring of the Circuit Breaker........................................... 215 2.15.4 Controlling Protection Elements.................................................................................216 2.15.5 Zone Sequencing / Fuse Saving Scheme..................................................................... 218 2.15.6 Setting Notes.............................................................................................................219 2.15.7 Settings.....................................................................................................................224 2.15.8 Information List......................................................................................................... 230 2.16 Fault Locator...................................................................................................................232 2.16.1 Functional Description............................................................................................... 232 2.16.2 Setting Notes.............................................................................................................233 2.16.3 Settings.....................................................................................................................234 2.16.4 Information List......................................................................................................... 234 2.17 Breaker Failure Protection 50BF....................................................................................... 235 2.17.1 Functional Description............................................................................................... 235 2.17.2 Setting Notes.............................................................................................................238 2.17.3 Settings.....................................................................................................................240 2.17.4 2.18 Information List......................................................................................................... 241 Flexible Protection Functions...........................................................................................242 2.18.1 Functional Description............................................................................................... 242 2.18.2 Setting Notes.............................................................................................................246 2.18.3 Settings.....................................................................................................................250 2.18.4 Information List......................................................................................................... 252 2.19 Reverse-Power Protection Application with Flexible Protection Function...........................253 2.19.1 Functional Description............................................................................................... 253 2.19.2 Implementation of the Reverse Power Protection....................................................... 256 2.19.3 Configuring the Reverse Power Protection in DIGSI.....................................................258 2.20 14 Intermittent Ground Fault Protection...............................................................................198 Synchrocheck................................................................................................................. 261 2.20.1 General..................................................................................................................... 261 2.20.2 Functional Sequence................................................................................................. 263 2.20.3 De-energized Switching............................................................................................. 264 2.20.4 Direct Command / Blocking........................................................................................ 265 2.20.5 Interaction with Control, Automatic Reclosing and External Control............................265 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Table of Contents 2.20.6 Setting Notes.............................................................................................................267 2.20.7 Settings.....................................................................................................................271 2.20.8 Information List......................................................................................................... 272 2.21 Phase Rotation................................................................................................................ 274 2.21.1 Functional Description............................................................................................... 274 2.21.2 Setting Notes.............................................................................................................274 2.22 Function Logic................................................................................................................ 275 2.22.1 Pickup Logic of the Entire Device................................................................................275 2.22.2 Tripping Logic of the Entire Device............................................................................. 275 2.22.3 2.23 Setting Notes.............................................................................................................276 Auxiliary Functions..........................................................................................................277 2.23.1 2.23.1.1 2.23.1.2 2.23.1.3 Message Processing...................................................................................................277 LED Displays and Binary Outputs (Output Relays).................................................. 277 Information on the Integrated Display (LCD) or Personal Computer....................... 277 Information to a Control Center............................................................................279 2.23.2 2.23.2.1 2.23.2.2 2.23.2.3 2.23.2.4 Statistics....................................................................................................................279 Functional Description......................................................................................... 279 Circuit Breaker Maintenance.................................................................................280 Setting Notes....................................................................................................... 286 Information List................................................................................................... 288 2.23.3 2.23.3.1 2.23.3.2 2.23.3.3 Measurement............................................................................................................ 288 Display of Measured Values.................................................................................. 289 Transfer of Measured Values................................................................................ 290 Information List................................................................................................... 291 2.23.4 2.23.4.1 2.23.4.2 2.23.4.3 2.23.4.4 Average Measurements............................................................................................. 292 Functional Description......................................................................................... 292 Setting Notes....................................................................................................... 292 Settings............................................................................................................... 293 Information List................................................................................................... 293 2.23.5 2.23.5.1 2.23.5.2 2.23.5.3 2.23.5.4 Min/Max Measurement Setup.................................................................................... 293 Functional Description......................................................................................... 293 Setting Notes....................................................................................................... 293 Settings............................................................................................................... 294 Information List................................................................................................... 294 2.23.6 2.23.6.1 Set Points for Measured Values.................................................................................. 295 Setting Notes....................................................................................................... 296 2.23.7 2.23.7.1 2.23.7.2 2.23.7.3 Set Points for Statistic................................................................................................ 296 Functional Description......................................................................................... 296 Setting Notes....................................................................................................... 296 Information List................................................................................................... 296 2.23.8 2.23.8.1 2.23.8.2 2.23.8.3 2.23.8.4 Energy Metering........................................................................................................296 Functional Description......................................................................................... 297 Setting Notes....................................................................................................... 297 Settings............................................................................................................... 297 Information List................................................................................................... 297 2.23.9 2.23.9.1 Commissioning Aids.................................................................................................. 297 Functional Description......................................................................................... 298 2.24 2.24.1 2.24.1.1 2.24.1.2 Breaker Control............................................................................................................... 299 Control Device........................................................................................................... 299 Functional Description......................................................................................... 299 Information List................................................................................................... 300 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 15 Table of Contents 2.24.2 2.24.2.1 Types of Commands.................................................................................................. 300 Functional Description......................................................................................... 300 2.24.3 2.24.3.1 Command Sequence..................................................................................................300 Functional Description......................................................................................... 301 2.24.4 2.24.4.1 Interlocking............................................................................................................... 301 Functional Description......................................................................................... 301 2.24.5 2.24.5.1 Command Logging.................................................................................................... 308 Functional Description......................................................................................... 308 2.25 2.25.1 3 Mounting and Connections............................................................................................. 312 3.1.1 Configuration Information......................................................................................... 312 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.............................................................................................315 Disassembly......................................................................................................... 315 Connections of the Current Terminals...................................................................318 Connections of the Voltage Terminals...................................................................319 Interface Modules................................................................................................ 320 Reassembly.......................................................................................................... 322 3.1.3 3.1.3.1 3.1.3.2 3.1.3.3 3.1.3.4 Installation................................................................................................................ 323 General................................................................................................................323 Panel Flush Mounting...........................................................................................324 Cubicle Mounting.................................................................................................325 Panel Surface Mounting....................................................................................... 326 3.2 Checking Connections.....................................................................................................328 3.2.1 Checking the Data Connections of the Interfaces........................................................328 3.2.2 Checking the System Connections............................................................................. 330 3.3 Commissioning............................................................................................................... 332 3.3.1 Test Mode and Transmission Block............................................................................. 333 3.3.2 Testing the System Interface (at Port B) .....................................................................333 3.3.3 Configuring Communication Modules........................................................................ 334 3.3.4 Checking the Status of Binary Inputs and Outputs...................................................... 338 3.3.5 Tests for Breaker Failure Protection............................................................................ 340 3.3.6 Testing User-Defined Functions..................................................................................342 3.3.7 Current, Voltage, and Phase Rotation Testing............................................................. 342 3.3.8 Test for High Impedance Protection........................................................................... 343 3.3.9 Testing the Reverse Interlocking Scheme....................................................................343 3.3.10 Direction Check with Load Current............................................................................. 344 3.3.11 Polarity Check for Voltage Input V3.............................................................................345 3.3.12 Ground Fault Check................................................................................................... 347 3.3.13 Polarity Check for Current Input E.............................................................................. 347 3.3.14 Trip/Close Tests for the Configured Operating Devices................................................ 350 3.3.15 Creating Oscillographic Recordings for Tests.............................................................. 350 3.4 Final Preparation of the Device........................................................................................ 352 Technical Data.......................................................................................................................................... 353 4.1 16 Different operation.................................................................................................... 309 Mounting and Commissioning................................................................................................................. 311 3.1 4 Notes on Device Operation..............................................................................................309 General Device Data........................................................................................................354 4.1.1 Analog Inputs............................................................................................................ 354 4.1.2 Auxiliary voltage........................................................................................................354 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Table of Contents A B 4.1.3 Binary Inputs and Outputs......................................................................................... 355 4.1.4 Communication Interfaces......................................................................................... 356 4.1.5 Electrical Tests...........................................................................................................358 4.1.6 Mechanical Tests....................................................................................................... 360 4.1.7 Climatic Stress Tests.................................................................................................. 360 4.1.8 Service Conditions..................................................................................................... 361 4.1.9 Constructive Design...................................................................................................361 4.1.10 UL certification conditions......................................................................................... 362 4.2 Definite-time Overcurrent Protection............................................................................... 363 4.3 Inverse-time Overcurrent Protection................................................................................ 365 4.4 Directional Overcurrent Protection.................................................................................. 376 4.5 Inrush Restraint...............................................................................................................378 4.6 Dynamic Cold Load Pickup...............................................................................................379 4.7 1-phase Overcurrent Protection.......................................................................................380 4.8 Voltage Protection.......................................................................................................... 381 4.9 Negative Sequence Protection (definite-time characteristic).............................................383 4.10 Negative Sequence Protection (inverse-time characteristics)............................................ 384 4.11 Frequency Protection 81 O/U...........................................................................................390 4.12 Undervoltage-controlled reactive power protection (27/Q)...............................................391 4.13 Thermal Overload Protection........................................................................................... 393 4.14 Ground Fault Detection (Sensitive/Insensitive)................................................................. 395 4.15 Intermittent Ground Fault Protection...............................................................................401 4.16 Directional intermittent ground fault protection.............................................................. 402 4.17 Automatic Reclosing....................................................................................................... 403 4.18 Fault Locator...................................................................................................................404 4.19 Breaker Failure Protection 50BF ...................................................................................... 405 4.20 Flexible Protection Functions ..........................................................................................406 4.21 Synchrocheck 25 ............................................................................................................409 4.22 User-defined Functions (CFC).......................................................................................... 411 4.23 Auxiliary Functions..........................................................................................................416 4.24 Switching Device Control................................................................................................ 421 4.25 Dimensions.....................................................................................................................422 4.25.1 Panel Flush and Cubicle Mounting (Housing Size 1/6) ................................................ 422 4.25.2 Panel Surface Mounting (Housing Size 1/6) ............................................................... 423 4.25.3 Bottom view.............................................................................................................. 423 4.25.4 Varistor..................................................................................................................... 424 Ordering Information and Accessories.....................................................................................................425 A.1 Ordering Information 7SJ80 ........................................................................................... 426 A.2 Accessories..................................................................................................................... 431 Terminal Assignments.............................................................................................................................. 433 B.1 C 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting ...........................................................................................................434 Connection Examples............................................................................................................................... 441 C.1 Connection Examples for Current and Voltage Transformers............................................ 442 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 17 Table of Contents C.2 D E F Connection Examples for SICAM I/O Units........................................................................ 454 Current Transformer Requirements......................................................................................................... 455 D.1 Accuracy limiting factors................................................................................................. 456 D.2 Class conversion............................................................................................................. 457 D.3 Cable core balance current transformer........................................................................... 458 Default Settings and Protocol-dependent Functions............................................................................... 459 E.1 LEDs............................................................................................................................... 460 E.2 Binary Input.................................................................................................................... 462 E.3 Binary Output................................................................................................................. 463 E.4 Function Keys................................................................................................................. 464 E.5 Default Display................................................................................................................465 E.6 Protocol-dependent Functions.........................................................................................468 Functions, Settings, Information..............................................................................................................469 F.1 Functional Scope............................................................................................................ 470 F.2 Settings.......................................................................................................................... 472 F.3 Information List.............................................................................................................. 501 F.4 Group Alarms..................................................................................................................539 F.5 Measured Values.............................................................................................................541 Literature.................................................................................................................................................. 547 Glossary.................................................................................................................................................... 549 Index.........................................................................................................................................................559 18 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 1 Introduction The device family SIPROTEC 7SJ80 devices is introduced in this section. An overview of the devices is presented in their application, characteristics, and scope of functions. 1.1 Overall Operation 20 1.2 Application Scope 22 1.3 Characteristics 24 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 19 Introduction 1.1 Overall Operation 1.1 Overall Operation The digital SIPROTEC 7SJ80 overcurrent protection is equipped with a powerful microprocessor. It allows all tasks to be processed digitally, from the acquisition of measured quantities to sending commands to circuit breakers. Figure 1-1 shows the basic structure of the 7SJ80. Analog Inputs The measuring inputs (MI) convert the currents and voltages coming from the measuring transformers and adapt them to the level appropriate for the internal processing of the device. The device provides 4 current transformers and - depending on the model - additionally 3 voltage transformers. Three current inputs serve for the input of the phase currents, another current input (N) may be used for measuring the ground fault current N (current transformer neutral point) or for a separate ground current transformer (for sensitive ground fault detection Ns and directional determination of ground faults ) - depending on the model. [hw-struktur-7sj80-060606, 1, en_US] Figure 1-1 Hardware structure of the digital multi-functional protective relay 7SJ80 The optional voltage transformers can either be used to input 3 phase-to-ground voltages or 2 phase-to-phase voltages and the displacement voltage (open delta voltage) or any other voltages. It is also possible to connect two phase-to-phase voltages in open delta connection. The analog input quantities are passed on to the input amplifiers (IA). The input amplifier IA element provides a high-resistance termination for the input quantities. It consists of filters that are optimized for measuredvalue processing with regard to bandwidth and processing speed. The analog-to-digital (AD) transformer group consists of an analog-to-digital converter and memory components for the transmission of data to the microcomputer. 20 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Introduction 1.1 Overall Operation Microcomputer System Apart from processing the measured values, the microcomputer system (C) also executes the actual protection and control functions. They especially include: * Filtering and preparation of the measured quantities * * * * * * * * Continuous monitoring of the measured quantities Monitoring of the pickup conditions for the individual protective functions Interrogation of limit values and sequences in time Control of signals for the logic functions Output of control commands for switching devices Recording of messages, fault data and fault values for analysis Management of the operating system and the associated functions such as data recording, real-time clock, communication, interfaces, etc. The information is distributed via output amplifiers (OA). Binary Inputs and Outputs The computer system obtains external information through the binary input/output boards (inputs and outputs). The computer system obtains information from the system (e.g remote resetting) or from external equipment (e.g. blocking commands). These outputs include, in particular, trip commands to circuit breakers and signals for the remote indication of important events and conditions. Front Panel Information such as messages related to events, states, measured values and the functional status of the device are visualized by light-emitting diodes (LEDs) and a display screen (LCD) on the front panel. Integrated control and numeric keys in conjunction with the LCD enable interaction with the remote device. These elements can be used to access the device for information such as configuration and setting parameters. Similarly, setting parameters can be accessed and changed if needed. In addition, control of circuit breakers and other equipment is possible from the front panel of the device. Interfaces Communication with a PC can be implemented via the USB DIGSI interface using the DIGSI software, allowing all device functions to be easily executed. Communication with a PC is also possible via port A (Ethernet interface) and port B (System/Service interface) using DIGSI. In addition to the device communication via DIGSI, port B can also be used to transmit all device data to a central evaluator or a control center. This interface may be provided with various protocols and physical transmission schemes to suit the particular application. Power Supply A power supply unit (Vaux or PS) delivers power to the functional units using the different voltage levels. Voltage dips may occur if the voltage supply system (substation battery) becomes short-circuited. Usually, they are bridged by a capacitor (see also Technical Data). A buffer battery is located under the flap at the lower end of the front cover. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 21 Introduction 1.2 Application Scope 1.2 Application Scope The multi-function numerical overcurrent protection SIPROTEC 4 7SJ80 is used as protection, control and monitoring unit for busbar feeders. For line protection, the device can be used in networks with grounded, lowresistance grounded, isolated or a compensated neutral point structure. It is suited for networks that are radial and supplied from a single source, open or closed looped networks and for lines with sources at both ends. The device includes the functions that are usually necessary for protection, monitoring of circuit breaker positions and control of circuit breakers in single and double busbars; therefore, the device can be employed universally. The device provides excellent backup protection of differential protective schemes of any kind for lines, transformers and busbars of all voltage levels. Protective Functions Non-directional overcurrent protection (50, 50N, 51, 51N) is the basic function of the device. There are three definite time elements and one inverse time element for the phase currents and the ground current. For the inverse time elements, several characteristics of different standards are provided. Alternatively, a user-defined characteristic can be used for the sensitive ground fault detection. Further protection functions included are the negative sequence protection, overload protection, circuit breaker failure protection and ground fault protection. Depending on the ordered variant, further protection functions are included, such as frequency protection, overvoltage and undervoltage protection, and ground fault protection for high-resistance ground faults (directional or non-directional). Apart from the short circuit protection functions mentioned before, there are further protection functions possible as order variants. The overcurrent protection can, for example, be supplemented by a directional overcurrent protection. The automatic reclosing function enables several different reclosing cycles for overhead lines. An external automatic reclosing system can also be connected. To ensure quick detection of the fault location after a short circuit, the device is equipped with a fault locator. Before reclosing after a three-pole tripping, the device can verify the validity of the reclosure via a voltage check and/or a synchrocheck. The synchrocheck function can also be controlled externally. Control Functions The device provides a control function which can be accomplished for activating and deactivating the switchgear via operator buttons, port B, binary inputs and - using a PC and the DIGSI software - via the front interface. 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 alarm condition monitoring. The number of operating equipments 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 indications. Depending on the primary equipment being controlled, one binary input (single point indication) or two binary inputs (double point indication) may be used for this process. The capability of switching primary equipment can be restricted by a setting associated with switching authority (Remote or Local), and by the operating mode (interlocked/non-interlocked, with or without password request). Processing of interlocking conditions for switching (e.g. switchgear interlocking) can be established with the aid of integrated, user-configurable logic functions. Messages and Measured Values; Recording of Event and Fault Data 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 cover (allocatable), can be externally processed via output contacts (allocatable), linked with user-definable logic functions and/or issued via serial interfaces. 22 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Introduction 1.2 Application Scope During a fault (system fault) important events and changes in conditions are saved in fault protocols (Event Log or Trip Log). Instantaneous fault values are also saved in the device and may be analyzed subsequently. Communication The following interfaces are available for communication with external operating, control and memory systems. The USB DIGSI interface on the front cover serves for local communication with a PC. 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 user-specific logic functions, retrieving operational messages and measured values, inquiring device conditions and measured values, issuing control commands. Depending on the ordered variant, additional interfaces are located at the bottom of the device. They serve for establishing extensive communication with other digital operating, control and memory components: Port A serves for DIGSI communication directly on the device or via network. Furthermore, 2 SICAM I/O units 7XV5673 can be connected to this port. Port A can also be used for time synchronization using the NTP protocol. Port B serves for central communication between the device and a control center. It can be operated via data lines or fiber optic cables. For the data transfer, there are standard protocols in accordance with IEC 60870-5103 available. The integration of the devices into the SINAUT LSA and SICAM automation systems can also be implemented with this profile. Alternatively, additional connection options are available with PROFIBUS DP and the DNP3.0 and MODBUS protocols. If an EN100 module is available, you can use the protocols IEC61850, PROFINET or DNP3 TCP. Furthermore, connecting a SICAM I/O unit is possible via IEC651850 GOOSE. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 23 Introduction 1.3 Characteristics 1.3 Characteristics General Characteristics * * Powerful 32-bit microprocessor system Complete digital processing and control of measured values, from the sampling of the analog input quantities to the initiation of outputs, for example, tripping or closing circuit breakers or other switchgear devices * Total electrical separation between the internal processing stages of the device and the external transformer, control, and DC supply circuits of the system because of the design of the binary inputs, outputs, and the DC or AC converters * * Complete set of functions necessary for the proper protection of lines, feeders, motors, and busbars * * * Continuous calculation and display of measured and metered values on the front of the device * Constant monitoring of the measured quantities, as well as continuous self-diagnostics covering the hardware and software * Communication with SCADA or substation controller equipment via serial interfaces through the choice of data cable, modem, or optical fibers * Battery-buffered clock which can be synchronized via a synchronization signal at the binary input or via a protocol * Switching statistics: Counting the number of trip commands initiated by the device, logging the currents of the last switch-off operation initiated by the device, and accumulating the eliminated short-circuit currents of each breaker pole * * Operating hours counter: Counting the operating hours of the protected object under load Easy device operation through an integrated operator panel or by means of a connected personal computer running DIGSI Storage of min./max. measured values (slave pointer function) and storage of long-term mean values Recording of event and fault data for the last 8 system faults (fault in a network) with real-time information as well as instantaneous values for fault recording for a maximum time range of 20 s Commissioning aids such as connection and direction check, status indication of all binary inputs and outputs, easy testing of port B, and influencing of information at port B during test operation. Time Overcurrent Protection 50, 51, 50N, 51N * Three definite time overcurrent protective elements and one inverse time overcurrent protective element for phase current and ground current N or summation current 30 * * Two-phase operation of the overcurrent protection (A, C) is possible * * * Blocking is possible, e.g. for reverse interlocking with any element For inverse-time overcurrent protection, selection from various characteristics of different standards possible Instantaneous tripping by any element is possible when switching onto a fault In-rush restraint with second harmonic current quantities. Ground Fault Protection 50N, 51N 24 * Three definite time overcurrent protective elements and one inverse time overcurrent protective element applicable for grounded or high-resistance grounded systems * For inverse-time overcurrent protection, selection from various characteristics of different standards SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Introduction 1.3 Characteristics * * In-rush restraint with second harmonic current quantities Instantaneous tripping by any overcurrent element upon switch onto fault is possible. Directional Time Overcurrent Protection 67, 67N * Three definite time overcurrent protection elements and one inverse time overcurrent protection element for the phase operate in parallel to the non-directional overcurrent elements. Their pickup values and time delays can be set independently of these. * Direction determination with cross-polarized voltages and voltage memory and dynamically unlimited direction sensitivity * Fault direction is calculated phase-selectively and separately for phase faults, ground faults and summation current faults. Dynamic Cold Load Pick-up Function 50C, 50NC, 51C, 51NC, 67C, 67NC * Dynamic changeover of time overcurrent protection settings, e.g. when cold load conditions are recognized * * * Detection of cold load condition via circuit breaker position or current threshold Activation via automatic reclosure (AR) is possible Activation also possible via binary input. Single-Phase Overcurrent Protection * * Evaluation of the measured current via the sensitive or insensitive ground current transformer * As tank leakage protection against abnormal leakage currents between transformer tanks and ground. Suitable as differential protection that includes the neutral point current on transformer side, generator side or motor side or for a grounded reactor set Voltage Protection 27, 59 * Two element undervoltage detection via the positive-sequence system of the voltages, phase-to-phase or phase-to-ground voltages * * Choice of current supervision for 27-1 and 27-2 * Settable dropout ratio for all elements of the undervoltage and overvoltage protection. Separate two-element overvoltage detection of the largest voltages applied or detection of the positive or negative sequence component of the voltages Negative Sequence Protection 46 * * Evaluation of the negative sequence component of the currents Two definite-time elements 46-1 and 46-2 and one inverse-time element 46-TOC; curves of common standards are available for 46-TOC. Frequency Protection 81 O/U * Monitoring of falling below (f<) and/or exceeding (f>) with 4 frequency limits and time delays that are independently adjustable * * Insensitive to harmonics and abrupt phase angle changes Adjustable undervoltage threshold. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 25 Introduction 1.3 Characteristics Undervoltage-controlled reactive power protection (27/Q) * * * Detection of critical power system situations Disconnection of power supply facilities from the grid Reconnection under stable power system conditions Thermal Overload Protection 49 * * * * Thermal profile of energy losses (overload protection has full memory capability) True r.m.s. calculation Adjustable thermal warning element Adjustable alarm level based on current magnitude Monitoring Functions * Increased reliability due to monitoring of the internal measurement circuits as well as the hardware and software * * Fuse failure monitor with protection function blocking * * Trip circuit monitoring possible Monitoring of the current transformer and voltage transformer secondary circuits using sum and symmetry supervision with optional protection function blocking Phase rotation check. Ground Fault Detection 50N(s), 51N(s), 67N(s), 59N/64 * * * * * * * Displacement voltage is measured or calculated from the three phase voltages * Any element can be set as directional or non-directional -- forward sensing directional, or reverse sensing directional * Optionally applicable as additional ground fault protection. Determination of a faulty phase on ungrounded or grounded systems Two-element Ground Fault Detection: 50Ns-1 and 50Ns-2 High sensitivity (as low as 1 mA) Overcurrent element with definite time or inverse time delay For inverse-time overcurrent protection, a user-defined characteristic is available Direction determination with zero sequence quantities(0, V0), wattmetric ground fault direction determination Intermittent Ground Fault Protection * * Detects and accumulates intermittent ground faults Tripping after configurable total time. Directional intermittent ground fault protection * * * 26 Detects intermittent ground faults Direction determination Tripping after settable number of intermittent re-ignitions SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Introduction 1.3 Characteristics Automatic Reclosing 79 * * * Single-shot or multi-shot * * Separate programs for phase and ground faults * Synchronous reconnection is possible . With separate dead times for the first and all succeeding shots Protective elements that initiate automatic reclosing are selectable. The choices can be different for phase faults and ground faults Interaction to time overcurrent protection element and ground fault elements. They can be blocked in dependence of the reclosing cycle or released instantaneously Fault Location * * * Initiation by trip command, external command or dropout of pickup Calculation of the fault distance and output of the fault location in ohms (primary and secondary) and in kilometers or miles Up to three line sections can be configured. Breaker Failure Protection 50 BF * * * By checking the current and/or evaluating the circuit breaker auxiliary contacts Started by any integrated protection function that trips Initiation possible via a binary input from an external protective device. Flexible Protective Functions * * * * * Up to 20 customizable protection functions with three-phase or single-phase operation Any calculated or directly measured quantity can be evaluated on principle Standard protection logic with definite time characteristic Internal and configurable pickup and dropout delay Modifiable message texts. Synchrocheck * * Verification of the synchronous conditions before reclosing after three-pole tripping Fast measurement of the voltage difference V, the phase angle difference and the frequency difference f * * * Alternatively, check of the de-energized state before reclosing * * Measurement also possible via transformer without external intermediate matching transformer Setable minimum and maximum voltage Verification of the synchronous conditions or de-energized state also possible before the manual closing of the circuit breaker, with separate limit values Measuring voltages optionally phase-to-phase or phase-to-ground. Phase Rotation * Selectable ABC or ACB by setting (static) or binary input (dynamic). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 27 Introduction 1.3 Characteristics Circuit-Breaker Maintenance * * Statistical methods to help adjust maintenance intervals for CB contacts according to their actual wear * Acquisition and conditioning of measured values for all subfunctions operates phase-selective using one procedure-specific threshold per subfunction. several independent subfunctions have been implemented(-procedure, x-procedure, 2P-procedure and 2t-procedure) User Defined Functions * Freely programmable linking of internal and external signals in order to implement user-defined logic functions * * * All standard logic functions (AND, OR, NOT, EXCLUSIVE-OR, etc.) Time delays and limit value interrogations Processing of measured values, including zero suppression, adding a knee curve for a transducer input, and live-zero monitoring. Breaker Control 28 * Switching devices can be opened and closed manually using control keys, programmable function keys, via port B (e.g. of SICAM or LSA), or via the user interface (using a personal computer and the DIGSI operating software) * * Feedback of switching states via the switch auxiliary contacts Plausibility monitoring of the circuit breaker position and check of interlocking conditions. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 2 Functions This chapter describes the numerous functions available on the SIPROTEC 4 device 7SJ80. It shows the setting possibilities for each function in maximum configuration. Information with regard to the determination of setting values as well as formulas, if required, are also provided. Based on the following information, it can also be determined which of the provided functions should be used. 2.1 General 30 2.2 Overcurrent Protection 50, 51, 50N, 51N 56 2.3 Directional Overcurrent Protection 67, 67N 82 2.4 Dynamic Cold Load Pickup 106 2.5 Single-Phase Overcurrent Protection 112 2.6 Voltage Protection 27, 59 122 2.7 Negative Sequence Protection 46 132 2.8 Frequency Protection 81 O/U 138 2.9 Undervoltage-controlled reactive power protection (27/Q) 142 2.10 Thermal Overload Protection 49 147 2.11 Monitoring Functions 154 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) 172 2.13 Intermittent Ground Fault Protection 198 2.14 Dir. Intermittent earth fault protection 204 2.15 Automatic Reclosing System 79 209 2.16 Fault Locator 232 2.17 Breaker Failure Protection 50BF 235 2.18 Flexible Protection Functions 242 2.19 Reverse-Power Protection Application with Flexible Protection Function 253 2.20 Synchrocheck 261 2.21 Phase Rotation 274 2.22 Function Logic 275 2.23 Auxiliary Functions 277 2.24 Breaker Control 299 2.25 Notes on Device Operation 309 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 29 Functions 2.1 General 2.1 General The settings associated with the various device functions can be modified using the operating or service interface in DIGSI in conjunction with a personal computer. Some parameters can also be changed using the controls on the front panel of the device. The procedure is described in detail in the SIPROTEC System Description /1/ SIPROTEC 4 System Description. 2.1.1 Functional Scope The 7SJ80 relay contains protection functions as well as auxiliary functions. The hardware and firmware is designed for this scope of functions. Additionally, the control functions can be matched to the system requirements. Individual functions can be enabled or disabled during the configuration procedure. The interaction of functions may also be modified. 2.1.1.1 Functional Description Setting the Functional Scope Example for the configuration of the functional scope: A protected system consists of overhead lines and underground cables. Since automatic reclosing is only needed for the overhead lines, the automatic reclosing function is not configured or "disabled" for the relays protecting the underground cables. The available protection and additional functions can be configured as Enabled or Disabled. For individual functions, a choice between several alternatives may be possible, as described below. Functions configured as Disabled are not processed by the 7SJ80. There are no messages and corresponding settings (functions, limit values) queried during configuration. i 2.1.1.2 NOTE Available functions and default settings are depending on the order variant of the relay (see A Ordering Information and Accessories). Setting Notes Setting the Functional Scope Your protection device is configured using the DIGSI software. Connect your personal computer either to the USB port on the device front or to port A or port B on the bottom side of the device depending on the device version (ordering code). The operation via DIGSI is explained in the SIPROTEC 4 System Description. The Device Configuration dialog box allows you to adjust your device to the specific system conditions. Password no. 7 is required (for parameter set) for changing configuration parameters in the device. Without the password the settings can only be read but not edited and transmitted to the device. Special Features Most settings are self-explanatory. The special cases are described in the following. If you want to use the setting group change function, set address 103 Grp Chge OPTION to Enabled. In this case, you can select up to four different groups of function parameters between which you can switch quickly and conveniently during operation. Only one setting group can be used when selecting the option Disabled. For the elements associated with non-directional overcurrent protection 50(N), 51(N) (phase and ground), various tripping characteristics can be selected at addresses 112 Charac. Phase and 113 Charac. Ground. If only the definite time characteristic is desired, select Definite Time. Alternatively, you can select between inverse-time curves according to IEC standard (TOC IEC) or ANSI standard (TOC ANSI). The dropout behavior of the IEC and ANSI curves is specified at address 1210 or 1310 when configuring the time overcurrent protection. 30 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Set to Disabled to disable the entire time overcurrent protection. The directional overcurrent protection 67(N) is set at address 115 67/67-TOC and 116 67N/67N-TOC. Here, the same options are available as for non-directional overcurrent protection (except the 50-3 element). For (sensitive) ground fault detection address 130 S.Gnd.F.Dir.Ch lets you specify the directional characteristic of the sensitive ground fault detection. You can select between cos / sin and V0/I0 mea. as the measurement procedure. The cos / sin procedure (via residual wattmetric current detection) is set by default. If the measuring method cos / sin is set, select between a definite time characteristic (Definite Time) and an inverse time characteristic User Defined PU at address 131 Sens. Gnd Fault. V0/I0 mea. provides the definite time characteristic Definite Time, inverse time characteristics TOC IEC or TOC ANSI. When selecting the setting Disabled, the entire function is disabled. For the intermittent ground fault protection, you can specify the measured quantity (with Ignd, with 3I0 or with Ignd,sens.) to be used by this protection function at address 133 INTERM.EF. At address 134 Dir. Interm. EF you can set the directional intermittent ground fault protection to Enabled or Disabled. For unbalanced load protection, address 140 46 allows you to specify which tripping characteristics to use. You can select between Definite Time, TOC ANSI or TOC IEC. If this function is not required, select Disabled. The overload protection is activated in address 142 49 by selecting the setting without ambient temperature No ambient temp or it is set to Disabled. At address 155 27/Q-Protection you can set the QU protection to Enabled or Disabled. The synchronization function is activated in address 161 25 Function 1 by the setting SYNCHROCHECK or it is set to Disabled. In address 170 you can set the breaker failure protection to Enabled or Disabled. The setting option enabled w/ 3I0> subjects the ground current and the negative sequence current to a plausibility check. For the CB maintenance functions, several options are available under address 172 52 B.WEAR MONIT. Irrespective of this, the basic functionality of the summation current formation ( procedure) is always active. It requires no further configurations and adds up the tripping currents of the trips initiated by the protection functions. When selecting the Ix-Procedure, the sum of all tripping current powers is formed and output as reference value. The 2P Procedure continuously calculates the remaining lifespan of the circuit breaker. With the 2t Procedure the square fault current integrals are formed via arc time and output as a reference value. Further information concerning the individual procedures of the CB maintenance are given in Section2.23.2 Statistics. You can also disable this function by setting it to Disabled. In address 181, you can enter how many line sections (maximum of three) are taken into account by the fault locator. Under address 182 74 Trip Ct Supv it can be selected whether the trip-circuit supervision works with two (2 Binary Inputs) or only one binary input (1 Binary Input), or whether the function is configured Disabled. In address 617 ServiProt (CM) you can specify for which purpose port B is used. T103 means that the device is connected to a control and protection facility via serial port, DIGSI means that you are using the port to connect DIGSI or you are not using port B (Disabled). The flexible protection functions can be configured via parameter FLEXIBLE FUNC.. You can create up to 20 flexible functions by setting a checkmark in front of the desired function (an example is given in the Section 2.19 Reverse-Power Protection Application with Flexible Protection Function). If the checkmark of a function is removed, all settings and configurations made previously will be lost. After re-selecting the function, all settings and configurations are in default setting. Setting of the flexible function is done in DIGSI under "Parameters", "Additional Functions" and "Settings". The configuration is done, as usual, under "Parameters" and "Masking I/O (Configuration Matrix)". SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 31 Functions 2.1 General 2.1.1.3 Settings Addr. Parameter Setting Options Default Setting Comments 103 Grp Chge OPTION Disabled Enabled Disabled Setting Group Change Option 104 OSC. FAULT REC. Disabled Enabled Enabled Oscillographic Fault Records 112 Charac. Phase Disabled Definite Time TOC IEC TOC ANSI Definite Time 50/51 113 Charac. Ground Disabled Definite Time TOC IEC TOC ANSI Definite Time 50N/51N 115 67/67-TOC Disabled Definite Time TOC IEC TOC ANSI Definite Time 67, 67-TOC 116 67N/67N-TOC Disabled Definite Time TOC IEC TOC ANSI Definite Time 67N, 67N-TOC 117 Coldload Pickup Disabled Enabled Disabled Cold Load Pickup 122 InrushRestraint Disabled Enabled Disabled 2nd Harmonic Inrush Restraint 127 50 1Ph Disabled Enabled Disabled 50 1Ph 130 S.Gnd.F.Dir.Ch cos / sin V0/I0 mea. cos / sin (sens.) Ground fault dir. characteristic 131 Sens. Gnd Fault Disabled Definite Time User Defined PU Disabled (sensitive) Ground fault 133 INTERM.EF Disabled with Ignd with 3I0 with Ignd,sens. Disabled Intermittent earth fault protection 134 Dir. Interm. EF Disabled Enabled Disabled Dir. Intermittent earth fault protection 135 E Flt(ext) Disabled EPTR Trans. Neutral Disabled Earth Fault(extend) 140 46 Disabled TOC ANSI TOC IEC Definite Time Disabled 46 Negative Sequence Protection 142 49 Disabled No ambient temp No ambient temp 49 Thermal Overload Protection 32 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Addr. Parameter Setting Options Default Setting Comments 150 27/59 Disabled Enabled Disabled 27, 59 Under/Overvoltage Protection 154 81 O/U Disabled Enabled Disabled 81 Over/Underfrequency Protection 155 27/Q-Protection Disabled Enabled Disabled 27 / Q dir. con. Protection 161 25 Function 1 Disabled SYNCHROCHECK Disabled 25 Function group 1 170 50BF Disabled Enabled enabled w/ 3I0> Disabled 50BF Breaker Failure Protection 171 79 Auto Recl. Disabled Enabled Disabled 79 Auto-Reclose Function 172 52 B.WEAR MONIT Disabled Ix-Method 2P-Method I2t-Method Disabled 52 Breaker Wear Monitoring 180 Fault Locator Disabled Enabled Disabled Fault Locator 181 L-sections FL 1 Section 2 Sections 3 Sections 1 Section Line sections for fault locator 182 74 Trip Ct Supv Disabled 2 Binary Inputs 1 Binary Input Disabled 74TC Trip Circuit Supervision 617 ServiProt (CM) Disabled T103 DIGSI T103 Port B usage - FLEXIBLE FCT. 1...20 Flexible Function 01 Flexible Function 02 Flexible Function 03 Flexible Function 04 Flexible Function 05 Flexible Function 06 Flexible Function 07 Flexible Function 08 Flexible Function 09 Flexible Function 10 Flexible Function 11 Flexible Function 12 Flexible Function 13 Flexible Function 14 Flexible Function 15 Flexible Function 16 Flexible Function 17 Flexible Function 18 Flexible Function 19 Flexible Function 20 Please select Flexible Functions 1...20 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 33 Functions 2.1 General 2.1.2 Device, General Settings The device requires some general information. This may be, for example, the type of annunciation to be issued in the event of an occurrence of a power system fault. 2.1.2.1 Functional Description Command-Dependent Messages "No Trip - No Flag" The storage of indications assigned to local LEDs and the availability of spontaneous indications can be made dependent on whether the device has issued a trip command. This information is then not issued if during a system disturbance one or more protection functions have picked up but the 7SJ80 did not trip because the fault was cleared by another device (e.g. on another line). These messages are then limited to faults in the line to be protected. The following figure illustrates the generation of the reset command for stored indications. The instant the device drops out, the presetting of parameter 610 FltDisp.LED/LCD decides whether the new fault remains stored or is reset. [ruecksetzbefehl-fuer-n-speicher-led-lcd-meld-260602-kn, 1, en_US] Figure 2-1 Creation of the reset command for the latched LED and LCD messages Spontaneous Messages on the Display You can determine whether or not the most important data of a fault event is displayed automatically after the fault has occurred (see also Subsection "Fault Messages" in Section "Auxiliary Functions"). 2.1.2.2 Setting Notes Fault Messages A new pickup of a protection function generally turns off any previously set light 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 messages on the display appear after the new pickup or only after a new trip signal is issued. In order to select the desired mode of display, select the Device submenu in the SETTINGS menu. Under address 610 FltDisp.LED/LCD the two options Target on PU and Target on TRIP ("No trip - no flag") can be selected. Use parameter 611 Spont. FltDisp. to specify whether or not a spontaneous fault message should appear automatically on the display (YES) or not (NO). Selection of Default Display The start page of the default display appearing after startup of the device can be selected in the device data via parameter640 Start image DD. The pages available for each device version are listed in the Appendix E Default Settings and Protocol-dependent Functions. Time Synchronization via Port A If you want the time synchronization of the device to be performed via port A, set the parameters required for this purpose at the following addresses: Address 660 IP adr[0](Prim) to 663 IP adr[3] IP-Addresses 0 to 3, NTP primary (Prim) 34 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Address 664 IP adr[0] (Sec) to 667 IP adr[3] IP-Addresses 0 to 3, NTP secondary (Sec) Address 668 Client activ Address 669 Daylight Set client for primary and secondary addresses switched on or off. daylight saving time switched on or off. Address 670 Offset TZ/min offset for the time zone in minutes Address 671 Offset DayT/min offset for daylight saving time in minutes Address 672 W2S month to 675 W2S hour month, week (of the month), day of the week, hour of switching to daylight saving time month, week (of the month), day of the week, hour of switching to winter time Address 676 S2W month to 679 S2W hour Access authorization for port A At address 651 ParEN100(LC)blk you can parameterize a read access option via the EN100 module at port A. If the parameter is set to ON, you can read out the device parameters using DIGSI or fetch fault records. IEC 61850 GOOSE Function At address 700 GOOSE-Stop you can set the GOOSE function of the IEC 61850 protocol to active or not. If GOOSE-Stop is set to YES, you can release the GOOSE function again via a binary input during operation. 2.1.2.3 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 611 Spont. FltDisp. YES NO NO Spontaneous display of flt.annunciations 640 Start image DD image 1 image 2 image 3 image 4 image 5 image 6 image 1 Start image Default Display 651 ParEN100(LC)blk OFF ON OFF DIGSI-config. over EN100 (LC) blocked 660 IP adr[0](Prim) 0 .. 255 0 IP address [0] (NTP-Primary) 661 IP adr[1](Prim) 0 .. 255 0 IP address [1] (NTP-Primary) 662 IP adr[2](Prim) 0 .. 255 0 IP address [2] (NTP-Primary) 663 IP adr[3](Prim) 0 .. 255 0 IP address [3] (NTP-Primary) 664 IP adr[0] (Sec) 0 .. 255 0 IP address [0] (NTP-Sekundary) 665 IP adr[1] (Sec) 0 .. 255 0 IP address [1] (NTP-Sekundary) 666 IP adr[2] (Sec) 0 .. 255 0 IP address [2] (NTP-Sekundary) 667 IP adr[3] (Sec) 0 .. 255 0 IP address [3] (NTP-Sekundary) 668 Client activ OFF ON OFF Client activ 669 Daylight Set OFF ON OFF Daylight Set 670 Offset TZ/min -1440 .. 1440 min 60 min Offset for time zone in minutes 671 Offset DayT/min -1440 .. 1440 min 60 min Offset for daylight in minutes SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 35 Functions 2.1 General Addr. Parameter Setting Options Default Setting Comments 672 W2S month 1 .. 12 3 month of time set winter to summer 673 W2S week 1 .. 5 5 week of time set winter to summer 674 W2S day Monday Tuesday Wednesday Thursday Friday Saturday Sunday Sunday day of time set winter to summer 675 W2S hour 1 .. 24 2 hour of time set winter to summer 676 S2W month 1 .. 12 10 month of time set summer to winter 677 S2W week 1 .. 5 5 week of time set summer to winter 678 S2W day Monday Tuesday Wednesday Thursday Friday Saturday Sunday Sunday day of time set summer to winter 679 S2W hour 1 .. 24 3 hour of time set summer to winter 700 GOOSE-Stop YES NO NO GOOSE-Stop 2.1.2.4 Information List No. Information Type of Information Comments - >Light on SP >Back Light on - Reset LED IntSP Reset LED - DataStop IntSP Stop data transmission - Test mode IntSP Test mode - Feeder gnd IntSP Feeder GROUNDED - Brk OPENED IntSP Breaker OPENED - HWTestMod IntSP Hardware Test Mode - SynchClock IntSP_Ev Clock Synchronization - Distur.CFC OUT Disturbance CFC 1 Not configured SP No Function configured 2 Non Existent SP Function Not Available 3 >Time Synch SP_Ev >Synchronize Internal Real Time Clock 5 >Reset LED SP >Reset LED 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 36 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General No. Information Type of Information Comments 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 140 Error Sum Alarm OUT Error with a summary alarm 160 Alarm Sum Event OUT Alarm Summary Event 177 Fail Battery OUT Failure: Battery empty 178 I/O-Board error OUT I/O-Board Error 181 Error A/D-conv. OUT Error: A/D converter 191 Error Offset OUT Error: Offset 193 Alarm NO calibr OUT Alarm: NO calibration data available 194 Error neutralCT OUT Error: Neutral CT different from MLFB 232 CT ph mismatch OUT LPCT phase Current Transf. mismatching 233 CT gnd mismatch OUT LPCT ground Current Transf. mismatching 301 Pow.Sys.Flt. OUT Power System fault 302 Fault Event OUT Fault Event 303 sens Gnd flt OUT sensitive Ground fault 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 335 >GOOSE-Stop SP >GOOSE-Stop 502 Relay Drop Out SP Relay Drop Out 510 Relay CLOSE SP General CLOSE of relay 545 PU Time VI Time from Pickup to drop out 546 TRIP Time VI Time from Pickup to TRIP 10080 Error Ext I/O OUT Error Extension I/O 10081 Error Ethernet OUT Error Ethernet 10082 Error Terminal OUT Error Current Terminal 10083 Error Basic I/O OUT Error Basic I/O 2.1.3 Power System Data 1 2.1.3.1 Functional Description The device requires certain basic data regarding the protected equipment so that the device can adapt to its desired application. These may be, for instance, nominal power system and transformer data, measured quantity polarities and their physical connections, breaker properties (where applicable) etc. There are also certain SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 37 Functions 2.1 General parameters that are common to all functions, i.e. not associated with a specific protection, control or monitoring function. The following section discusses these parameters. 2.1.3.2 Setting Notes General Some P.System Data 1 can be entered directly at the device. See Section 2.25 Notes on Device Operation for more information regarding this topic. In DIGSI double-click Settings to open the corresponding dialog box. In doing so, a dialog box with tabs will open under P.System Data 1 where individual parameters can be configured. The following descriptions are therefore structured according to these tabs. Rated Frequency (Power System) The nominal frequency of the system is set under the Address 214 Rated Frequency. The factory presetting in accordance with the model need only be changed if the device will be employed for a purpose other than that which was planned when ordering. In the US device versions (ordering data position 10= C), parameter 214 is preset to 60 Hz. 214. Phase Rotation (Power System) Address 209 PHASE SEQ. is used to change the default phase sequence (A B C for clockwise rotation) if your power system permanently has an anti-clockwise phase sequence (A C B. A temporary reversal of rotation is also possible using binary inputs (see Section 2.21.2 Setting Notes). Polarity of Current Transformers (Power System) At address 201 CT Starpoint, the polarity of the wye-connected current transformers is specified (the following figure applies accordingly to two current transformers). This setting determines the measuring direction of the device (forward = line direction). Changing this parameter also results in a polarity reversal of the ground current inputs N or NS. [polung-stromwandler-020313-kn, 1, en_US] Figure 2-2 Polarity of current transformers Current Connection 4 (Power System) Here, it is communicated to the device whether the ground current of the current transformer neutral point is connected to the fourth current input (4). This corresponds to the Holmgreen connection, (see connection example in C Connection Examples). In this case, parameter 280 Holmgr. for i is set to YES. In all other cases, even if the ground current of the own line is measured via a separate ground current transformer, enter the setting NO. This setting exclusively affects the function "Current Sum Monitoring" (see Section 2.11.1 Measurement Supervision). 38 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Current Connection (Power System) Via parameter 251 CT Connect. a special connection of the current transformers can be determined. The standard connection is A, B, C, (Gnd). It may only be changed if the device is set to measure one or more ground currents via two current inputs. The standard connection has to be used in all other cases. The following picture illustrates such a special connection. [7sj80-mess-2erdstroeme-20070301, 1, en_US] Figure 2-3 Measurement of two ground currents, example The phase currents A and C must be connected to the first current input (terminals F1, F2) and to the third (terminals F5, F6) The ground current N or Ns is connected to the fourth input (terminals F7, F8) as usual, in this case the ground current of the line. A second ground current, in this case the transformer starpoint current, is connected to the second current input N2 (terminals F3, F4). The settings A,G2,C,G; G->B or A,G2,C,G; G2->B are used here. They both define the connection of a ground current N2 to the second current input (terminals F3, F4). The settings only differ in the calculation of B. In the case of A,G2,C,G; G2->B, the phase current B is determined from the phase currents A and C and from the measured ground current N or Ns at the fourth current input. In the case of A,G2,C,G; G2->B, the phase current B is determined from the phase currents A and C and from the measured ground current N2 at the second current input. This setting is only possible for devices with sensitive ground current transformer. Therefore, the current N2 at the second current input is referred to N in the flexible protection functions and in the operational measured values. The sensitive ground current at the fourth current input is referred to Ns. The setting must be selected according to the system requirements. The following table gives an overview of how the protection functions are assigned to the ground current inputs for the special connection. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 39 Functions 2.1 General Function Current input 2 Current input 4 (N2) (N/ Ns) Time overcurrent protection ground 50N/51N (Section 2.2 Overcurrent Protection 50, 51, 50N, 51N) x Directional time overcurrent protection ground 67N (Section 2.3 Directional Overcurrent Protection 67, 67N). x Ground fault detection 64, 67N(s), 50N(s), 51N(s) (Section 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s)) x Single-phase Time Overcurrent Protection (Section2.5 Single-Phase Overcurrent Protection) x Operational Measured Values Display N Ns Track in disturbance record N Ns Important! The function "Directional Time Overcurrent Protection Ground 67N" may only be enabled if the ground current of the protected line is measured via N2. This is not the case in the example shown in Figure 2-3. Here, the ground current of the protected line is measured via N. The function must be deactivated. A connection in which the function can be enabled is illustrated in the Appendix C Connection Examples Figure C-11 The settings for address 251 are only possible with DIGSI at Display Additional SettingsThe Appendix provides some connection examples at C Connection Examples. i NOTE The settings in address 2251 CT Connect. for evaluating the phase currents are only effective if address 250 50/51 2-ph prot was set to OFF. Voltage Connection (Power System) Address 213 specifies how the voltage transformers are connected. VT Connect. 3ph = Van, Vbn, Vcn means that the three phase voltages are wye connected, i.e. the three phase-to-ground voltages are measured.ground. VT Connect. 3ph = Vab, Vbc, VGnd means that two phase-to-phase voltages (open delta voltage) and the displacement voltage VGND are connected. VT Connect. 3ph = Vab, Vbc means that two phase-to-phase voltages (open delta voltage) are connected. The third voltage transformer of the device is not used. VT Connect. 3ph = Vab, Vbc, Vx means that two phase-to-phase voltages (open delta voltage) are connected. Furthermore, any third voltage Vx is connected that is used exclusively for the flexible protection functions. The transformer nominal voltages for Vx are set at address 232 and 233. VT Connect. 3ph = Vab, Vbc, VSyn means that two phase-to-phase voltages (open delta voltage) and the reference voltage for VSYN are connected. This setting is enabled if the synchronization function of the device is used. VT Connect. 3ph = Vph-g, VSyn is used if the synchronization function of the device is used and only phase-to-ground voltages are available for the protected object to be synchronized. One of these voltages is connected to the first voltage transformer; the reference voltage VSYN is connected to the third voltage transformer. The selection of the voltage transformer connection affects the operation of all device functions that require voltage input. The settings Vab, Vbc or Vab, Vbc, Vx or Vab, Vbc, VSyn or Vph-g, VSyn do not allow determining the zero sequence voltage. The associated protection functions are inactive in this case. The table gives an overview of the functions that can be activated for the corresponding connection type (depends also on the ordering number). The functions which are not shown are available for all connection types. 40 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Table 2-1 Connection Types of the Voltage Transformers Connection type Functions Directional definite time/ inverse time overcurrent protection phase Directional Sensitive definiteground fault time/ inverprotection setime over- 50Ns, 51Ns, current 67Ns protection ground Synchronization Fault locator QU protection DirecFuse tional failure intermit- monitor tent ground fault Van, Vbn, Vcn yes yes yes no yes yes yes yes Vab, Vbc, VGnd yes yes yes no yes yes yes yes Vab, Vbc yes yes1) yes2) no no yes no no Vab, Vbc, Vx yes yes1) yes2) no no yes no no Vab, Vbc, VSyn yes no yes2) yes no yes no no Vph-g, VSyn no no yes2) yes no no no no 1) Determination of the direction is only possible by evaluating the negative sequence system (otherwise select zero sequence system or negative sequence system). 2) With this type of voltage transformer connection the current elements operate only non-directional, the voltage elements do not work. With voltage connections Vab, Vbc, Vab, Vbc, Vx and Vab, Vbc, VSyn the power values are only available if you have symmetrical voltage conditions within the network. In this case, address 207 Vol. Symmetry (Power System Data 1) is set to YES. The power values are not available with setting NO. Measured values, which due to the chosen voltage connection cannot be calculated, will be displayed as dots. The Appendix provides some connection examples for all connection types atC Connection Examples. Distance Unit (Power System) Address 215 Distance Unit allows you to specify the distance unit (km or Miles) for the fault locator. In the absence of a fault locator or if this function has been removed, this parameter is of no importance. Changing the distance unit does not imply an automatic conversion of the setting values that are dependent on the distance unit. These have to be re-entered at the respective addresses. ATEX100 (Power System) Parameter 235 ATEX100 enables meeting the requirements for protecting explosion-protected motors for thermal replicas. Set this parameter to YES to save all thermal replicas of the 7SJ80 devices in the event of a power supply failure. After the supply voltage is restored, the thermal replicas will resume operation using the stored values. Set the parameter to NO, to reset the calculated overtemperature values of all thermal replicas to zero if the power supply fails. Nominal Values of Current Transformers (CTs) At addresses 204 CT PRIMARY and 205 CT SECONDARY, information is entered regarding the primary and secondary ampere ratings of the current transformers. It is important to ensure that the rated secondary current of the current transformer matches the rated current of the device, otherwise the device will calculate incorrect primary data. At addresses 217 Ignd-CT PRIM and 218 Ignd-CT SEC, information is entered regarding the primary and secondary ampere rating of the current transformer. In case of a normal connection (neutral point current connected to N transformer), 217 Ignd-CT PRIM and 204 CT PRIMARY must be set to the same value. If the device features a sensitive ground current input, parameter 218 Ignd-CT SEC is set to 1 A by default. In this case, the setting cannot be changed. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 41 Functions 2.1 General For US device models (order item 10= C) parameters 205 and 218 are set by default to 5 A.. If address 251 has been set so that ground currents are measured by two inputs (setting options A,G2,C,G; G->B or A,G2,C,G; G2->B), you have to set the primary rated current of the second ground transformer connected to N2 at address 238. secondary ampere rating must conform with the phase current transformer. To calculated the phase current B correctly, the primary rated current of the ground current transformer, which is used to calculate B (address 217 or address 238), must be smaller than the primary rated current of the phase current transformer (address 204). Nominal Values of Voltage Transformers (VTs) At addresses 202 Vnom PRIMARY and 203 Vnom SECONDARY, information is entered regarding the primary nominal voltage and secondary nominal voltage (phase-to-phase) of the connected voltage transformers. Transformation Ratio of Voltage Transformers (VTs) Address 206 Vph / Vdelta informs the device of the adjustment factor between the phase voltage and the displacement voltage. This information is relevant for the processing of ground faults (in grounded systems and ungrounded systems), for the operational measured value VN and measured-variable monitoring. If the voltage transformer set provides open delta windings and if these windings are connected to the device, this must be specified accordingly in address 213 (see above margin heading "Voltage Connection"). Since the voltage transformer ratio is normally as follows: [uebersetzung-spannungswandler-020313-kn, 1, en_US] the factor Vph/VN (secondary voltage, address 206 Vph / Vdelta) must be set to 3/ 3 = 3 = 1.73 which must be used if the VN voltage is connected. For other transformation ratios, i.e. the formation of the displacement voltage via an interconnected transformer set, the factor must be corrected accordingly. Please take into consideration that also the calculated secondary V0-voltage is divided by the value set in address 206. Thus, even if the V0-voltage is not connected, address 206 has an impact on the secondary operational measured value VN. If Vab, Vbc, VGnd is selected as voltage connection type, parameter Vph / Vdelta is used to calculate the phase-to-ground voltages and is therefore important for the protection function. With voltage connection type Van, Vbn, Vcn, this parameter is used only to calculate the operational measured value of the secondary voltage VN. Trip and Close Command Duration (Breaker) In address 210 the minimum trip command duration TMin TRIP CMD is set. This setting applies to all protection functions that can initiate tripping. In address 211 the maximum close command duration TMax CLOSE CMD is set. It applies to the integrated reclosing function. It must be set long enough to ensure that the circuit breaker has securely closed. An excessive duration causes no problem since the closing command is interrupted in the event another trip is initiated by a protection function. Current Flow Monitoring (Breaker) In address 212 BkrClosed I MIN the pickup threshold of the integrated current flow monitoring function can be set. This parameter is used by several protection functions (e.g. voltage protection with current criterion, overload protection and circuit breaker maintenance). If the set current value is exceeded, the circuit breaker is considered closed. The threshold value setting applies to all three phases, and must take into consideration all used protection functions. The pickup threshold for the breaker failure protection is set separately (see 2.17.2 Setting Notes). 42 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Circuit-breaker Maintenance (Breaker) Parameters 260 to 267 are assigned to CB maintenance. The parameters and the different procedures are explained in the setting notes of this function (see Section 2.23.2 Statistics). Pickup Thresholds of the Binary Inputs (Thresholds BI) At address 220 Threshold BI 1 to 226 Threshold BI 7 you can set the pickup thresholds of the binary inputs of the device. The settings Thresh. BI 176V, Thresh. BI 88V or Thresh. BI 19V are possible. Two-phase Time Overcurrent Protection (Protection Operating Quantities) The two-phase overcurrent protection functionality is used in grounded or compensated systems where interaction of three-phase devices with existing two-phase protection equipment is required. Via parameter 250 50/51 2-ph prot the time overcurrent protection can be configured to two or three-phase operation. If the parameter is set to ON, the value 0 A instead of the measured value for B is used permanently for the threshold comparison so that no pickup is possible in phase B. All other functions, however, operate in three phases. Ground Fault Protection (Protection Operating Quantities) Parameter 613 50N/51N/67N w. defines whether ground fault protection, breaker failure protection or Fuse Failure Monitor is either to operate using measured values (Ignd (measured))) or the quantities calculated from the three phase currents (3I0 (calcul.)). In the first case, the measured quantity at the fourth current input is evaluated. In the latter case, the summation current is calculated from the three phase current inputs. If the device features a sensitive ground current input (measuring range starts at 1 mA), the ground fault protection always uses the calculated variable 3I0. In this case, parameter 613 50N/51N/67N w. is not available. Voltage Protection (Protection Operating Quantities) In a three-phase connection, the fundamental harmonic of the largest of the three phase-to-phase voltages (Vphph) or phase-ground voltages (Vph-n) or the positive sequence voltage (V1) or the negative sequence voltage (V2) is supplied to the overvoltage protection elements. In three-phase connection, undervoltage protection relies either on the positive sequence voltage (V1) or the smallest of the phase-to-phase voltages (Vphph) or the phase-to-ground voltages (Vph-n). This is configured by setting the parameter value in address 614 OP. QUANTITY 59 and 615 OP. QUANTITY 27. With single-phase voltage transformers, a direct comparison of the measured quantities with the threshold values is carried out and the parameterization of the characteristic quantity switchover is ignored. i NOTE i NOTE 2.1.3.3 If parameter 213 VT Connect. 3ph is set to Vph-g, VSyn, the voltage measured by voltage transformer 1 is always used for voltage protection. Then parameters 614 and 615 are not available. If parameter 213 VT Connect. 3ph is set to Vab, Vbc, VSyn or Vab, Vbc or Vab, Vbc, Vx, the setting option Vph-n for parameter 614 and 615 is not available. Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 201 CT Starpoint C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Setting Options Default Setting Comments towards Line towards Busbar towards Line CT Starpoint 43 Functions 2.1 General Addr. Parameter 202 203 Setting Options Default Setting Comments Vnom PRIMARY 0.10 .. 800.00 kV 20.00 kV Rated Primary Voltage Vnom SECONDARY 34 .. 225 V 100 V Rated Secondary Voltage (L-L) 204 CT PRIMARY 10 .. 50000 A 400 A CT Rated Primary Current 205 CT SECONDARY 1A 5A 1A CT Rated Secondary Current 206A Vph / Vdelta 1.00 .. 3.00 1.73 Matching ratio Phase-VT To Open-Delta-VT 207 Vol. Symmetry NO YES NO Assumption voltage symmetry 209 PHASE SEQ. ABC ACB ABC Phase Sequence 210A TMin TRIP CMD 0.01 .. 32.00 sec 0.15 sec Minimum TRIP Command Duration 211A TMax CLOSE CMD 0.01 .. 32.00 sec 1.00 sec Maximum Close Command Duration 212 BkrClosed I MIN 1A 0.04 .. 1.00 A 0.04 A 5A 0.20 .. 5.00 A 0.20 A Closed Breaker Min. Current Threshold 213 VT Connect. 3ph Van, Vbn, Vcn Vab, Vbc, VGnd Vab, Vbc, VSyn Vab, Vbc Vph-g, VSyn Vab, Vbc, Vx Van, Vbn, Vcn VT Connection, threephase 214 Rated Frequency 50 Hz 60 Hz 50 Hz Rated Frequency 215 Distance Unit km Miles km Distance measurement unit 217 Ignd-CT PRIM 1 .. 50000 A 60 A Ignd-CT rated primary current 218 Ignd-CT SEC 1A 5A 1A Ignd-CT rated secondary current 220 Threshold BI 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 1 221 Threshold BI 2 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 2 222 Threshold BI 3 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 3 223 Threshold BI 4 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 4 224 Threshold BI 5 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 5 44 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Addr. Parameter 225 C Setting Options Default Setting Comments Threshold BI 6 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 6 226 Threshold BI 7 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 7 227 Threshold BI 8 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 8 228 Threshold BI 9 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 9 229 Threshold BI 10 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 10 230 Threshold BI 11 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 11 232 VXnom PRIMARY 0.10 .. 800.00 kV 20.00 kV Rated Primary Voltage X 233 VXnom SECONDARY 100 .. 225 V 100 V Rated Secondary Voltage X 235A ATEX100 NO YES YES Storage of th. Replicas w/o Power Supply 238 Ignd2-CT PRIM. 1 .. 50000 A 400 A Ignd2-CT rated primary c. (conn. to I2) 239 Ignd2-CT SEC. 1A 5A 1A Ignd2-CT rated secondary current (I2) 250A 50/51 2-ph prot OFF ON OFF 50, 51 Time Overcurrent with 2ph. prot. 251A CT Connect. A, B, C, (Gnd) A,G2,C,G; G->B A,G2,C,G; G2->B A, B, C, (Gnd) CT Connection 252 Ph LPCT pol. not reversed reversed not reversed Phase LPCT orientation / polarity 260 Ir-52 10 .. 50000 A 125 A Rated Normal Current (52 Breaker) 261 OP.CYCLES AT Ir 100 .. 1000000 10000 Switching Cycles at Rated Normal Current 262 Isc-52 10 .. 100000 A 25000 A Rated Short-Circuit Breaking Current 263 OP.CYCLES Isc 1 .. 1000 50 Switch. Cycles at Rated Short-Cir. Curr. 264 Ix EXPONENT 1.0 .. 3.0 2.0 Exponent for the IxMethod 265 Cmd.via control (Setting options depend on none configuration) 52 B.Wear: Open Cmd. via Control Device 266 T 52 BREAKTIME 1 .. 600 ms 80 ms Breaktime (52 Breaker) 267 T 52 OPENING 1 .. 500 ms 65 ms Opening Time (52 Breaker) 280 Holmgr. for i NO YES NO Holmgreen-conn. (for fast sum-i-monit.) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 45 Functions 2.1 General Addr. Parameter 310 C Setting Options Default Setting Comments Iph-PRIM ref. 10 .. 50000 A 400 A Primary refer. phase current for prot. 311 Iph-LPCT PRIM 1 .. 5000 A 400 A Rated primary phase current LPCT 312 Ignd-PRIM ref. 1 .. 50000 A 60 A Primary refer. ground current for prot. 313 Ignd-LPCT PRIM 0.01 .. 5000.00 A 2.00 A Rated primary ground current LPCT 314 Vph-LPCT SEC 10.0 .. 1000.0 mV 225.0 mV Rated secondary phase voltage LPCT 315 Vgnd-LPCT SEC 10.0 .. 1000.0 mV 225.0 mV Rated secondary ground voltage LPCT 320A Corr.factor IL1 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IL1 321A Corr.factor IL2 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IL2 322A Corr.factor IL3 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IL3 323A Corr.factor IE 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IE 324A Corr.factor IEE 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IEE 330 V-LPVT SEC 3.00 .. 17.00 V 3.25 V rated secondary voltage LPVT 332A V-LPVT PHA -10.00 .. 10.00 0.00 phase angle LPVT 613A Gnd O/Cprot. w. Ignd (measured) 3I0 (calcul.) Ignd (measured) Ground Overcurrent protection with 614A OP. QUANTITY 59 Vphph Vph-n V1 V2 Vphph Opera. Quantity for 59 Overvolt. Prot. 615A OP. QUANTITY 27 V1 Vphph Vph-n V1 Opera. Quantity for 27 Undervolt. Prot. 616 STATIC GEN. YES NO NO Static or non self-exc. Asyn. Generator 2.1.3.4 Information List No. Information Type of Information Comments 5145 >Reverse Rot. SP >Reverse Phase Rotation 5147 Rotation ABC OUT Phase rotation ABC 5148 Rotation ACB OUT Phase rotation ACB 2.1.4 Oscillographic Fault Records The Multifunctional Protection with Control 7SJ80 is equipped with a fault record memory. The instantaneous values of the measured values 46 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General iA, iB, iC, iN, iNs and vA, vB, vC, vA2, vB3, vC1, vN, vX, vph-n, vSYN (voltages depending on connection) are sampled at intervals of 1.0 ms (at 50 Hz) and stored in a revolving buffer (20 samples per cycle). In the event of a fault, the data are recorded for a set period of time, but not for more than 5 seconds. A maximum of 8 faults can be recorded in this buffer. The fault record memory is automatically updated with every new fault, so no acknowledgment for previously recorded faults is required. In addition to protection pickup, the recording of the fault data can also be started via a binary input or via the serial interface. 2.1.4.1 Functional Description The data of a fault event can be read out via the device interface and evaluated with the help of the SIGRA 4 graphic analysis software. SIGRA 4 graphically represents the data recorded during the fault event and also calculates additional information from the measured values. Currents and voltages can be presented either as primary or as secondary values. Signals are additionally recorded as binary tracks (marks), e.g. "pickup", "trip". If port B of the device has been configured correspondingly, the fault record data can be imported by a central controller via this interface and evaluated. Currents and voltages are prepared for a graphic representation. Signals are additionally recorded as binary tracks (marks), e.g. "pickup", "trip". The retrieval of the fault data by the central controller takes place automatically either after each protection pickup or after a tipping. If device parameter 651 ParEN100(LC)blk is set to ON, you can also read out fault records via port A (see Section 2.1.2.2 Setting Notes). Depending on the selected type of connection of the voltage transformers (address 213 VT Connect. 3ph), the following measured values are recorded in the fault record: Voltage connection Van, Vbn, Vcn Vab, Vbc, VGnd Vab, Vbc Vab, Vbc, Vx Vab, Vbc, VSyn vAB yes yes yes yes yes vBC yes yes yes yes yes vCA yes yes yes yes yes vA yes yes vB yes yes vC yes yes v Vph-g, VSyn yes ven yes yes vSYN yes vx yes yes i NOTE i NOTE The signals used for the binary tracks can be allocated in DIGSI. If one of the current transformer connection types A,G2,C,G; G->B or A,G2,C,G; G2->B has been selected via parameter 251 CT Connect., the ground current N2 measured with the second current transformer is indicated under track N. The ground current detected by the fourth current transformer is indicated under track Ns. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 47 Functions 2.1 General 2.1.4.2 Setting Notes Configuration Fault recording (waveform capture) will only take place if address 104 OSC. FAULT REC. is set to Enabled. Other settings pertaining to fault recording (waveform capture) are found in the Osc. Fault Rec. 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 (address 401 WAVEFORMTRIGGER). Normally, the trigger is the pickup of a protection element, i.e. the time 0 is defined as the instant the first protection function picks up. 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. A fault event starts with the pickup by any protection function and ends when the last pickup of a protection function has dropped out. Usually this is also the extent of a fault recording (address 402 WAVEFORM DATA = Fault event). If automatic reclosing is performed, the entire system fault -- with several reclosing attempts if necessary -- can be recorded until the fault has been cleared for good (address 402 WAVEFORM DATA = Pow.Sys.Flt.). This facilitates the representation of the entire system fault history, but also consumes storage capacity during the automatic reclosing dead time(s). The actual storage time begins at the pre-fault time PRE. TRIG. TIME (address 404) ahead of the reference instant, and ends at the post-fault time POST REC. TIME (address 405) after the storage criterion has reset. The maximum storage duration of each fault record (MAX. LENGTH) is entered at address 403. Recording per fault must not exceed 5 seconds. In maximum 8 records can be saved altogether with a maximum total time of 18 s . An oscillographic record can be triggered by a status change of a binary input, or from a PC via the operator interface. Storage is then triggered dynamically. The length of the fault recording is set in address 406 BinIn CAPT.TIME (but not longer than MAX. LENGTH, address 403). Pre-fault and post-fault times will add to this. If the binary input time is set to , the length of the record equals the time that the binary input is activated (static), but not longer than the MAX. LENGTH (address 403). 2.1.4.3 Settings Addr. Parameter Setting Options Default Setting Comments 401 WAVEFORMTRIGGER Save w. Pickup Save w. TRIP Start w. TRIP Save w. Pickup Waveform Capture 402 WAVEFORM DATA Fault event Pow.Sys.Flt. Fault event Scope of Waveform Data 403 MAX. LENGTH 0.30 .. 5.00 sec 2.00 sec Max. length of a Waveform Capture Record 404 PRE. TRIG. TIME 0.05 .. 0.50 sec 0.25 sec Captured Waveform Prior to Trigger 405 POST REC. TIME 0.05 .. 0.50 sec 0.10 sec Captured Waveform after Event 406 BinIn CAPT.TIME 0.10 .. 5.00 sec; 0.50 sec Capture Time via Binary Input 2.1.4.4 Information List No. Information Type of Information Comments - FltRecSta IntSP Fault Recording Start 4 >Trig.Wave.Cap. SP >Trigger Waveform Capture 203 Wave. deleted OUT_Ev Waveform data deleted 30053 Fault rec. run. OUT Fault recording is running 48 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General 2.1.5 Settings Groups Up to four different setting groups can be created for establishing the device's function settings. Applications * 2.1.5.1 Setting groups enable the user to save the corresponding settings for each application so that they can be quickly called up when required. All setting groups are stored in the device. Only one setting group may be active at a time. Functional Description Changing Setting Groups During operation the user can switch back and forth setting groups locally, via the operator panel, binary inputs (if so configured), the service interface using 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 as Enabled during configuration (see Section 2.1.1.2 Setting Notes). In 7SJ80 relays, four independent setting groups (A to D) are available. While setting values may vary, the selected functions of each setting group remain the same. 2.1.5.2 Setting Notes General If setting group change option is not required, Group A is the default selection. Then, the rest of this section is not applicable. If the changeover option is desired, group changeover must be set to Grp Chge OPTION = Enabled (address 103) when the function extent is configured. For the setting of the function parameters, each of the required setting groups A to D (a maximum of 4) must be configured in sequence. The SIPROTEC 4 System Description gives further information on how to copy setting groups or reset them to their status at delivery and also how to change from one setting group to another. Section 3.1 Mounting and Connections of this manual tells you how to change between several setting groups externally via binary inputs. 2.1.5.3 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 2.1.5.4 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 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 49 Functions 2.1 General 2.1.6 Power System Data 2 2.1.6.1 Functional Description The general protection data (P.System Data 2) include settings associated with all functions rather than a specific protection or monitoring function. In contrast to the P.System Data 1 as discussed before, they can be changed with the setting group. Applications When the primary reference voltage and the primary reference current of the protected object are set, the device is able to calculate and output the operational measured value percentage. For purposes of fault location, a maximum of three different line sections can be considered. 2.1.6.2 Setting Notes Definition of Nominal Rated Values At addresses 1101 FullScaleVolt. and 1102 FullScaleCurr., the primary reference voltage (phasetophase) and reference current (phase) of the protected equipment is entered. If these reference sizes match the primary nominal values of the VTs and CTs, they correspond to the settings in address 202 and 204 (Section 2.1.3.2 Setting Notes). They are generally used to show values referenced to full scale. Ground Impedance Ratios (only for Fault Location) The adjustment of the ground impedance ratio is only important for the utilization of the line fault location function. This is done by entering the resistance ratio RE/RL and the reactance ratio XE/XL. The values under addresses 1103 and 1104 apply if only one line section is available and to all faults that occur outside the defined line sections. If several line sections are set, the following shall apply: * for line section 1, addresses 6001 and 6002 * * for line section 1, addresses 6011 and 6012 for line section 1, addresses 6021 and 6022. Resistance ratio RE/RL and reactance ratio XE/XL are calculated formally and do not correspond to the real and imaginary components of ZE/ZL. No complex calculation is required! The ratios can be obtained from the line data using the following formulas: [formelfehlerorter-260602-kn, 1, en_US] Where R0 - Zero sequence resistance of the line X0 - Zero sequence reactance of the line R1 - Positive sequence resistance of the line X1 - Positive sequence reactance of the line This data can be used for the entire line or line section, or as distance-related values, since the quotients are independent of the distance. Calculation example: 20 kV free line 120 mm2 with the following data: 50 R0/s = 0.88 /km (1.42 /mile) Zero sequence resistance X0/s = 1.26 /km (2.03 /mile) Zero sequence reactance R1/s = 0.24 /km (0.39 /mile) Positive sequence resistance SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General X1/s = 0.34 /km (0.55 /mile) Positive sequence reactance For ground impedance ratios, the following results: [formfehl-260602-kn, 1, en_US] Reactance per Unit Length (only for Fault Location) The setting of the reactance per unit length is only important for the utilization of the line fault location function. The reactance setting enables the protective relay to indicate the fault location in terms of distance. The reactance value X' is entered as a reference value x', i.e. in /mile if set to distance unit Miles (address 215, see Section 2.1.3.2 Setting Notes under "Distance Unit") or in /km if set to distance unit km. If, after having entered the reactance per unit length, the distance unit is changed under address 215, the reactance per unit length must be reconfigured in accordance with the new distance unit. The values under address 1106 (km) or 1105 (Miles) apply if only one line section is available and to all faults that occur outside the defined line sections. If several line sections are set, the following shall apply: * for line section 1, addresses 6004(km) or 6003 (Miles) * * for line section 2, addresses 6014 (km) or 6013 (Miles), for line section 3, addresses 6024 (km) or 6023 (Miles). When setting the parameters in DIGSI, the values can also be entered as primary values. In that case the following conversion to secondary values is not required. For the conversion of primary values to secondary values the following applies in general: [zsekundaer-260602-kn, 1, en_US] Likewise, the following applies to the reactance per unit length of a line: [xsekundaer-260602-kn, 1, en_US] with NCTR -- Transformation ratio of the current transformer NVTR -- Transformation ratio of the voltage transformer Calculation example: In the following, the same line as illustrated in the example for ground impedance ratios (above) and additional data on the voltage transformers will be used: Current Transformers Voltage Transformers 500 A/5 A 20 kV/0.1 kV The secondary reactance per unit length is calculated as follows: [xsekund-beispiel-260602-kn, 1, en_US] SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 51 Functions 2.1 General Line Angle (only for Fault Location) The setting of the line angle is only important for the utilization of the line fault location function. The line angle can be derived from the line constants. The following applies: [formel-allg-ltgdaten-1-oz-310702, 1, en_US] with RL being the ohmic resistance and XL being the reactance of the line. The value under address 1109 applies if only one line section is available and to all faults that occur outside the defined line sections. If several line sections are set, the following shall apply: * for line section 1, address 6005 * * for line section 2, address 6015 for line section 3, address 6025 This data can be used for the entire line or line section, or as distance-related values, since the quotients are independent of the distance. It is also irrelevant whether the quotients were derived from primary or secondary values. Calculation Example:: 110 kV free line 150 mm2 with the following data: R'1 = 0.19 /km (0.31 /mile) X'1 = 0.42 /km (0.69 /mile) The line angle is calculated as follows: [formel-allg-ltgdaten-2-oz-310702, 1, en_US] The respective address must be set to Line angle = 66. Line Length (only for Fault Location) The setting of the line length is only important for the utilization of the line fault location function. The line length is required so that the fault location can be given as a reference value (in %). Furthermore, when using several line sections, the respective length of the individual sections is defined. The values under address 1110 (km) or 1111 (Miles apply if only one line section is available and to all faults that occur outside the defined line sections. If several line sections are set, the following shall apply: * for line section 1, addresses 6006 (km) or 6007 (Miles) * * for line section 2, addresses 6016 (km) or 6017 (Miles) for line section 3, addresses 6026 (km) or 6027 (Miles) The length set for the entire line must correspond to the sum of lengths configured for the line sections. A deviation of 10% max. is admissible. Operating Range of the Overload Protection The current threshold entered in address 1107 I MOTOR START limits the operating range of the overload protection to larger current values. The thermal replica is kept constant for as long as this threshold is exceeded. 52 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General Inverting Power Measured Values/Metered Values The directional values (power, power factor, work and related min., max., mean and setpoint values), calculated in the operational measured values, are usually defined a positive in the direction of the protected object. This requires that the connection polarity for the entire device was configured accordingly in the P.System Data 1 (compare also "Polarity of the Current Transformers", address 201). But it is also possible to make different settings for the "forward" direction" for the protection functions and the positive direction for the power etc., e.g. to have the active power supply (from the line to the busbar) displayed positively. To do so, set address 1108 P,Q sign to reversed. If the setting is not reversed (default), the positive direction for the power etc. corresponds to the "forward" direction for the protection functions. Section 4 Technical Data provides a detailed list of the values in question. 2.1.6.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 1101 Setting Options Default Setting Comments FullScaleVolt. 0.10 .. 800.00 kV 20.00 kV Measurem:FullScaleVoltage(Equipm.rating) 1102 FullScaleCurr. 10 .. 50000 A 400 A Measurem:FullScaleCurrent(Equipm.rating) 1103 RE/RL -0.33 .. 7.00 1.00 Zero seq. compensating factor RE/RL 1104 XE/XL -0.33 .. 7.00 1.00 Zero seq. compensating factor XE/XL 1105 x' 1A 0.0050 .. 15.0000 /mi 0.2420 /mi 5A 0.0010 .. 3.0000 /mi 0.0484 /mi feeder reactance per mile: x' 1A 0.0050 .. 9.5000 /km 0.1500 /km feeder reactance per km: x' 5A 0.0010 .. 1.9000 /km 0.0300 /km 1A 0.40 .. 10.00 A 2.50 A 5A 2.00 .. 50.00 A 12.50 A P,Q sign not reversed reversed not reversed P,Q operational measured values sign 1109 Line angle 10 .. 89 85 Line angle 1110 Line length 0.1 .. 1000.0 km 100.0 km Line length in kilometer 1111 Line length 0.1 .. 650.0 Miles 62.1 Miles Line length in miles 6001 S1: RE/RL -0.33 .. 7.00 1.00 S1: Zero seq. compensating factor RE/RL 6002 S1: XE/XL -0.33 .. 7.00 1.00 S1: Zero seq. compensating factor XE/XL 6003 S1: x' 1A 0.0050 .. 15.0000 /mi 0.2420 /mi 5A 0.0010 .. 3.0000 /mi 0.0484 /mi S1: feeder reactance per mile: x' 6004 S1: x' 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km S1: feeder reactance per km: x' 6005 S1: Line angle 10 .. 89 85 S1: Line angle 6006 S1: Line length 0.1 .. 650.0 Miles 62.1 Miles S1: Line length in miles 6007 S1: Line length 0.1 .. 1000.0 km 100.0 km S1: Line length in kilometer 6011 S2: RE/RL -0.33 .. 7.00 1.00 S2: Zero seq. compensating factor RE/RL 6012 S2: XE/XL -0.33 .. 7.00 1.00 S2: Zero seq. compensating factor XE/XL 6013 S2: x' 1A 0.0050 .. 15.0000 /mi 0.2420 /mi 5A 0.0010 .. 3.0000 /mi 0.0484 /mi S2: feeder reactance per mile: x' 1106 1107 1108 x' I MOTOR START C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Motor Start Current (Block 49, Start 48) 53 Functions 2.1 General Addr. Parameter C Setting Options Default Setting Comments 6014 S2: x' 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km S2: feeder reactance per km: x' 6015 S2: Line angle 10 .. 89 85 S2: Line angle 6016 S2: Line length 0.1 .. 650.0 Miles 62.1 Miles S2: Line length in miles 6017 S2: Line length 0.1 .. 1000.0 km 100.0 km S2: Line length in kilometer 6021 S3: RE/RL -0.33 .. 7.00 1.00 S3: Zero seq. compensating factor RE/RL 6022 S3: XE/XL -0.33 .. 7.00 1.00 S3: Zero seq. compensating factor XE/XL 6023 S3: x' 1A 0.0050 .. 15.0000 /mi 0.2420 /mi 5A 0.0010 .. 3.0000 /mi 0.0484 /mi S3: feeder reactance per mile: x' 6024 S3: x' 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km S3: feeder reactance per km: x' 6025 S3: Line angle 10 .. 89 85 S3: Line angle 6026 S3: Line length 0.1 .. 650.0 Miles 62.1 Miles S3: Line length in miles 6027 S3: Line length 0.1 .. 1000.0 km 100.0 km S3: Line length in kilometer 2.1.6.4 Information List No. Information Type of Information Comments 126 ProtON/OFF IntSP Protection ON/OFF (via system port) 356 >Manual Close SP >Manual close signal 466.4010 Cmd Trip IntSP Trip via control command 501 Relay PICKUP OUT Relay PICKUP 511 Relay TRIP OUT Relay GENERAL TRIP command 533 Ia = VI Primary fault current Ia 534 Ib = VI Primary fault current Ib 535 Ic = VI Primary fault current Ic 561 Man.Clos.Detect OUT Manual close signal detected 2720 >Enable ANSI#-2 SP >Enable 50/67-(N)-2 (override 79 blk) 4601 >52-a SP >52-a contact (OPEN, if bkr is open) 4602 >52-b SP >52-b contact (OPEN, if bkr is closed) 16019 >52 Wear start SP >52 Breaker Wear Start Criteria 16020 52 WearSet.fail OUT 52 Wear blocked by Time Setting Failure 16027 52WL.blk I PErr OUT 52 Breaker Wear Logic blk Ir-CB>=Isc-CB 16028 52WL.blk n PErr OUT 52 Breaker W.Log.blk SwCyc.Isc>=SwCyc.Ir 18420 >Trip via BI SP >Trip via Binary Input 18421 Trip via GOOSE ExSP Trip via GOOSE 18423 Direct Trip OUT Direct Trip 18424 PI Trip NC OUT PI Trip NC(ON,if Device ok & No Trip) 18425 >DDI Open SP >DDI Open status 54 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.1 General 2.1.7 EN100-Module 2.1.7.1 Functional Description The Ethernet EN100-Modul enables integration of the 7SJ80 in 100-Mbit communication networks in control and automation systems with the protocols according to IEC 61850 standard. This standard permits uniform communication of the devices without gateways and protocol converters. Even when installed in heterogeneous environments, SIPROTEC 4 relays therefore provide for open and interoperable operation. Parallel to the process control integration of the device, this interface can also be used for communication with DIGSI and for inter-relay communication via GOOSE. 2.1.7.2 Setting Notes Interface Selection No special settings are required for operating the Ethernet system interface module (IEC 1850, Ethernet EN100-Modul). If the ordered version of the device is equipped with such a module, it is automatically allocated to the interface available for it, namely Port B. IEC 61850 GOOSE Function The GOOSE function can be disabled via a device parameter. For more information, please refer to Section 2.1.2.2 Setting Notes. 2.1.7.3 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) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 55 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 2.2 Overcurrent Protection 50, 51, 50N, 51N The overcurrent protection is provided with a total of four elements each for the phase currents and the ground current. All elements are independent from each other and can be combined as desired. If it is desired in isolated or resonant-grounded systems that three-phase devices should work together with two-phase protection equipment, the overcurrent protection can be configured in such a way that it allows twophase operation besides the three-phase mode (see Section 2.1.3.2 Setting Notes). The high-set elements 50-2, 50-3, 50N-2, 50N-3 as well as the overcurrent elements 50-1 and 50N-1 always operate with a definite tripping time (51), the elements 51 and 51N always with an inverse tripping time (50). Applications * 2.2.1 The non-directional overcurrent protection is applicable for networks that are radial and supplied from a single source or open looped networks, for backup protection of differential protective schemes of all types of lines, transformers, generators and busbars. General The overcurrent protection for the ground current can either operate with measured values N or with the quantities 30 calculated from the three phase currents. Which values are used depends on the setting of parameter 613 Gnd O/Cprot. w. and the selected type of connection of the current transformers. Information on this can be found in Chapter 2.1.3.2 Setting Notes, connection examples in Appendix C Connection Examples. Devices featuring a sensitive ground current input, however, generally use the calculated quantity 30. All overcurrent elements enabled in the device may be blocked via the automatic reclosing function (depending on the cycle) or via an external signal to the binary inputs of the device. Removal of blocking during pickup will restart time delays. The Manual Close signal is an exception in this case. If a circuit breaker is manually closed onto a fault, it can be re-opened immediately. For overcurrent elements or high-set elements the delay may be bypassed via a Manual Close pulse, thus resulting in high speed tripping. This pulse is extended up to at least 300 ms. The automatic reclosure function 79 may also initiate immediate tripping for the overcurrent and high-set elements depending on the cycle. Pickup of the definite-time elements can be stabilized by setting the dropout times. This protection is used in systems where intermittent faults occur. Combined with electromechanical relays, it allows different dropout responses to be adjusted and a time grading of digital and electromechanical relays to be implemented. Pickup and delay settings may be quickly adapted to system requirements via dynamic setting changeover (see Section 2.4 Dynamic Cold Load Pickup). Tripping by the 50-1 and 51 elements (in phases), 50N-1 and 51N elements (in ground path) may be blocked for inrush conditions by utilizing the inrush restraint feature. The following table gives an overview of the interconnections to other functions of the devices 7SJ80. Table 2-2 Overcurrent Protection Elements 56 Interconnection to other functions Connection to Automatic Reclosing Manual CLOSE Dynamic Cold Load Pickup Inrush Restraint 50-1 * * * 50-2 * * * * 50-3 * * * 51 * * * * 50N-1 * * * * 50N-2 * * * 50N-3 * * * SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N Overcurrent Protection Elements Connection to Automatic Reclosing 51N 2.2.2 * Manual CLOSE * Dynamic Cold Load Pickup * Inrush Restraint * Definite Time, High-set Elements 50-3, 50-2, 50N-3, 50N-2 For each element, an individual pickup value 50-3 PICKUP, 50-2 PICKUP or 50N-3 PICKUP, 50N-2 PICKUP is set. For 50-3 PICKUP and 50N-3 PICKUP, it is possible to measure the Instantaneous in addition to Fundamental and True RMS. If set to Instantaneous, the element picks up at 2 * 2 * setting value (rms). Each phase and ground current is compared separately per element with the common pickup values 50-3 PICKUP, 50-2 PICKUP or 50N-3 PICKUP, 50N-2 PICKUP. If the respective pickup value is exceeded, this is signaled. After the user-defined time delays 50-3 DELAY, 50-2 DELAY or 50N-3 DELAY, 50N-2 DELAY have elapsed, trip commands are issued which are available for each element. The dropout value is roughly equal to 95% of the pickup value for currents > 0.3 Nom. If the measurement of the instantaneous values has been parameterized for the 50-3 or 50N-3 element, the dropout ratio is set to 90 %. Pickup can be stabilized by setting dropout times 1215 50 T DROP-OUT or 1315 50N T DROP-OUT. This time is started and maintains the pickup condition if the current falls below the threshold. Therefore, the function does not drop out at high speed. The trip delay time 50-3 DELAY, 50-2 DELAY or 50N-3 DELAY, 50N-2 DELAY continues running in the meantime. After the dropout delay time has elapsed, the pickup is reported OFF and the trip delay time is reset unless the threshold 50-3 PICKUP, 50-2 PICKUP or 50N-3 PICKUP, 50N-2 PICKUP has been exceeded again. If the threshold is exceeded again during the dropout delay time, the time is canceled. The trip delay time 50-3 DELAY, 50-2 DELAY or 50N-3 DELAY, 50N-2 DELAY continues running in the meantime. If the threshold value is exceeded after this time has elapsed, the trip command is issued immediately. If the threshold value is not exceeded at this time, there is no reaction. If the threshold value is exceeded again after expiry of the trip command delay time while the dropout delay time is still running, tripping is initiated immediately. These elements can be blocked by the automatic reclosing function (79 AR). The pickup values of each 50-2, 50-3 Element for phase currents and 50N-2, 50N-3 Element for the ground current and the element-specific time delays can be set individually. The following figures give an example of logic diagrams for the high-set elements 50-2 PICKUP or 50N-2 PICKUP. They also apply analogously to the high-set elements 50-3 PICKUP and 50N-3 PICKUP. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 57 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x-hochstromst-i-fuer-ph-20061212, 1, en_US] Figure 2-4 Logic diagram for 50-2 high-set element for phases If parameter MANUAL CLOSE is set to 50-2 instant. or 50-3 instant. and manual close detection is used, a pickup causes instantaneous tripping, even if the element is blocked via binary input. The same applies to 79 AR 50-2 inst. or 79 AR 50-3 inst. 58 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x-hochstromst-ie-20061212, 1, en_US] Figure 2-5 Logic diagram for 50N-2 high-set element If parameter MANUAL CLOSE is set to 50N-2 instant. or 50N-3 instant. and manual close detection is used, a pickup causes instantaneous tripping, even if the element is blocked via binary input. The same applies to AR 50N-2 inst. The same applies to 79 AR 50N-2 inst. or 79 AR 50N-3 inst. 2.2.3 Definite Time Overcurrent Elements 50-1, 50N-1 For each element an individual pickup value 50-1 PICKUP or 50N-1 PICKUP is set. Apart from Fundamental, the True RMS can also be measured. Each phase and ground current is compared separately with the setting value 50-1 or 50N-1 for each element. If the respective value is exceeded, this is signaled. If the inrush restraint feature (see below) is applied, either the normal pickup signals or the corresponding inrush signals are output as long as inrush current is detected. After user-configured time delays 50-1 DELAY or 50N-1 DELAY have elapsed, a trip signal is issued if no inrush current is detected or inrush restraint is disabled. If the inrush restraint feature is enabled and an inrush condition exists, no tripping takes place but a message is recorded and displayed indicating when the overcurrent element time delay elapses. Trip signals and signals on the expiration of time delay are available separately for each element. The dropout value is approximately 95% of the pickup value for currents > 0.3 INom. Pickup can be stabilized by setting dropout times 1215 50 T DROP-OUT or1315 50N T DROP-OUT. This time is started and maintains the pickup condition if the current falls below the threshold. Therefore, the function does not drop out at high speed. The trip-command delay time 50-1 DELAY or 50N-1 DELAY continues running in the meantime. After the dropout delay time has elapsed, the pickup is reported OFF and the trip delay time is reset unless the threshold 50-1 or 50N-1 has been exceeded again. If the threshold is exceeded again during the dropout delay time, the time is canceled. However, the trip-command delay time 50-1 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 59 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N DELAY or 50N-1 DELAY continues running. If the threshold value is exceeded after its expiry, the trip command is issued immediately. If the threshold value is not exceeded at this time, there is no reaction. If the threshold value is exceeded again after expiry of the trip-command delay time, while the dropout delay time is still running, tripping occurs immediately. Pickup stabilization of the overcurrent elements 50-1 or 50N-1 by means of settable dropout time is deactivated if an inrush pickup is present since an inrush does not represent an intermittent fault. These elements can be blocked by the automatic reclosing function (79 AR). The pickup values of each 50-1 element for phase currents and 50N-1 element for the ground current and the element-specific time delays can be set individually. The following figures show the logic diagrams for the current elements 50-1 and 50N-1. [7sj6x-ueberstromst-i-fuer-ph-20061212, 1, en_US] Figure 2-6 Logic diagram for the 50-1 overcurrent element for phases If parameter MANUAL CLOSE is set to 50 -1 instant. and manual close detection is used, a pickup causes instantaneous tripping, even if blocking of the element via binary input is present. The same applies to 79 AR 50-1 inst. The dropout delay only operates if no inrush was detected. An incoming inrush will reset a running dropout delay time. 60 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x_rueckfallverzoegerung_i_gr_ph_260803_he, 1, en_US] Figure 2-7 Logic diagram of the dropout delay for 50-1 [7sj6x-ueberstromst-ie-20061212, 1, en_US] Figure 2-8 Logic diagram for the 50N-1 overcurrent current element If parameter MANUAL CLOSE is set to 50N-1 instant. and manual close detection applies, the trip is initiated as soon as the pickup conditions arrive, even if the element is blocked via a binary input. The same applies to 79 AR 50N-1 inst. The pickup values of each 50-1, 50-2 element for the phase currents and 50N-1, 50N-2 element for the ground current and the valid delay times for each element can be set individually. The dropout delay only functions if no inrush was detected. An incoming inrush will reset a running dropout time delay. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 61 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x_rueckfallverzoegerung_i_gr_erde_260803_he, 1, en_US] Figure 2-9 2.2.4 Logic of the dropout delay for 50N-1 Inverse Time Overcurrent Elements 51, 51N Inverse time overcurrent elements are dependent on the ordering version. They always operate with an inverse time Curve in accordance with IEC or ANSI standards. The characteristics and associated formulas are given in the Technical Data. When configuring one of the inverse-time characteristics, the definite-time elements 50-3, 50-2,and 50-1 are also active (see Section "Definite-time High-set Current Elements 50-3, 50-2, 50N-3, 50N-2 " and "Definitetime Overcurrent Elements 50-1, 50N-1 "). A voltage restraint can optionally be set (see Section "Inverse Time Overcurrent Protection (Voltagecontrolled / Voltage-restraint"). Pickup Behavior For each element, an individual pickup value 51 PICKUP or 51N PICKUP is set. Apart from Fundamental, the True RMS can also be measured. Each phase and ground current is separately compared with the setting value 51 or 51N per element. If a current exceeds 1.1 times the setting value, the corresponding element picks up and is signaled individually. If the inrush restraint function is used, either the normal pickup signals or the corresponding inrush signals are issued as long as inrush current is detected. If the 51 element picks up, the tripping time is calculated from the actual fault current flowing, using an integrating method of measurement. The calculated tripping time depends on the selected tripping curve. Once this time has elapsed, a trip signal is issued provided that no inrush current is detected or inrush restraint is disabled. If the inrush restraint function is enabled and an inrush condition exists, no tripping takes place but a message is issued indicating when the overcurrent element time delay elapses. These elements can be blocked by the automatic reclosing feature (79 AR). For ground current element 51N, the characteristic may be selected independently of the characteristic used for phase currents. Pickup values of elements 51 (phase currents) and 51N (ground current) and the relevant time multiplicators may be set individually. The following two figures show the logic diagrams for the inverse time overcurrent protection. 62 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x-abhueberstromzeit-phase-20061212, 1, en_US] Figure 2-10 Logic diagram of the inverse-time overcurrent protection element for phases If an ANSI characteristic is configured, parameter 1209 51 TIME DIAL is used instead of parameter 1208 51 TIME DIAL. If parameter MANUAL CLOSE is set to 51 instant. and manual close detection applies, the trip is initiated as soon as the pickup conditions arrive, even if the element is blocked via a binary input. The same applies to 79 AR 51N inst. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 63 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x-abhueberstromzeit-erde-20061212, 1, en_US] Figure 2-11 Logic diagram of the inverse-time overcurrent protection element for ground If an ANSI characteristic is configured, parameter 1309 51N TIME DIAL is used instead of parameter 1308 51N TIME DIAL. If parameter MANUAL CLOSE is set to 51N instant. and manual close detection applies, the trip is initiated as soon as the pickup conditions arrive, even if the element is blocked via binary input. The same applies to 79 AR 51N inst. Dropout Behavior For the ANSI or IEC characteristics, you can select whether an element drops out instantaneously after a threshold has been undershot or whether dropout is performed by means of disk emulation. "Instantaneous" means that the picked-up element drops out when 95 % of the pickup value is undershot. For a new pickup, the time delay starts at zero. The disk emulation evokes a dropout process (timer counter is decrementing) which begins after de-energization. This process corresponds to the reset of a Ferraris disk (explaining its denomination "disk emulation"). In case several faults occur in succession, the "history" is taken into consideration due to the inertia of the Ferraris disk and the time response is adapted. Reset begins as soon as 90 % of the setting value is undershot, in accordance to the dropout curve of the selected characteristic. In the range between the dropout value (95 % of the pickup value) and 90 % of the setting value, the incrementing and the decrementing processes are in idle state. Disk emulation offers advantages when the overcurrent relay elements must be coordinated with conventional electromechanical overcurrent relays located towards the source. 64 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 2.2.5 Inverse Time Overcurrent Protection 51V (Voltage-controlled / Voltagerestraint) Undervoltage Consideration The inverse time overcurrent protection is provided with an undervoltage detection that can be disabled (address 1223 VOLT. INFLUENCE). This function can influence overcurrent detection by means of two different methods: * Voltage-controlled: If a set voltage threshold is undershot, the overcurrent element is released. * Voltage-restraint: The pickup threshold of the overcurrent element depends on the voltage magnitude. A lower voltage decreases the current pickup value (see Figure 2-13). In the range between V/VNom = 1.00 to 0.25 a linear, directly proportional dependence is realized, and therefore the following applies: [spannungsabhaengigkeit-des-anregewertes, 1, en_US] Figure 2-12 Voltage influence of the pickup value The 51 PICKUP value is decreased proportional to the voltage decrease. Consequently, for constant current the / 51 PICKUP ratio is increased and the tripping time is reduced. Compared with the standard curves represented in Section "Technical Data" the tripping curve shifts to the left side as the voltage decreases. Switching to the lower pickup value or decreasing the pickup threshold is carried out phase-selectively. The assignment of voltages to current-carrying phases is shown in the following table. Table 2-3 Controlling voltages in relation to the fault currents Strom Spannung A VA - VB B VB - VC C VC - VA In order to avoid an unwanted operation in case of a voltage transformer fault, a function blocking is implemented via a binary input controlled by the voltage transformer protection breaker as well as via the deviceinternal measuring voltage failure detection ("Fuse Failure Monitor"). The following two figures show the logic diagrams for the inverse time overcurrent protection with undervoltage consideration. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 65 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sjx_logic_51-phase-schleife-aktiv, 1, en_US] Figure 2-13 66 Logic diagram of the voltage-controlled inverse time overcurrent protection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sjx_logic_51-phase, 1, en_US] Figure 2-14 2.2.6 Logic diagram of the voltage-restraint inverse-time overcurrent protection Dynamic Cold Load Pickup Function It may be necessary to dynamically increase the pickup thresholds of the overcurrent protection if certain system components exhibit an increased power consumption when they are switched on after a long period of zero voltage (e.g. air-conditioning systems, heating installations, motors). Thus, a general increase of pickup thresholds can be avoided taking into consideration such starting conditions. This dynamic pickup value changeover fuction is common to all overcurrent elements and is described in Section 2.4 Dynamic Cold Load Pickup. The alternative pickup values can be set individually for each element of the time overcurrent protection. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 67 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 2.2.7 Inrush Restraint When the multi-functional protective relay with local control 7SJ80 is installed, for instance, to protect a power transformer, large magnetizing inrush currents will flow when the transformer is energized. These inrush currents may be several times the nominal transformer current, and, depending on the transformer size and design, may last from several tens of milliseconds to several seconds. Although pickup of the relay elements is based only on the fundamental harmonic component of the measured currents, false device pickup due to inrush is still a potential problem since, depending on the transformer size and design, the inrush current also comprises a large component of the fundamental. The 7SJ80 features an integrated inrush restraint function. It prevents the "normal" pickup of 50-1 or 51 relay elements (not 50-2 and 50-3) in the phases and the ground path of all directional and non-directional overcurrent relay elements. The same is true for the alternative pickup thresholds of the dynamic cold load pickup function. After detection of inrush currents above a pickup value, special inrush signals are generated. These signals also initiate fault annunciations and start the associated trip delay time. If inrush conditions are still present after the tripping time delay has elapsed, a corresponding message (....Timeout.") is output, but the overcurrent tripping is blocked (see also logic diagrams of time overcurrent elements, Figure 2-6 to Figure 2-11). Inrush current contains a relatively large second harmonic component (twice the nominal frequency) which is nearly absent during a fault current. The inrush restraint is based on the evaluation of the 2nd harmonic present in the inrush current. For frequency analysis, digital filters are used to conduct a Fourier analysis of all three phase currents and the ground current. Inrush current is recognized if the following conditions are fulfilled at the same time: * * * The harmonic content is larger than the setting value 2202 2nd HARMONIC (minimum 0.125 * Nom,sec); the currents do not exceed an upper limit value 2205 I Max; an exceeding of a threshold value via an inrush restraint of the blocked element takes place. In this case an inrush in the affected phase is recognized (annunciations 1840 to 1842 and 7558 InRush Gnd Det InRush Gnd Det", see Figure 2-15) and its blocking being carried out. Since quantitative analysis of the harmonic components cannot be completed until a full line period has been measured, pickup will generally be blocked by then. Therefore, assuming the inrush restraint feature is enabled, a pickup message will be delayed by a full line period if no closing process is present. On the other hand, trip delay times of the time overcurrent protection feature are started immediately even with the inrush restraint being enabled. Time delays continue running with inrush currents present. If inrush blocking drops out after the time delay has elapsed, tripping will occur immediately. Therefore, utilization of the inrush restraint feature will not result in any additional tripping delays. If a relay element drops out during inrush blocking, the associated time delay will reset. Cross Blocking Since inrush restraint operates individually for each phase, protection is ideal where a power transformer is energized into a single-phase fault and inrush currents are detected on a different healthy phase. However, the protection feature can be configured to allow that not only this phase element but also the remaining elements (including ground) are blocked (the so-called CROSS BLOCK function, address 2203) if the permissible harmonic component of the current is exceeded for only one phase. Please take into consideration that inrush currents flowing in the ground path will not cross-block tripping by the phase elements. Cross blocking is reset if there is no more inrush in any phase. Furthermore, the cross blocking function may also be limited to a particular time interval (address 2204 CROSS BLK TIMER). After expiry of this time interval, the cross blocking function will be disabled, even if inrush current is still present. The inrush restraint has an upper limit: Above this (via adjustable parameter 2205 I Max) current blocking is suppressed since a high-current fault is assumed in this case. The following figure shows the inrush restraint influence on the time overcurrent elements including crossblocking. 68 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N [7sj6x_einschaltstabilisierung-150502-kn, 1, en_US] Figure 2-15 2.2.8 Logic diagram for inrush restraint Pickup Logic and Tripping Logic The pickup annunciations of the individual phases (or ground) and the individual element are combined with each other in such a way that the phase information and the element that has picked up are issued. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 69 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N Table 2-4 Pickup Indications of Overcurrent Protection Internal indication Figure 50-3 A PU 50-2 A PU 50-1 A PU 51 A PU Figure 2-4 Figure 2-6 Figure 2-10 50-3 B PU 50-2 B PU 50-1 B PU 51 B PU Figure 2-4 Figure 2-6 Figure 2-10 50-3 C PU 50-2 C PU 50-1 C PU 51 C PU Figure 2-4 Figure 2-6 Figure 2-10 50N-3 PU 50N-2 PU 50N-1 PU 51N PU Figure 2-5 Figure 2-8 Figure 2-11 Output indication FNo. 50/51 Ph A PU 1762 50/51 Ph B PU 1763 50/51 Ph C PU 1764 50N/51NPickedup 1765 50-3 A PU 50-3 B PU 50-3 C PU 50-3 picked up 1767 50N-3 PU 50N-3 picked up 1768 50-2 A PU 50-2 B PU 50-2 C PU Figure 2-4 Figure 2-4 Figure 2-4 50-2 picked up 1800 50N-2 PU Figure 2-5 50N-2 picked up 1831 50-1 A PU 50-1 B PU 50-1 C PU Figure 2-6 Figure 2-6 Figure 2-6 50-1 picked up 1810 50N-1 PU Figure 2-5 50N-1 picked up 1834 51 A PU 51 B PU 51 C PU Figure 2-10 Figure 2-10 Figure 2-10 51 picked up 1820 51N PU Figure 2-11 51N picked up 50(N)/51(N) PU 1837 (All pickups) 1761 In the trip signals, the element which initiated the tripping is also indicated. 2.2.9 Two-phase Overcurrent Protection (Only Non-Directional) The 2-phase overcurrent protection functionality is used in isolated or grounded systems where interaction with existing 2-phase protection equipment is required. As an isolated or grounded system remains operational with a 1-phase ground fault, this protection serves to detect double ground faults with high ground fault currents. The respective feeder must be switched off only in this case. A 2-phase measurement is sufficient for this purpose. In order to ensure selectivity of the protection in this section of the system, only phases A and C are monitored. If 250 50/51 2-ph prot (settable in P.System Data 1) is set to ON, B is not used for threshold comparison. If the fault is a simple ground fault in B, the element will not pick up. A double ground fault is assumed only after pickup on A or C, causing the element to pick up and trip after the delay time has elapsed. 70 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N i NOTE With inrush detection activated and inrush only on B, no cross blocking will take place in the other phases. On the other hand, if inrush with cross blocking is activated on A or C, B will also be blocked. 2.2.10 Fast Busbar Protection Using Reverse Interlocking Application Example Each of the current elements can be blocked via binary inputs. A setting parameter determines whether the binary input operates in the normally open (i.e. actuated when energized) or the normally closed (i.e. actuated when de-energized) mode. This allows fast busbar protection to be applied in star systems or open ring systems by applying "reverse interlocking". This principle is often used, for example, in distribution systems, auxiliary systems of power plants and similar systems, where a station supply transformer supplied from the transmission grid serves internal loads of the generation station via a medium voltage bus with multiple feeders (Figure 2-16). The reverse interlocking principle is based on the following: Time overcurrent protection of the busbar feeder trips with a short time delay T 50-2 independent of the grading times of the feeders, unless the pickup of the next load-side overcurrent protection element blocks the busbar protection (Figure 2-16). Always the protection element nearest to the fault will trip with the short time delay since this element cannot be blocked by a protection element located behind the fault. Time elements T 50-1 or T51 are still effective as backup element. Pickup signals output by the load-side protective relay are used as input message >BLOCK 50-2 via a binary input at the feeder-side protective relay. [rueckwverr-150502-kn, 1, en_US] Figure 2-16 Reverse interlocking protection scheme SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 71 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 2.2.11 Setting Notes General When selecting the time overcurrent protection in DIGSI, a dialog box appears with several tabs for setting the individual parameters. Depending on the functional scope specified during configuration of the protection functions under addresses 112 Charac. Phase and 113 Charac. Ground, the number of tabs can vary. If address FCT 50/51 was set to Definite Time, or Charac. Ground was set to Definite Time, then only the settings for the definite time elements are available. The selection of TOC IEC or TOC ANSI makes available additional inverse time characteristics. The superimposed high-set elements 50-2, 50-3 or 50N-2, 50N-3 are available in all these cases. Parameter 250 50/51 2-ph prot can also be set to activate two-phase overcurrent protection. Under address 1201 FCT 50/51, overcurrent protection for phases and under address 1301 FCT 50N/51N, the ground overcurrent protection can be switched ON or OFF. Pickup values, time delays, and characteristics for ground protection are set separately from the pickup values, time delays and characteristic curves associated with phase protection. Because of this, relay coordination for ground faults is independent of relay coordination for phase faults, and more sensitive settings can often be applied to directional ground protection. Depending on the setting of parameter 251 CT Connect., the device can also be used in specific system configuration with regard to current connections. Further information can be found under Section 2.1.3.2 Setting Notes, "Current Connections". Measurement Methods The comparison values to be used for the respective element can be set in the setting sheets for the elements. * Measurement of the fundamental harmonic (standard method): This measurement method processes the sampled values of the current and filters in numerical order the fundamental harmonic so that the higher harmonics or transient peak currents remain largely unconsidered. * Measurement of the true RMS value The current amplitude is derived from the sampled values in accordance with the definition equation of the true RMS value. This measurement method should be selected when higher harmonics are to be considered by the function (e.g. in capacitor banks). * Measurement with instantaneous values This procedure compares the instantaneous values to the set threshold. The element picks up at 2 * 2 * setting value (rms). It does not perform a mean-value calculation and is thus sensitive with regard to disturbances. This measurement method should only be selected if an especially short pickup time of the element is required. In this measurement procedure, the operating time of the element is reduced compared to the measurement of effective values or fundamental harmonics (see "Technical Data"). The type of the comparison values can be set under the following addresses: 50-3 element Address 1219 50-3 measurem. 50-2element Address 1220 50-2 measurem. 50-1 element Address 1221 50-1 measurem. 51 element Address 1222 51 measurem. 50N-3 element Address 1319 50N-3 measurem. 50N-2 element Address 1320 50N-2 measurem. 50N-1 element Address 1321 50N-1 measurem. 51Nelement Address 1322 51N measurem. High-set Current Elements 50-2, 50-3 (phases) The pickup current of the high-set element 50-2 PICKUP or50-3 PICKUP can be set at address 1202 or 1217. The corresponding delay time 50-2 DELAY or 50-3 DELAY can be configured under address 1203 or 72 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 1218. It is usually used for purposes of current grading intended for large impedances that are prevalent in transformers or generators. It is specified in such manner that it picks up faults up to this impedance. Example of the high-set current element 50-2 PICKUP: Transformer used for busbar supply with the following data: Rated apparent power SNomT = 16 MVA Transformer impedance Primary nominal voltage ZT = 10 % VNom1 = 110 kV Secondary nominal voltage VNom2 = 20 kV Vector groups Neutral point Fault power on 110 kV-side Dy 5 Grounded 1 GVA Based on the data above, the following fault currents are calculated: Three-Phase High Voltage Side Fault Current Three-Phase Low Voltage Side Fault Current On the High Voltage Side Flowing at 110 kV = 5250 A at 20 kV = 3928 A at 110 kV = 714 A The nominal current of the transformer is: NomT, 110 = 84 A (High Voltage Side) Current Transformer (High Voltage Side) Current Transformer (Low Voltage Side) NomT, 20 = 462 A (Low Voltage Side) 100 A/1 A 500 A/1 A Due to the following definition [hochstrom-260602-kn, 1, en_US] the following setting applies to the protection device: The 50-2 high-set current element must be set higher than the maximum fault current which is detected during a low side fault on the high side. To reduce fault probability as much as possible even when fault power varies, the following setting is selected in primary values: 50-2 /Nom = 10, i.e. 50-2 = 1000 A. The same applies analogously when using the high-set element 50-3. Increased inrush currents, if their fundamental component exceeds the setting value, are rendered harmless by delay times (address 1203 50-2 DELAY or 1218 50-3 DELAY). The principle of the "reverse interlocking" utilizes the multi-element function of the time overcurrent protection: Element 50-2 PICKUP is applied as a fast busbar protection with a shorter safety delay time 50-2 DELAY (e.g. 100 ms). For faults at the outgoing feeders, element 50-2 is blocked. The elements 50-1 or 51 serve as backup protection. The pickup values of both elements (50-1 PICKUP or 51 PICKUP and 50-2 PICKUP) are set equal. The delay time 50-1 DELAY or 51 TIME DIAL is set in such manner that it overgrades the delay for the outgoing feeders. The selected time is an additional delay time and does not include the operating time (measuring time, dropout time). The delay can also be set to . In this case, the element will not trip after pickup. However, pickup, will be signaled. If the 50-2 element or the 50-3 element is not required at all, the pickup threshold 50-2 or 50-3 is set to . This setting prevents tripping and the generation of a pickup message. High-set Current Elements 50N-2, 50N-3 (ground) The pickup current of the high-set element 50N-2 PICKUP or 50N-3 PICKUP can be set at address 1302 or 1317. The corresponding delay time 50N-2 DELAY or 50N-3 DELAY can be configured under address 1303 or 1318. The same considerations apply to these settings as they did for phase currents discussed earlier. The selected time is an additional delay time and does not include the operating time (measuring time, dropout time). The delay can also be set to . In this case, the element will not trip after pickup. However, SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 73 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N pickup, will be signaled. If the 50N-2 element or 50N-3 element is not required at all, the pickup threshold 50N-2 or 50N-3 should be set to . This setting prevents tripping and the generation of a pickup message. 50-1 Element (phases) For setting the 50-1 element, it is the maximum anticipated load current that must be considered above all. Pickup due to overload should never occur since in this mode the device operates as fault protection with correspondingly short tripping times and not as overload protection. For this reason, a setting equal to 20% of the expected peak load is recommended for line protection, and a setting equal to 40% is recommended for transformers and motors. The settable time delay (address 1205 50-1 DELAY) results from the grading coordination chart defined for the system. The selected time is an additional delay time and does not include the operating time (measuring time, dropout time). The delay can also be set to . In this case, the element will not trip after pickup. However, pickup, will be signaled. If the 50-1 element is not required at all, then the pickup threshold 50-1 should be set to . This setting prevents tripping and the generation of a pickup message. 50N-1 Element (ground) The 50N-1 element is normally set based on minimum ground fault current. If the relay is used to protect transformers or motors with large inrush currents, the inrush restraint feature of 7SJ80 may be used for the 50N-1 relay element. It can be enabled or disabled for both the phase current and the ground current in address 2201 INRUSH REST.. The characteristic values of the inrush restraint are listed in Subsection "Inrush Restraint". The settable delay time (address 1305 50N-1 DELAY) results from the time coordination chart defined for the system. For ground currents in a grounded system a separate coordination timer with short time delays can be applied. The selected time is an additional delay time and does not include the operating time (measuring time, dropout time). The delay can also be set to . In this case, the element will not trip after pickup. However, pickup, will be signaled. If the 50N-1 element is not required at all, the pickup threshold 50N-1 PICKUP should be set to . This setting prevents tripping and the generation of a pickup message. Pickup Stabilization (Definite Time) The configurable dropout times 1215 50 T DROP-OUT or 1315 50N T DROP-OUT can be set to implement a uniform dropout behavior when using electromechanical relays. This is necessary for a time grading. The dropout time of the electromechanical relay must be known to this end. Subtract the dropout time of the device (see Technical Data) from this value and enter the result in the parameters. 51 Element (phases) with IEC or ANSI characteristics Having set address 112 Charac. Phase = TOC IEC or TOC ANSI when configuring the protection functions (Section 2.1.1.2 Setting Notes), the parameters for the inverse time characteristics will also be available. If address 112 Charac. Phase was set to TOC IEC, you can select the desired IEC characteristic (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse) at address 1211 51 IEC CURVE. If address 112 Charac. Phase was set to TOC ANSI, you can select the desired ANSI characteristic (Very Inverse, Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. or Definite Inv.) at address 1212 51 ANSI CURVE. If the inverse time trip characteristic is selected, it must be noted that a safety factor of about 1.1 has already been included between the pickup value and the setting value. This means that a pickup will only occur if a current of about 1.1 times the setting value is present. If Disk Emulation was selected at address 1210 51 Drop-out, reset will occur in accordance with the reset curve as described before. The current value is set in address 1207 51 PICKUP. The setting is mainly determined by the maximum anticipated operating current. Pickup due to overload should never occur since in this mode, the device operates as fault protection with correspondingly short tripping times and not as overload protection. The corresponding time multiplier for an IEC characteristic is set at address 1208 51 TIME DIAL and in address 1209 51 TIME DIAL for an ANSI characteristic. It must be coordinated with the time coordination chart of the system. 74 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N The time multiplier can also be set to . In this case, the element will not trip after pickup. However, pickup will be signaled. If the 51 element is not required at all, address 112 Charac. Phase should be set to Definite Time during protection function configuration (see Section 2.1.1.2 Setting Notes). If highly sensitive settings close to the load current are required in weak power systems or transformers, the element can be stabilized via the undervoltage as an additional criterion for the power system fault. The operating modes can be set in address 1223 VOLT. INFLUENCE. In a voltage-controlled operation, the voltage threshold is defined via parameter 1224 51V V< below which the current element is released 51N Element (ground) with IEC or ANSI Characteristics Having set address 113 Charac. Ground = TOC IEC when configuring the protection functions (Section 2.1.1 Functional Scope), the parameters for the inverse time characteristics will also be available. Specify in address 113 Charac. Ground = TOC IEC the desired IEC characteristic (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse). If address 113 Charac. Ground = TOC ANSI, you can select the desired ANSI characteristic (Very Inverse, Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. or Definite Inv.) in address 1312 51N ANSI CURVE. If the inverse time trip characteristic is selected, it must be noted that a safety factor of about 1.1 has already been included between the pickup value and the setting value. This means that a pickup will only occur if a current of about 1.1 times the setting value is present. If Disk Emulation was selected at address 1310 51 Drop-out, reset will occur in accordance with the reset curve as described before. The current value is set in address 1307 51N PICKUP. The setting is mainly determined by the minimum anticipated ground fault current. The corresponding time multiplier for an IEC characteristic is set at address 1308 51N TIME DIAL and at address 1309 51N TIME DIAL for an ANSI characteristic. This has to be coordinated with the grading coordination chart of the network. For ground currents with grounded network, you can often set up a separate grading coordination chart with shorter delay times. The time multiplier can also be set to . In this case, the element will not trip after pickup. However, pickup will be signaled. If the 51N-TOC elementt is not required at all, address 113 Charac. Ground should be set to Definite Time during configuration of the protection functions (see Section 2.1.1 Functional Scope). Inrush Restraint When applying the protection device to transformers where high inrush currents are to be expected, the 7SJ80 can make use of an inrush restraint function for the overcurrent elements 50-1, 51, 50N-1 and 51N. Inrush restraint is only effective and accessible if address 122 InrushRestraint was set to Enabled. If this function is not required, then Disabled is set. In address 2201 INRUSH REST., the function is switched ON or OFF jointly for the overcurrent elements 50-1 PICKUP,51 PICKUP, 50N-1 PICKUP and 51N PICKUP The inrush restraint is based on the evaluation of the 2nd harmonic present in the inrush current. Upon delivery from the factory, a ratio 2f/f of 15 % is set. Under normal circumstances, this setting will not need to be changed. The setting value is identical for all phases and ground. However, the component required for restraint may be adjusted to system conditions in address 2202 2nd HARMONIC. To provide more restraint in exceptional cases, where energizing conditions are particularly unfavorable, a smaller value can be set in the aforementioned address, e.g. 12 %. Irrespective of parameter 2202 2nd HARMONIC, rush blocking will only occur if the absolute value of the 2nd harmonic is at least 0.125 * INom,sec. The effective duration of the cross-blocking 2203 CROSS BLK TIMER can be set to a value between 0 s (harmonic restraint active for each phase individually) and a maximum of 180 s (harmonic restraint of a phase blocks also the other phases for the specified duration). If the current exceeds the value set in address 2205 I Max, no further restraint will take place for the 2nd harmonic. Manual Close Mode (phases ground) When a circuit breaker is closed onto a faulted line, a high-speed trip by the circuit breaker is usually desired. For overcurrent or high-set element the delay may be bypassed via a Manual Close pulse, thus resulting in instantaneous tripping. The internal "Manual close" signal is built from the binary input signal >Manual Close (no. 356). The internal "Manual close" signal remains active as long as the binary input signal >Manual Close is active, but at least for 300 ms (see the following logic diagram). To enable the device to react properly on SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 75 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N occurrence of a fault in the phase element, address 1213 MANUAL CLOSE has to be set accordingly. Correspondingly, address 1313 MANUAL CLOSE is considered for the ground path address. Thus, the user determines for both elements, the phase and the ground element, what pickup value is active with what delay when the circuit breaker is closed manually. [lo_7sj6-hand-ein, 1, en_US] Figure 2-17 Manual close feature External Control Command If the manual close signal is not sent from 7SJ80 device, i.e. neither via the built-in operator interface nor via a serial interface, but directly from a control acknowledgment switch, this signal must be passed to a 7SJ80 binary input, and configured accordingly (>Manual Close), so that the element selected for MANUAL CLOSE can become effective. The alternative Inactive means that all elements operate as per configuration even with manual close and do not get special treatment. Internal Control Function If the manual close signal is sent via the internal control function of the device, an internal connection of information has to be established via CFC (interlocking task level) using the CMD_Information block (see Figure 2-18). [handein-260602-kn, 1, en_US] Figure 2-18 i Example for the generation of a manual close signal using the internal control function NOTE For an interaction between the automatic reclosing function (79 AR) and the control function, an extended CFC logic is necessary. See margin heading "Close command: Directly or via Control" in the Setting Notes of the automatic reclosing function (Section 2.15.6 Setting Notes). Interaction with the Automatic Reclosing Function (phases) If reclosing follows, high-speed and simultaneous protection against faults with 50-2 or 50-3 is usually desired. If the fault still exists after the first reclosing, the 50-1 or the 51 element will be initiated with graded tripping times, that is, element 50-2 or 50-3 will be blocked. You can use the parameters 1214 50-2 active or 1216 50-3 active active for this purpose to define whether or not the 50-2 or the 50-3 element is impacted by a release signal of the internal or an external automatic reclosing system. The setting with 79 active means that the 50-2 or the 50-3 element will only be released if automatic reclosing is not blocked. If this is not desired, the setting Always is selected so that the 50-2 or the 50-3 element is always active. The integrated automatic reclosing function of 7SJ80 also provides the option to individually determine for each overcurrent element whether tripping or blocking is to be carried out instantaneously or unaffected by the AR with the set time delay (see Section 2.15 Automatic Reclosing System 79). Interaction with the Automatic Reclosing Function (ground) When reclosing occurs, it is desirable to have high-speed protection against faults with 50N-2 or 50N-3. If the fault still exists after the first reclosing, the 50N-1 or the 51N element will be initiated with coordinated tripping times, that is, element 50N-2 or 50N-3 will be blocked. At address 1314 50N-2 active or 1316 50N-3 active active it can be specified whether the 50N-2 or the 50N-3 element should be influenced by the 76 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N release signal of an internal or external automatic reclosing system. Address with 79 active determines that the 50N-2 or the 50N-3 element will only operate if automatic reclosing is not blocked. If not desired, select the setting Always so that the 50N-2 or the 50N-3 element will always operate, as configured. The integrated automatic reclosing function of 7SJ62/64 also provides the option to individually determine for each overcurrent element whether tripping or blocking is to be carried out instantaneously or unaffected by the AR with the set time delay (see Section 2.15 Automatic Reclosing System 79). 2.2.12 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 1201 FCT 50/51 1202 50-2 PICKUP 1203 50-2 DELAY 1204 50-1 PICKUP 1205 50-1 DELAY 1207 51 PICKUP 1208 51 TIME DIAL 1209 1210 C Setting Options Default Setting Comments ON OFF ON 50, 51 Phase Time Overcurrent 1A 0.10 .. 35.00 A; 4.00 A 50-2 Pickup 5A 0.50 .. 175.00 A; 20.00 A 0.00 .. 60.00 sec; 0.00 sec 50-2 Time Delay 1A 0.10 .. 35.00 A; 1.00 A 50-1 Pickup 5A 0.50 .. 175.00 A; 5.00 A 0.00 .. 60.00 sec; 0.50 sec 50-1 Time Delay 1A 0.10 .. 4.00 A 1.00 A 51 Pickup 5A 0.50 .. 20.00 A 5.00 A 0.05 .. 3.20 sec; 0.50 sec 51 Time Dial 51 TIME DIAL 0.50 .. 15.00 ; 5.00 51 Time Dial 51 Drop-out Instantaneous Disk Emulation Disk Emulation Drop-out characteristic 1211 51 IEC CURVE Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1212 51 ANSI CURVE Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1213A MANUAL CLOSE 50-3 instant. 50-2 instant. 50 -1 instant. 51 instant. Inactive 50-2 instant. Manual Close Mode 1214A 50-2 active Always with 79 active Always 50-2 active 1215A 50 T DROP-OUT 0.00 .. 60.00 sec 0.00 sec 50 Drop-Out Time Delay 1216A 50-3 active Always with 79 active Always 50-3 active SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 77 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N Addr. Parameter C Setting Options Default Setting Comments 1217 50-3 PICKUP 1A 1.00 .. 35.00 A; A 50-3 Pickup 5A 5.00 .. 175.00 A; A 1218 50-3 DELAY 0.00 .. 60.00 sec; 0.00 sec 50-3 Time Delay 1219A 50-3 measurem. Fundamental True RMS Instantaneous Fundamental 50-3 measurement of 1220A 50-2 measurem. Fundamental True RMS Fundamental 50-2 measurement of 1221A 50-1 measurem. Fundamental True RMS Fundamental 50-1 measurement of 1222A 51 measurem. Fundamental True RMS Fundamental 51 measurement of 1223 VOLT. INFLUENCE NO Volt. controll. Volt. restraint NO 51V Voltage Influence 1224 51V V< 10.0 .. 125.0 V 75.0 V 51V V< Threshold for Release Ip 1301 FCT 50N/51N ON OFF ON 50N, 51N Ground Time Overcurrent 1302 50N-2 PICKUP 1A 0.05 .. 35.00 A; 0.50 A 50N-2 Pickup 5A 0.25 .. 175.00 A; 2.50 A 1303 50N-2 DELAY 1304 50N-1 PICKUP 0.00 .. 60.00 sec; 0.10 sec 50N-2 Time Delay 1A 0.05 .. 35.00 A; 0.20 A 50N-1 Pickup 1305 50N-1 DELAY 5A 0.25 .. 175.00 A; 1.00 A 0.00 .. 60.00 sec; 1307 51N PICKUP 0.50 sec 50N-1 Time Delay 1A 0.05 .. 4.00 A 0.20 A 51N Pickup 1308 51N TIME DIAL 5A 0.25 .. 20.00 A 1.00 A 0.05 .. 3.20 sec; 0.20 sec 51N Time Dial 1309 1310 51N TIME DIAL 0.50 .. 15.00 ; 5.00 51N Time Dial 51N Drop-out Instantaneous Disk Emulation Disk Emulation Drop-Out Characteristic 1311 51N IEC CURVE Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1312 51N ANSI CURVE Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1313A MANUAL CLOSE 50N-3 instant. 50N-2 instant. 50N-1 instant. 51N instant. Inactive 50N-2 instant. Manual Close Mode 78 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N Addr. Parameter 1314A C Setting Options Default Setting Comments 50N-2 active Always With 79 Active Always 50N-2 active 1315A 50N T DROP-OUT 0.00 .. 60.00 sec 0.00 sec 50N Drop-Out Time Delay 1316A 50N-3 active Always with 79 active Always 50N-3 active 1317 50N-3 PICKUP 0.25 .. 35.00 A; A 50N-3 Pickup 1318 50N-3 DELAY 0.00 .. 60.00 sec; 0.05 sec 50N-3 Time Delay 1319A 50N-3 measurem. Fundamental True RMS Instantaneous Fundamental 50N-3 measurement of 1320A 50N-2 measurem. Fundamental True RMS Fundamental 50N-2 measurement of 1321A 50N-1 measurem. Fundamental True RMS Fundamental 50N-1 measurement of 1322A 51N measurem. Fundamental True RMS Fundamental 51N measurement of 2201 INRUSH REST. OFF ON OFF Inrush Restraint 2202 2nd HARMONIC 10 .. 45 % 15 % 2nd. harmonic in % of fundamental 2203 CROSS BLOCK NO YES NO Cross Block 2204 CROSS BLK TIMER 2205 I Max 1A 0.00 .. 180.00 sec 0.00 sec Cross Block Time 1A 0.30 .. 25.00 A 7.50 A 5A 1.50 .. 125.00 A 37.50 A Maximum Current for Inrush Restraint 2.2.13 Information List No. Information Type of Information Comments 1704 >BLK 50/51 SP >BLOCK 50/51 1714 >BLK 50N/51N SP >BLOCK 50N/51N 1718 >BLOCK 50-3 SP >BLOCK 50-3 1719 >BLOCK 50N-3 SP >BLOCK 50N-3 1721 >BLOCK 50-2 SP >BLOCK 50-2 1722 >BLOCK 50-1 SP >BLOCK 50-1 1723 >BLOCK 51 SP >BLOCK 51 1724 >BLOCK 50N-2 SP >BLOCK 50N-2 1725 >BLOCK 50N-1 SP >BLOCK 50N-1 1726 >BLOCK 51N SP >BLOCK 51N 1751 50/51 PH OFF OUT 50/51 O/C switched OFF 1752 50/51 PH BLK OUT 50/51 O/C is BLOCKED 1753 50/51 PH ACT OUT 50/51 O/C is ACTIVE 1756 50N/51N OFF OUT 50N/51N is OFF 1757 50N/51N BLK OUT 50N/51N is BLOCKED 1758 50N/51N ACT OUT 50N/51N is ACTIVE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 79 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N No. Information Type of Information Comments 1761 50(N)/51(N) PU OUT 50(N)/51(N) O/C PICKUP 1762 50/51 Ph A PU OUT 50/51 Phase A picked up 1763 50/51 Ph B PU OUT 50/51 Phase B picked up 1764 50/51 Ph C PU OUT 50/51 Phase C picked up 1765 50N/51NPickedup OUT 50N/51N picked up 1767 50-3 picked up OUT 50-3 picked up 1768 50N-3 picked up OUT 50N-3 picked up 1769 50-3 TRIP OUT 50-3 TRIP 1770 50N-3 TRIP OUT 50N-3 TRIP 1787 50-3 TimeOut OUT 50-3 TimeOut 1788 50N-3 TimeOut OUT 50N-3 TimeOut 1791 50(N)/51(N)TRIP OUT 50(N)/51(N) TRIP 1800 50-2 picked up OUT 50-2 picked up 1804 50-2 TimeOut OUT 50-2 Time Out 1805 50-2 TRIP OUT 50-2 TRIP 1810 50-1 picked up OUT 50-1 picked up 1814 50-1 TimeOut OUT 50-1 Time Out 1815 50-1 TRIP OUT 50-1 TRIP 1820 51 picked up OUT 51 picked up 1824 51 Time Out OUT 51 Time Out 1825 51 TRIP OUT 51 TRIP 1831 50N-2 picked up OUT 50N-2 picked up 1832 50N-2 TimeOut OUT 50N-2 Time Out 1833 50N-2 TRIP OUT 50N-2 TRIP 1834 50N-1 picked up OUT 50N-1 picked up 1835 50N-1 TimeOut OUT 50N-1 Time Out 1836 50N-1 TRIP OUT 50N-1 TRIP 1837 51N picked up OUT 51N picked up 1838 51N TimeOut OUT 51N Time Out 1839 51N TRIP OUT 51N TRIP 1840 PhA InrushDet OUT Phase A inrush detection 1841 PhB InrushDet OUT Phase B inrush detection 1842 PhC InrushDet OUT Phase C inrush detection 1843 INRUSH X-BLK OUT Cross blk: PhX blocked PhY 1851 50-1 BLOCKED OUT 50-1 BLOCKED 1852 50-2 BLOCKED OUT 50-2 BLOCKED 1853 50N-1 BLOCKED OUT 50N-1 BLOCKED 1854 50N-2 BLOCKED OUT 50N-2 BLOCKED 1855 51 BLOCKED OUT 51 BLOCKED 1856 51N BLOCKED OUT 51N BLOCKED 1866 51 Disk Pickup OUT 51 Disk emulation Pickup 1867 51N Disk Pickup OUT 51N Disk emulation picked up 7551 50-1 InRushPU OUT 50-1 InRush picked up 7552 50N-1 InRushPU OUT 50N-1 InRush picked up 7553 51 InRushPU OUT 51 InRush picked up 80 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N No. Information Type of Information Comments 7554 51N InRushPU OUT 51N InRush picked up 7556 InRush OFF OUT InRush OFF 7557 InRush BLK OUT InRush BLOCKED 7558 InRush Gnd Det OUT InRush Ground detected 7559 67-1 InRushPU OUT 67-1 InRush picked up 7560 67N-1 InRushPU OUT 67N-1 InRush picked up 7561 67-TOC InRushPU OUT 67-TOC InRush picked up 7562 67N-TOCInRushPU OUT 67N-TOC InRush picked up 7563 >BLOCK InRush SP >BLOCK InRush 7564 Gnd InRush PU OUT Ground InRush picked up 7565 Ia InRush PU OUT Phase A InRush picked up 7566 Ib InRush PU OUT Phase B InRush picked up 7567 Ic InRush PU OUT Phase C InRush picked up 10034 50-3 BLOCKED OUT 50-3 BLOCKED 10035 50N-3 BLOCKED OUT 50N-3 BLOCKED SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 81 Functions 2.3 Directional Overcurrent Protection 67, 67N 2.3 Directional Overcurrent Protection 67, 67N The directional time overcurrent protection comprises three elements each for phase currents and the ground current that can operate directional or non-directional. All elements are independent of each other and can be combined as desired. High current element 67-2 and overcurrent element 67-1 always operate with a definite tripping time, the third element 67-TOC always operates with inverse tripping time. Applications 2.3.1 * The directional overcurrent protection allows the application of multifunctional protection devices 7SJ80 also in systems where protection coordination depends on knowing both the magnitude of the fault current and the direction of power flow to the fault location. * The non-directional overcurrent protection described in Section 2.2 Overcurrent Protection 50, 51, 50N, 51N may operate as overlapping backup protection or may be disabled. Additionally, individual elements (e.g. 67-2 and/or 67N-2) may be interconnected with the directional overcurrent protection. * For parallel lines or transformers supplied from a single source, only directional overcurrent protection allows selective fault detection. * For line sections supplied from two sources or in ring-operated lines, the overcurrent protection has to be supplemented by the element-specific directional criterion. General For parallel lines or transformers supplied from a single source (see Figure 2-19), the second feeder (II) is opened on occurrence of a fault in the first feeder (I) if tripping of the breaker in the parallel feeder is not prevented by a directional measuring element (at B). Therefore, where indicated with an arrow (Figure 2-19), directional overcurrent protection is applied. Please ensure that the "forward" direction of the protection element is in the direction of the line (or object to be protected). This is not necessarily identical with the direction of the normal load flow, as shown in Figure 2-19. [ueberstromzeitschutz-bei-paralleltransformatoren-020626-kn, 1, en_US] Figure 2-19 82 Overcurrent protection for parallel transformers SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N For line sections supplied from two sources or in ring-operated lines, the overcurrent protection has to be supplemented by the directional criterion. Figure 2-20 shows a ring system where both energy sources are merged to one single source. [zweiseitig-gespeister-leitungszug-260602-kn, 1, en_US] Figure 2-20 Transmission lines with sources at both ends Depending on the setting of parameter 613 50N/51N/67N w., the ground current element can operate either with measured values IN or with the values 3I0 calculated from the three phase currents. Devices featuring a sensitive ground current input, however, use the calculated quantity 3I0. The directional orientation Forward, Reverse or Non-Directional can be set individually for each element (Non-Directional from V4.7 on). For each element the time can be blocked via binary input or automatic reclosing (cycle-dependent), thus suppressing the trip command. Removal of blocking during pickup will restart time delays. The Manual Close signal is an exception. If a circuit breaker is manually closed onto a fault, it can be re-opened immediately. For overcurrent elements or high-set elements the delay may be bypassed via a Manual Close pulse, thus resulting in high-speed tripping. Furthermore, immediate tripping may be initiated in conjunction with the automatic reclosing function (cycle dependant). Pickup stabilization for the 67/67N elements of the directional overcurrent protection can be accomplished by means of settable dropout times. This protection comes into use in systems where intermittent faults occur. Combined with electromechanical relays, it allows different dropout responses to be adjusted and a time grading of digital and electromechanical relays to be implemented. Pickup and delay settings may be quickly adjusted to system requirements via dynamic setting switching (see Section 2.4 Dynamic Cold Load Pickup). Utilizing the inrush restraint feature tripping may be blocked by the 67-1, 67-TOC, 67N-1, and 67N-TOC elements in phases and ground path when inrush current is detected. The following table gives an overview of these interconnections to other functions of the 7SJ80 devices. Table 2-5 Interconnection to other functions Directional Time Overcurrent Protection Elements Connection to Automatic Reclosing Manual CLOSE Dynamic Cold Load Pickup Inrush Restraint 67-1 * * * 67-2 * * * 67-3 * * * 67-TOC * * * * 67N-1 * * * * 67N-2 * * * SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 * 83 Functions 2.3 Directional Overcurrent Protection 67, 67N Directional Time Overcurrent Protection Elements 2.3.2 Connection to Automatic Reclosing Manual CLOSE Dynamic Cold Load Pickup 67N-3 * * * 67N-TOC * * * Inrush Restraint * Definite Time Directional High-set Elements 67-2, 67N-2, 67-3, 67N-3 For each element an individual pickup value 67-2 PICKUP, 67-3 PICKUP or 67N-2 PICKUP, 67N-3 PICKUP is set which can be measured as Fundamental or True RMS. Each phase current and the ground current is compared with the common pickup value for each element 67-2 PICKUP, 67-3 PICKUP or 67N-2 PICKUP, 67N-3 PICKUP, and it is signaled when the value is exceeded provided that the fault direction is the same as the parameterized direction. After the associated delay times 67-2 DELAY, 67-3 DELAY or 67N-2 DELAY, 67N-3 DELAY have expired, the tripping commands are initiated which are equally available separately for each element. The dropout value is approximately 95% of the pickup value for currents > 0.3 Nom. Pickup can be stabilized by setting dropout times 1518 67 T DROP-OUT or 1618 67N T DROP-OUT. This time is started and maintains the pickup condition if the current falls below the threshold. Therefore, the function does not drop out instantaneously. The trip delay times 50-2 DELAY, 67-3 DELAY or 50N-2 DELAY, 67N-3 DELAY continue during that time. After the dropout delay time has elapsed, the pickup is reported OFF and the trip delay time is reset unless the threshold 50-2 PICKUP, 67-3 PICKUP or 50N-2 PICKUP, 67N-3 PICKUP has been exceeded again. If the threshold is exceeded again during the dropout delay time, the time is canceled. The trip delay time 50-2 DELAY, 67-3 DELAY or 50N-2 DELAY, 67N-3 DELAY continues. If the threshold value is exceeded after this time has elapsed, the trip command is issued immediately. If the threshold value is not exceeded at this time, there is no reaction. If the threshold value is exceeded again after expiry of the trip command delay time, while the dropout delay time is still running, tripping is initiated immediately. Each of these elements can be directional or non-directional (non-directional from V4.7 on). These elements can be blocked by the automatic reclosing function (79 AR). The following figure gives an example of the logic diagram for the high-set elements 67-2 of the phase currents. The high-set element 67-3 is structured identically. 84 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N [7sj6x_gerueberstromzeit_hochstromst-030903-he, 1, en_US] Figure 2-21 Logic diagram for directional high-set element 67-2 for phases If parameter MANUAL CLOSE is set to 67-2 instant. or 67-3 instant. and manual close detection is present, a pickup causes instantaneous tripping even if the element is blocked via binary input. The same applies to 79 AR 67-2 or 79 AR 67-3 instantaneous. 2.3.3 Definite Time, Directional Time Overcurrent Elements 67-1, 67N-1 For each element, an individual pickup value 67-1 PICKUP or 67N-1 PICKUP is set which can be measured as Fundamental or True RMS. Phase and ground currents are compared separately with the common setting value 67-1 PICKUP or 67N-1 PICKUP. Currents above the setting values are recognized separately when fault direction is equal to the configured direction. If the inrush restraint function is used, either the normal pickup signals or the corresponding inrush signals are issued as long as inrush current is detected. When the relevant delay times 67-1 DELAY, 67N-1 DELAY have expired, a tripping command is issued SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 85 Functions 2.3 Directional Overcurrent Protection 67, 67N unless an inrush has been recognized or inrush restraint is active. If the inrush restraint feature is enabled, and an inrush condition exists, no tripping takes place, but a message is recorded and displayed indicating when the overcurrent element time delay elapses. Trip signals and other flags for each element are issued when the element times out. The dropout value is roughly equal to 95% of the pickup value for currents > 0.3 Nom. Pickup can be stabilized by setting dropout times 1518 67 T DROP-OUT or 1618 67N T DROP-OUT. This time is started and maintains the pickup condition if the current falls below the threshold. Therefore, the function does not drop out at high speed. The trip-command delay time 50-1 DELAY or 50N-1 DELAY continues in the meantime. After the dropout delay time has elapsed, the pickup is reported OFF and the trip delay time is reset unless the threshold 50-1 PICKUP or 50N-1 PICKUP has been exceeded again. If the threshold is exceeded again during the dropout delay time, the time is canceled. The trip-command delay time 50-1 DELAY or 50N-1 DELAY continues in the meantime. Should the threshold value be exceeded after its expiry, the trip command is issued immediately. If the threshold value is not exceeded at this time, there will be no reaction. If the threshold value is exceeded again after expiry of the trip-command delay time, while the dropout delay time is still running, tripping occurs immediately. The inrush restraint of the overcurrent elements 50-1 PICKUP or 50N-1 PICKUP is disabled via configurable dropout times if an inrush pickup occurs, because the occurrence of an inrush does not constitute an intermittent fault. Each of these elements can be directional or non-directional (non-directional from V4.7 on). These elements can be blocked by the automatic reclosure function (AR). The following figure shows by way of an example the logic diagram for the directional overcurrent element 67-1. 86 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N [7sj6x_gerueberstromzeit_ueberstromst-030903-he, 1, en_US] Figure 2-22 Logic diagram for the directional relay element 67-1 for phases If parameter MANUAL CLOSE is set to 67-1 instant. and manual close detection is present, a pickup causes instantaneous tripping even if the element is blocked via binary input. The same applies to 79 AR 67-1 instantaneous. The dropout delay does only function if no inrush was detected. An approaching inrush resets an already running dropout time delay. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 87 Functions 2.3 Directional Overcurrent Protection 67, 67N [7sj6x_gerrueckfallverzoegerung_i_gr_ph, 1, en_US] Figure 2-23 2.3.4 Logic of the dropout delay for 67-1 Inverse Time, Directional Overcurrent Elements 67-TOC, 67N-TOC Inverse time elements are dependent on the variant ordered. They operate either according to the IEC- or the ANSI-standard. The characteristics and associated formulas are identical with those of the non-directional overcurrent protection and are given in the Technical Data. When the inverse time curves are configured, the definite time elements (67-2, 67-1) are also available. Pickup Behavior For each element, an individual pickup value 67-TOC PICKUP or 67N-TOC PICKUP is set which can be measured as Fundamental or True RMS. Each phase and ground current is separately compared with the common pickup value 67-TOC PICKUP or 67N-TOC PICKUP of each element. When a current value exceeds the corresponding setting value by a factor of 1.1, the corresponding phase picks up and a message is generated phase-selectively assuming that the fault direction is equal to the direction configured. If the inrush restraint feature is used, either the normal pickup signals or the corresponding inrush signals are issued as long as inrush current is detected. If the 67-TOC element picks up, the tripping time is calculated from the actual fault current flowing, using an integrating method of measurement. The calculated tripping time depends on the selected tripping curve. Once this time has elapsed, a trip signal is issued provided that no inrush current is detected or inrush restraint is disabled. If the inrush restraint feature is enabled and an inrush condition exists, no tripping takes place, but a message is recorded and displayed indicating when the overcurrent element time delay elapses. For ground current element 67N-TOC PICKUP, the characteristic may be selected independently of the characteristic used for phase currents. Pickup values of the 67-TOC (phases) and 67N-TOC (ground current) and the associated time multipliers may be set individually. Each of these elements can be directional or non-directional (non-directional from V4.7 on). Dropout Behavior When using an ANSI or IEC curve, it can be selected whether the dropout of an element is to occur instantaneously or whether dropout is to be performed by means of the disk emulation mechanism. "Instantaneously" means that pickup drops out when the pickup value of approx. 95 % of the set pickup value is undershot. For a new pickup, the time counter starts at zero. The disk emulation evokes a dropout process (time counter is decrementing) which begins after de-energization. This process corresponds to the reset of a Ferraris disk (explaining its denomination "disk emulation"). In case several faults occur in succession the "history" is taken into consideration due to the inertia of the Ferraris disk and the time response is adapted. Reset begins as soon as 90 % of the setting value is undershot, in accordance to the dropout curve of the selected characteristic. In the range between the dropout value (95 % of the pickup value) and 90 % of the setting value, the incrementing and the decrementing processes are in idle state. Disk emulation offers advantages when the overcurrent relay elements must be coordinated with conventional electromechanical overcurrent relays located towards the source. The following figure shows by way of an example the logic diagram for the 67-TOC relay element of the directional inverse time overcurrent protection of the phase currents. 88 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N [7sj6x_gerueberstromzeit_abh_ueberstrom_ip-150502-kn, 1, en_US] Figure 2-24 2.3.5 Logic diagram for the directional overcurrent protection: 67-TOC relay element Interaction with Fuse Failure Monitor (FFM) False or undesired tripping can be caused by a measuring voltage that can be caused by either short-circuit or broken wire in the voltage transformer's secondary system or an operation of the voltage transformer fuse. Failure of the measuring voltage in one or two phases can be detected, and the directional time overcurrent elements (Dir Phase and Dir Ground) can be blocked, see logic diagrams. Undervoltage protection, sensitive ground fault detection and synchronization are also blocked in this case. For additional information on the operation of the fuse failure monitor, see Section 2.11.1 Measurement Supervision. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 89 Functions 2.3 Directional Overcurrent Protection 67, 67N 2.3.6 Dynamic Cold Load Pickup Function It may be necessary to dynamically increase the pickup values of the directional time overcurrent protection if, at starting, certain elements of the system show an increased power consumption after a long period of zero voltage (e.g. air-conditioning systems, heating installations, motors). Thus, a general raise of pickup thresholds can be avoided taking into consideration such starting conditions. This dynamic pickup value changeover is common to all overcurrent elements and is described in Section 2.4 Dynamic Cold Load Pickup. The alternative pickup values can be set individually for each element of the directional and non-directional time overcurrent protection. 2.3.7 Inrush Restraint 7SJ80 features an integrated inrush restraint function. It prevents "normal" pickup of the 67-1 or 67-TOC elements (not 67-2 and 67-3) in the phases and in the ground path of the non-directional and directional overcurrent protection functions. The same is true for the alternative pickup thresholds of the dynamic cold load pickup function. If inrush currents are detected, special inrush pickup signals are generated. These signals also initiate fault recording and start the associated trip delay time. If inrush conditions are still present after the tripping time delay has elapsed, a corresponding message ("....TimeOut ") is output, but tripping is blocked (for further information see "Inrush Restraint" in Section 2.2 Overcurrent Protection 50, 51, 50N, 51N). 2.3.8 Determination of Direction The determination of the fault direction for the phase directional element and the ground directional element is performed independently. Basically, the direction determination is performed by determining the phase angle between the fault current and a reference voltage. Method of Directional Measurement For the phase directional element the fault current of the corresponding phase and the unfaulted phasetophase voltage are used as reference voltage. The unfaulted voltage also allows for a correct direction determination even if the fault voltage has collapsed entirely (short-line fault). In phase-to-ground voltage connections, the phase-to-phase voltages are calculated. In a connection of two phase-to-phase voltages and VN, the third phase-to-phase voltage is also calculated. With three-phase short-line faults, memory voltage values are used to clearly determine the direction if the measurement voltages are not sufficient.Upon the expiration of the storage time period (2 s), the detected direction is saved, as long as no sufficient measuring voltage is available. When closing onto a fault, if no memory voltage values exist in the buffer, the relay element will trip. In all other cases the voltage magnitude will be sufficient for determining the direction. For each directional ground element there are two possibilities of direction determination. Direction Determination with Zero-sequence System or Ground Quantities For the directional ground fault elements, the direction can be determined from the zero-sequence system quantities. In the current path, the N current is valid, when the transformer neutral current is connected to the device. Otherwise, the device calculates the ground current from the sum of the three phase currents. In the voltage path, the displacement voltage VN is used as reference voltage if connected. Otherwise the device calculates as reference voltage the zero-sequence voltage 3 * V0 from the sum of the three phase voltages. If the magnitude of V0 or 3 * V0 is not sufficient to determine the direction, the direction is undefined. Then the directional ground element will not initiate a trip signal. The directional ground element cannot be applied when only two current transformers are used. 90 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N Direction Determination with Negative Sequence System Here, the negative sequence current and as reference voltage the negative sequence voltage are used for the direction determination. This is advantageous if the zero sequence is influenced via a parallel line or if the zero voltage becomes very small due to unfavorable zero impedances. The negative sequence system is calculated from the individual voltages and currents. As with the use of the zero sequence values, a direction determination is carried out if the values necessary for the direction determination have exceeded a minimum threshold. Otherwise the direction is undetermined. When voltage transformers are open-delta-connected, direction determination is always based on the negative- sequence quantities. Cross-Polarized Reference Voltages for Direction Determination The direction of a phase-directional element is detected by means of a cross-polarized voltage. In a phase-toground fault, the cross-polarized voltage (reference voltage) is 90 out of phase with the fault voltages (see Figure 2-25). With phase-to-phase faults, the position of the reference voltages changes, depending on the degree of collapse of the fault voltages, up to 30. [kurzschlussfremde-spannungen-fuer-richtungsbestimmung-260602-kn, 1, en_US] Figure 2-25 Cross-polarized voltages for direction determination Measured Values for the Determination of Fault Direction Each phase has its own phase measuring element. The fourth measuring element is used as ground measuring element. If the current exceeds the pickup threshold of a phase or that of the ground path, direction determination is started by the associated measuring element. In case of a multiphase fault, all phase measuring elements involved perform their own direction determination. If one of the calculated directions differs from the set direction, the function picks up. The following table shows the allocation of measured values for the determination of fault direction for various causes of pickup. Measured Values for the Determination of Fault Direction Table 2-6 Pickup Measuring element A B C ground Current Voltage Current Voltage Current Voltage Current Voltage A A VB - VC -- -- -- -- -- -- B -- -- B VC - VA -- -- -- -- C -- -- -- -- C VA - VB -- -- N -- -- -- -- -- -- N VN 1) VB - VC -- -- -- -- N VN 1) A, N B, N -- -- B VC - VA -- -- N VN 1) C, N -- -- -- -- C VA - VB N VN 1) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 91 Functions 2.3 Directional Overcurrent Protection 67, 67N Pickup Measuring element A B Current Voltage A, B C ground Current Voltage Current Voltage Current Voltage A VB - VC B VC - VA -- -- -- -- B, C -- -- B VC - VA C VA - VB -- -- AC A VB - VC -- -- C VA - VB -- -- A, B, N A VB - VC B VC - VA -- -- N VN 1) B, C, N -- -- B VC - VA C VA - VB N VN 1) A, C, N A VB - VC -- -- C VA - VB N VN 1) A, B, C A VB - VC B VC - VA C VA - VB -- -- A, B, C, N A VB - VC B VC - VA C VA - VB N VN 1) 1) or 3 * V0 = |VA + VB + VC|, depending on the connection type of voltages Direction Determination of Directional Phase Elements As already mentioned, the direction determination is performed by determining the phase angle between the fault current and the reference voltage. In order to satisfy different network conditions and applications, the reference voltage can be rotated by an adjustable angle. In this way, the vector of the rotated reference voltage can be closely adjusted to the vector of the fault current in order to provide the best possible result for the direction determination. Figure 2-26 clearly shows the relationship for the directional phase element based on a single-phase ground fault in Phase A. The fault current scA follows the fault voltage by fault angle sc. The reference voltage, in this case VBC for the directional phase element A, is rotated by the setting value 1519 ROTATION ANGLE, positively counter-clockwise. In this case, a rotation by +45. [7sj6x_drehung-referenzspannung-phase-200904-he, 1, en_US] Figure 2-26 Rotation of the reference voltage, directional phase element The rotated reference voltage defines the forward and reverse area, see Figure 2-27. The forward area is a range of 86 around the rotated reference voltage Vref,rot If the vector of the fault current is in this area, the device detects forward direction. In the mirrored area, the device detects reverse direction. In the intermediate area, the direction result is undefined. In a network, the vector of the fault current is usually in the forward or reverse area. If the vector moves out of one these areas, e.g. the forward area, in direction of the undefined area, it leaves the forward area at Vref,rot 86 and reaches the undefined area. If the vector leaves the undefined area in direction of the forward area 92 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N (or reverse area), a hysteresis of 2 is added. This hysteresis prevents chattering of the directional result. The current vector reaches the forward area at 84 (= 86-2 hysteresis). [7sj6x_vorwaertscharakteristik-gumz-phase-220904-he, 1, en_US] Figure 2-27 Forward characteristic of the directional function, directional phase element Direction Determination of Directional Ground Element with Ground Values Figure 2-28 shows the treatment of the reference voltage for the directional ground element, also based on a single-phase ground fault in phase A. Contrary to the directional phase elements, which work with the unfaulted voltage as reference voltage, the fault voltage itself is the reference voltage for the directional ground element. Depending on the connection of the voltage transformer, this is the voltage 3V0 (as shown in Figure 2-28) or VN. The fault current -30 is phase offset by 180 to the fault current scA and follows the fault voltage 3V0 by fault angle sc. The reference voltage is rotated by the setting value 1619 ROTATION ANGLE. In this case, a rotation by -45. [7sj6x_drehung-referenzspannung-erde-nullsys-220904-he, 1, en_US] Figure 2-28 Rotation of the reference voltage, directional ground element with zero sequence values The forward area is also a range of 86 around the rotated reference voltage Vref, rot. If the vector of the fault current -0 (or N) is in this area, the device detects forward direction. Direction Determination of Directional Ground Element with Negative Sequence Values Figure 2-29 shows the treatment of the reference voltage for the directional ground element using the negative sequence values based on a single-phase ground fault in phase A. As reference voltage, the negative SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 93 Functions 2.3 Directional Overcurrent Protection 67, 67N sequence voltage is used, as current for the direction determination, the negative sequence system in which the fault current is displayed. The fault current -32 is in phase opposition to the fault current scA and follows the voltage 3V2 by the fault angle sc. The reference voltage is rotated through the setting value 1619 ROTATION ANGLE. In this case, a rotation of -45. [7sj6x_drehung-referenzspannung-erde-gegensys-220904-he, 1, en_US] Figure 2-29 Rotation of the reference voltage, directional ground element with negative sequence values The forward area is a range of 86 around the rotated reference voltage Vref, rot. If the vector of the negative sequence system current -32 is in this area, the device detects forward direction. 2.3.9 Reverse Interlocking for Double End Fed Lines Application Example The directionality feature of the directional overcurrent protection enables the user to perform reverse interlocking also on double end fed lines using relay element 67-1. It is designed to selectively isolate a faulty line section (e.g. sections of rings) in high speed, i.e. no long graded times will slow down the process. This scheme is feasible when the distance between protective relays is not too great and when pilot wires are available for signal transfer via an auxiliary voltage loop. For each line, a separate data transfer path is required to facilitate signal transmission in each direction. When implemented in a closed-circuit connection, disturbances in the communication line are detected and signalled with time delay. The local system requires a local interlocking bus wire similar to the one described in Subsection "Reverse Interlocking Bus Protection" for the directional overcurrent protection (Section 2.2 Overcurrent Protection 50, 51, 50N, 51N). During a line fault, the device that detects faults in forward (line) direction using the directional relay element 67-1 will block one of the non-directional overcurrent elements (50-1, 50-TOC) of devices in the reverse direction (at the same busbar) since they should not trip (Figure 2-30). In addition, a message is generated regarding the fault direction. "Forward" messages are issued when the current threshold of the directional relay element 67-1 is exceeded and directional determination is done. Subsequently, "forward" messages are transmitted to the device located in reverse direction. During a busbar fault, the device that detects faults in reverse (busbar) direction using the directional relay element 67-1 will block one of the non-directional overcurrent elements (50-1, 50-TOC) of devices at the opposite end of the same feeder. In addition, a "Reverse" message is generated and transmitted via the auxiliary voltage loop to the relay located at the opposite end of the line. 94 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N [selektivitaetdurchrueckwverr-260602-kn, 1, en_US] Figure 2-30 Reverse interlocking using directional elements The directional overcurrent element providing normal time grading operates as selective backup protection. The following figure shows the logic diagram for the generation of fault direction signals. [7sj6x-meld-gener-fehlerricht-20060118, 1, en_US] Figure 2-31 Logic diagram for the generation of fault direction signals 2.3.10 Setting Notes General When selecting the directional time overcurrent protection in DIGSI, a dialog box appears with several tabs for setting the associated parameters. Depending on the functional scope specified during configuration of the protective functions in addresses 115 67/67-TOC and 116 67N/67N-TOC, the number of tabs can vary. If 67/67-TOC or 67N/67N-TOC is set equal to Definite Time, only the parameters for definite time overcurrent protection are accessible here. If you select TOC IEC or TOC ANSI, the inverse time characteristics is available, too. The superimposed directional elements 67-3, 67-2 and 67-1or 67N-3, 67N-2 and 67N-1apply in all these cases. At address 1501 FCT 67/67-TOC, directional phase overcurrent protection may be switched ON or OFF. Pickup values, time delays, and characteristic are set separately for phase protection and ground protection. Because of this, relay coordination for ground faults is independent of relay coordination for phase faults, and more sensitive settings can often be applied to directional ground protection. Thus, at address 1601 FCT 67N/67N-TOC, directional ground time overcurrent protection may be switched ON or OFF independent of the directional phase time overcurrent protection. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 95 Functions 2.3 Directional Overcurrent Protection 67, 67N Depending on the parameter 613 50N/51N/67N w., the device can either operate using measured values IN or the quantities 3I0 calculated from the three phase currents. Devices featuring a sensitive ground current input generally use the calculated quantity 30. The directional orientation of the function is influenced by parameter 201 CT Starpoint (see Section 2.1.3 Power System Data 1). Measurement Methods The comparison values to be used for the respective element can be set in the setting sheets for the elements. Measurement of the Fundamental Harmonic (standard method): This measurement method processes the sampled values of the current and filters in numerical order the fundamental harmonic so that the higher harmonics or transient peak currents are rejected. * * Measurement of the True RMS Value The current amplitude is derived from the sampled value in accordance with the definition equation of the true RMS value. This measurement method should be selected when higher harmonics are to be considered by the function (e.g. in capacitor bank). The type of the comparison values can be set under the following addresses: 67-3 element Address 1527 67-3 MEASUREM. 67-2 element Address 1520 67-2 MEASUREM. 67-1 element Address 1521 67-1 MEASUREM. 67-TOC element Address 1522 67-TOC MEASUR. 67N-3 element Address 1627 67N-3 MEASUREM. 67N-2 element Address 1620 67N-2 MEASUREM. 67N-1 element Address 1621 67N-1 MEASUREM. 67N-TOC element Address 1622 67N-TOC MEASUR. Direction Characteristic The direction characteristic, i.e. the position of the ranges "forward"and "reverse" is set for the phase directional elements under address 1519 ROTATION ANGLE and for the ground directional element under address 1619 ROTATION ANGLE. The short-circuit angle is generally inductive in a range of 30 to 60. This means that usually the default settings of +45 for the phase directional elements and -45 for the ground directional element can be maintained for the adjustment of the reference voltage, as they guarantee a safe direction result. Nevertheless, the following contains some setting examples for special applications (Table 2-7). The following must be observed: With the phase directional elements, the reference voltage (fault-free voltage) for phaseground- faults is vertical on the short-circuit voltage. For this reason, the resulting setting of the angle of rotation is (see also Section 2.3.8 Determination of Direction): Ref. volt. angle of rotation = 90 - sc Phase directional element (phaseto-ground fault) With the ground directional element, the reference voltage is the short-circuit voltage itself. The resulting setting of the angle of rotation is then: Ref. volt. angle of rotation = -sc Directional ground element (phaseto-ground fault). It should also be noted for phase directional elements that with phase-to-phase faults, the reference voltage is rotated between 0 (remote fault) and 30 (close-up fault) depending on the collapse of the faulty voltage. This can be taken into account with a mean value of 15: Ref. volt. angle of rotation = 90 - sc -15 96 Phase directional element (phaseto-phase fault) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N Table 2-7 Setting examples Application 1) Power 2) With k typical Setting Directional Phase Element 1519 ROTATION ANGLE Setting Directional Ground Element 1619 ROTATION ANGLE 60 Bereich 30...0 15 -60 30 Bereich 60...30 45 -30 30 Bereich 60...30 45 -30 flow direction the assumption that these are cable lines Directional Orientation Directional overcurrent protection normally operates in the direction of the protected object (line, transformer, etc.). If the protection device is properly connected in accordance with one of the circuit diagrams in Appendix C Connection Examples, this is the "forward" direction. The directional orientation Forward or Reverse can be set separately for each element. Moreover, each element can also be operated Non-Directional. * * * * * * * * i Address 1526 67-3 Direction Address 1523 67-2 Direction Address 1524 67-1 Direction Address 1525 67-TOC Direct. Address 1626 67N-3 Direction Address 1623 67N-2 Direction Address 1624 67N-1 Direction Address 1625 67N-TOC Direct. NOTE If the threshold value of the 67-1 or 67N-1 element is exceeded, the phase-specific directional indications "forward" or "reverse" are output (indications 2628 to 2636), independent of whether the fault direction is the same as the configured direction. These indications are used for directional comparison protection. Quantity Selection for Direction Determination for the Directional Ground Element Parameter 1617 67N POLARIZAT.can be set to specify whether direction determination is accomplished from the zero sequence quantities or ground quantities (with VN and IN) or from the negative sequence SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 97 Functions 2.3 Directional Overcurrent Protection 67, 67N quantities (with V2 and I2) in the ground directional element. The first option is the preferential setting; the latter is to be selected in case of danger that the zero voltage be too small due to unfavourable zero impedance or that a parallel line influences the zero system. i NOTE If parameter 213 VT Connect. 3ph is set to Vab, Vbc, Vab, Vbc, VSyn or Vab, Vbc, Vx, the direction is always determined using the negative sequence values V2/2. For these voltage connection types the zero sequence voltage (VN or 3V0) is not available. Directional High-set Elements 67-2, 67-3 (phases) The high-current element 67-2 PICKUP or 67-3 PICKUP is set at address 1502 or 1528. The associated delay 67-2 DELAY or 67-3 DELAY at 1503 or 1529. For setting, the same considerations apply as did for the non-directional time overcurrent protection in Section 2.2.11 Setting Notes. The selected time is only an additional time delay and does not include the operating time (measuring time, dropout time). The delay can be set to . After pickup the element will then not trip. Pickup, however, will be signaled. If the 67-2 element or 67-3 element is not required at all, the pickup value 67-2 PICKUP or 67-3 PICKUP should be set to . For this setting, there is neither a pickup signal generated nor a trip. Directional High-set Elements 67-2, 67-3 (ground) The high-current element 67N-2 PICKUP or 67N-3 PICKUP is set at address 1602 or 1628. The associated delay 67N-2 DELAY or 67N-3 DELAY at 1603 or 1629. The same considerations apply for these settings as for the phase currents. The selected time is an additional delay time and does not include the operating time (measuring time, dropout time). If the delay time is set to , the element does not trip after the pickup, but the pickup condition is signaled. If the directional 67N-2 element or 67N-3 element is not required, set the pickup threshold 67N-2 PICKUP or 67N-3 PICKUP to . This setting prevents tripping and the generation of a pickup indication. Directional Overcurrent Element 67-1 (phases) The pickup value of the 67-1 element (67-1 PICKUP) address1504 should be set above the maximum anticipated load current. Pickup due to overload should never occur since in this mode the device operates as fault protection with correspondingly short tripping times and not as overload protection. For this reason, lines are set to approx. 20% above the maximum expected (over)load and transformers and motors to approx. 40%. If the relay is used to protect transformers or motors with large inrush currents, the inrush restraint feature of 7SJ80 may be used for the 67-1 element (for more information see margin heading "Inrush Restraint"). The delay for directional elements (address 1505 67-1 DELAY) is usually set shorter than the delay for nondirectional elements (address 1205) since the non-directional elements overlap the directional elements as backup protection. It should be based on the system coordination requirements for directional tripping. For parallel transformers supplied from a single source (see "Applications"), the delay of element 67-1 DELAY located on the load side of the transformers may be set to 0 without provoking negative impacts on selectivity. The selected time is only an additional time delay and does not include the operating time (measuring time, dropout time). The delay can be set to . After pickup the element will then not trip. Pickup, however, will be signaled. If the 67-1 element is not required at all, the pickup value 67-1 PICKUP should be set to . This setting prevents from tripping and the generation of a pickup message. Directional Overcurrent Element 67N-1 (ground) The pickup value of the 67N-1 overcurrent element(1604 67N-1 PICKUP)should be set below the minimum anticipated ground fault current. If the relay is used to protect transformers or motors with large inrush currents, the inrush restraint feature of 7SJ80 may be used for the 67N-1 relay element (67N-1 PICKUP) (for more information see margin heading "Inrush Restraint"). 98 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N The delay is set at address 1605 67N-1 DELAY and should be based on system coordination requirements for directional tripping. For ground currents in a grounded system a separate coordination chart with short time delay is often used. The selected time is only an additional time delay and does not include the operating time (measuring time, dropout time). The delay can be set to . After pickup the element will then not trip. Pickup, however, will be signaled. If the 67N-1 element is not required at all, the pickup value 67N-1 PICKUP should be set to . This setting prevents from tripping and the generation of a pickup message. Pickup Stabilization (67/67N Directional) The pickups can also be stabilized via parameterizable dropout times under address 1518 67 T DROP-OUT or 1618 67N T DROP-OUT. Directional Element 67-TOC with IEC or ANSI Curves (phases) Having set address 115 67/67-TOC = TOC IEC or TOC ANSI when configuring the protection functions (Section 2.1.1 Functional Scope), the parameters for the inverse time characteristics will also be available. If the relay is used to protect transformers or motors with large inrush currents, the inrush restraint function of 7SJ80 may be used for the 67-TOC element (67-TOC PICKUP) (for more information see margin heading "Inrush Restraint"). If the inverse time trip characteristic is selected, it must be noted that a safety factor of about 1.1 has already been included between the pickup value and the setting value. This means that a pickup will only occur if a current of about 1.1 times the setting value is present. If Address 1510 67-TOC Drop-out is set to Disk Emulation, reset will occur in accordance with the reset curve as described in Section 2.2 Overcurrent Protection 50, 51, 50N, 51N. The current value is set in address 1507 67-TOC PICKUP. The setting is mainly determined by the maximum operating current. 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. The corresponding element time multiplication factor for an IEC characteristic is set at address 1508 67 TIME DIAL and in address 1509 67 TIME DIAL for an ANSI characteristic. It must be coordinated with the time grading of the network. The time multiplier can also be set to . After pickup the element will then not trip. Pickup, however, will be signaled. If the 67-TOC element is not required at all, address 115 67/67-TOC should be set to Definite Time during protective function configuration (see Section 2.1.1 Functional Scope). If address 115 67/67-TOC = TOC IEC, you can specify the desired IEC-characteristic (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse) in address 1511 67- IEC CURVE. If address 115 67/67-TOC = TOC ANSI you can specify the desired ANSI-characteristic (Very Inverse, Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. oder Definite Inv.) in address 1512 67- ANSI CURVE. Directional Element 67N-TOC with IEC or ANSI Curves (ground) Having set address 116 67N/67N-TOC = TOC IEC when configuring the protection functions (Section 2.1.1 Functional Scope), the parameters for the inverse time characteristics will also be available. Specify in address 1611 67N-TOC IEC the desired IEC characteristic (Normal Inverse, Very Inverse, Extremely Inv. or Long Inverse). If address 116 67N/67N-TOC was set to TOC ANSI, you can select the desired ANSI characteristic (Very Inverse, Inverse, Short Inverse, Long Inverse, Moderately Inv., Extremely Inv. or Definite Inv.) in address 1612 67N-TOC ANSI. If the relay is used to protect transformers or motors with large inrush currents, the inrush restraint feature of 7SJ80 may be used for the 67N-TOC element (67N-TOC PICKUP) (for more information see margin heading "Inrush Restraint"). If the inverse time trip characteristic is selected, it must be noted that a safety factor of about 1.1 has already been included between the pickup value and the setting value 67N-TOC PICKUP. This means that a pickup will only occur if a current of about 1.1 times the setting value is present. If Disk Emulation was selected at address 1610 67N-TOC DropOut, reset will occur in accordance with the reset curve as for the existing nondirectional time overcurrent protection described in Section 2.2 Overcurrent Protection 50, 51, 50N, 51N. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 99 Functions 2.3 Directional Overcurrent Protection 67, 67N The current value is set at address 1607 67N-TOC PICKUP. The minimum appearing ground fault current is most relevant for this setting. The corresponding element time multiplication factor for an IEC characteristic is set at address 1608 67N-TOC T-DIAL and in address 1609 67N-TOC T-DIAL for an ANSI characteristic. This has to be coordinated with the system grading coordination chart for directional tripping. For ground currents with grounded network, you can mostly set up a separate grading coordination chart with shorter delay times. The time multiplier can also be set to . After pickup the element will then not trip. Pickup, however, will be signaled. If the 67N-TOC element is not required at all, address 116 67N/67N-TOC should be set to Definite Time during protection function configuration (see Section 2.1.1). Inrush Restraint When applying the protection device to transformers where high inrush currents are to be expected, the 7SJ80 can make use of an inrush restraint function for the directional overcurrent elements 67-1 PICKUP, 67-TOC PICKUP, 67N-1 PICKUP and 67N-TOC PICKUP as well as the non-directional overcurrent elements. The inrush restraint option is enabled or disabled in 2201 INRUSH REST. (in the settings option non-directional time overcurrent protection). The characteristic values of the inrush restraint are already listed in the section discussing the non-directional time overcurrent (Section 2.2.11 Setting Notes). Manual Close Mode (phases, ground) When a circuit breaker is closed onto a faulted line, a high speed trip by the circuit breaker is often desired. For overcurrent or high-set element the delay may be bypassed via a Manual Close pulse, thus resulting in instantaneous tripping. The internal "Manual close" signal is built from the binary input signal >Manual Close (no. 356). The internal "Manual close" signal remains active as long as the binary input signal >Manual Close is active, but at least for 300 ms (see the following logic diagram). To enable the device to react properly on occurrence of a fault in the phase elements after manual close, address 1513 MANUAL CLOSE has to be set accordingly. Accordingly, address 1613 MANUAL CLOSE is considered for the ground path address. Thus, the user determines for both elements, the phase and the ground element, what pickup value is active with what delay when the circuit breaker is closed manually. [lo_7sj6-hand-ein, 1, en_US] Figure 2-32 Manual close feature External Control Switch If the manual close signal is not from the 7SJ80 device, that is, neither sent via the built-in operator interface nor via a serial port but directly from a control acknowledgment switch, this signal must be passed to a 7SJ80 binary input, and configured accordingly (>Manual Close), so that the element selected for MANUAL CLOSE can become effective. Inactive means that all elements (phase and ground) operate with the configured trip times even with manual close. Internal Control Function The manual closing information must be allocated via CFC (interlocking task-level) using the CMD_Information block, if the internal control function is used. [handein-260602-kn, 1, en_US] Figure 2-33 100 Example for the generation of a manual close signal using the internal control function SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N i NOTE For an interaction between the automatic reclosing function (79 AR) and the control function, an extended CFC logic is necessary. See margin heading "Close command: Directly or via Control" in the Setting Notes of the automatic reclosing function (Section 2.15.6 Setting Notes). Interaction with Automatic Reclosure Function (phases) When reclosing follows, high-speed protection against faults with 67-2 or 67-3 is usually desired. If the fault still exists after reclosing, the 67-1 or 67-TOC element will be initiated with graded tripping times, that is, the 67-2 or 67-3 element will be blocked. You can use parameter 1514 67-2 active or 1532 67-3 active active to define whether the 67-2 or 67-3 element is influenced by a release signal of the internal or an external automatic reclosing device or not. The setting with 79 active means that the 67-2 or 67-3 element is only released if the automatic reclosing function is not blocked. If this is not desired, the setting always is selected so that the 67-2 or 67-3 element is always active as configured. The integrated automatic reclosing function of 7SJ80 also provides the option to individually determine for each overcurrent element whether tripping or blocking is to be carried out instantaneously, unaffected by the AR with time delay (see Section 2.15 Automatic Reclosing System 79). Interaction with Automatic Reclosing Function (ground) If reclosing follows, high-speed and simultaneous closing in the event of a fault with 67N-2 is usually desired. If the fault still exists after reclosing, the 67N-1 or 67N-TOC element is initiated with graded tripping times, that is, the 67N-2 or 67N-3 element is blocked. For this purpose, parameter 1614 67N-2 active or 1632 67N-3 active is used to determine whether the 67N-2 or 67N-3 element is influenced by the release signal of the internal or an external automatic reclosing device or not. The setting with 79 active means that the 67N- 2 or 67N-3 element is only released if the automatic reclosing function is not blocked. If this is not desired, the setting always is selected so that the 67N-2 or 67N-3 element is always active as configured. The integrated automatic reclosing function of 7SJ80 also provides the option to individually determine for each overcurrent element whether tripping or blocking is to be carried out instantaneously, unaffected by the AR with time delay (see Section 2.15 Automatic Reclosing System 79). 2.3.11 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 1501 FCT 67/67-TOC 1502 67-2 PICKUP 1503 67-2 DELAY 1504 67-1 PICKUP 1505 67-1 DELAY 1507 67-TOC PICKUP C Setting Options Default Setting Comments OFF ON OFF 67, 67-TOC Phase Time Overcurrent 67-2 Pickup 1A 0.10 .. 35.00 A; 2.00 A 5A 0.50 .. 175.00 A; 10.00 A 0.00 .. 60.00 sec; 0.10 sec 67-2 Time Delay 1A 0.10 .. 35.00 A; 1.00 A 67-1 Pickup 5A 0.50 .. 175.00 A; 5.00 A 0.00 .. 60.00 sec; 0.50 sec 67-1Time Delay 1A 0.10 .. 4.00 A 1.00 A 67-TOC Pickup 5A 0.50 .. 20.00 A 5.00 A 1508 67 TIME DIAL 0.05 .. 3.20 sec; 0.50 sec 67-TOC Time Dial 1509 67 TIME DIAL 0.50 .. 15.00 ; 5.00 67-TOC Time Dial 1510 67-TOC Drop-out Instantaneous Disk Emulation Disk Emulation Drop-Out Characteristic SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 101 Functions 2.3 Directional Overcurrent Protection 67, 67N Addr. Parameter 1511 C Setting Options Default Setting Comments 67- IEC CURVE Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1512 67- ANSI CURVE Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1513A MANUAL CLOSE 67-3 instant. 67-2 instant. 67-1 instant. 67-TOC instant. Inactive 67-2 instant. Manual Close Mode 1514A 67-2 active with 79 active always always 67-2 active 1518A 67 T DROP-OUT 0.00 .. 60.00 sec 0.00 sec 67 Drop-Out Time Delay 1519A ROTATION ANGLE -180 .. 180 45 Rotation Angle of Reference Voltage 1520A 67-2 MEASUREM. Fundamental True RMS Fundamental 67-2 measurement of 1521A 67-1 MEASUREM. Fundamental True RMS Fundamental 67-1 measurement of 1522A 67-TOC MEASUR. Fundamental True RMS Fundamental 67-TOC measurement of 1523 67-2 Direction Forward Reverse Non-Directional Forward 67-2 Direction 1524 67-1 Direction Forward Reverse Non-Directional Forward 67-1 Direction 1525 67-TOC Direct. Forward Reverse Non-Directional Forward 67-TOC Direction 1526 67-3 Direction Forward Reverse Non-Directional Forward 67-3 Direction 1527A 67-3 MEASUREM. Fundamental True RMS Fundamental 67-3 measurement of 1528 67-3 PICKUP 1A 1.00 .. 35.00 A; A 67-3 Pickup 5A 5.00 .. 175.00 A; A 0.00 sec 1529 67-3 DELAY 0.00 .. 60.00 sec; 1530 67 1.00 .. 20.00 I/Ip; 0.01 .. 999.00 TD 67 1531 MofPU Res T/Tp 0.05 .. 0.95 I/Ip; 0.01 .. 999.00 TD Multiple of Pickup <-> T/Tp 102 67-3 Time Delay SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N Addr. Parameter 1532A Setting Options Default Setting Comments 67-3 active always with 79 active always 67-3 active 1601 FCT 67N/67N-TOC OFF ON OFF 67N, 67N-TOC Ground Time Overcurrent 1602 67N-2 PICKUP 1A 0.05 .. 35.00 A; 0.50 A 67N-2 Pickup 5A 0.25 .. 175.00 A; 2.50 A 1603 67N-2 DELAY 0.00 .. 60.00 sec; 0.10 sec 67N-2 Time Delay 1604 67N-1 PICKUP 1A 0.05 .. 35.00 A; 0.20 A 67N-1 Pickup 5A 0.25 .. 175.00 A; 1.00 A 0.00 .. 60.00 sec; 0.50 sec 67N-1 Time Delay 1A 0.05 .. 4.00 A 0.20 A 67N-TOC Pickup 5A 0.25 .. 20.00 A 1.00 A 1605 67N-1 DELAY 1607 67N-TOC PICKUP C 1608 67N-TOC T-DIAL 0.05 .. 3.20 sec; 0.20 sec 67N-TOC Time Dial 1609 67N-TOC T-DIAL 0.50 .. 15.00 ; 5.00 67N-TOC Time Dial 1610 67N-TOC DropOut Instantaneous Disk Emulation Disk Emulation Drop-Out Characteristic 1611 67N-TOC IEC Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1612 67N-TOC ANSI Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1613A MANUAL CLOSE 67N-3 instant. 67N-2 instant. 67N-1 instant. 67N-TOC instant Inactive 67N-2 instant. Manual Close Mode 1614A 67N-2 active always with 79 active always 67N-2 active 1617 67N POLARIZAT. with VN and IN with V2 and I2 with VN and IN Ground Polarization 1618A 67N T DROP-OUT 0.00 .. 60.00 sec 0.00 sec 67N Drop-Out Time Delay 1619A ROTATION ANGLE -180 .. 180 -45 Rotation Angle of Reference Voltage 1620A 67N-2 MEASUREM. Fundamental True RMS Fundamental 67N-2 measurement of 1621A 67N-1 MEASUREM. Fundamental True RMS Fundamental 67N-1 measurement of 1622A 67N-TOC MEASUR. Fundamental True RMS Fundamental 67N-TOC measurement of 1623 67N-2 Direction Forward Reverse Non-Directional Forward 67N-2 Direction SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 103 Functions 2.3 Directional Overcurrent Protection 67, 67N Addr. Parameter 1624 C Setting Options Default Setting Comments 67N-1 Direction Forward Reverse Non-Directional Forward 67N-1 Direction 1625 67N-TOC Direct. Forward Reverse Non-Directional Forward 67N-TOC Direction 1626 67N-3 Direction Forward Reverse Non-Directional Forward 67N-3 Direction 1627A 67N-3 MEASUREM. Fundamental True RMS Fundamental 67N-3 measurement of 1628 67N-3 PICKUP 0.50 .. 35.00 A; A 67N-3 Pickup 1629 67N-3 DELAY 0.00 .. 60.00 sec; 0.00 sec 67N-3 Time Delay 1630 M.of PU TD 1.00 .. 20.00 I/Ip; 0.01 .. 999.00 TD Multiples of PU Time-Dial 1631 I/IEp Rf T/TEp 0.05 .. 0.95 I/Ip; 0.01 .. 999.00 TD 67N TOC 1632A 67N-3 active always with 79 active always 67N-3 active 2.3.12 Information List No. Information Type of Information Comments 2603 67N-3 TRIP OUT 67N-3 TRIP 2604 >BLK 67/67-TOC SP >BLOCK 67/67-TOC 2605 67N-3 BLOCKED OUT 67N-3 is BLOCKED 2606 67-3 BLOCKED OUT 67-3 is BLOCKED 2614 >BLK 67N/67NTOC SP >BLOCK 67N/67N-TOC 2615 >BLOCK 67-2 SP >BLOCK 67-2 2616 >BLOCK 67N-2 SP >BLOCK 67N-2 2617 >BLOCK 67-3 SP >BLOCK 67-3 2618 >BLOCK 67N-3 SP >BLOCK 67N-3 2621 >BLOCK 67-1 SP >BLOCK 67-1 2622 >BLOCK 67-TOC SP >BLOCK 67-TOC 2623 >BLOCK 67N-1 SP >BLOCK 67N-1 2624 >BLOCK 67N-TOC SP >BLOCK 67N-TOC 2628 Phase A forward OUT Phase A forward 2629 Phase B forward OUT Phase B forward 2630 Phase C forward OUT Phase C forward 2632 Phase A reverse OUT Phase A reverse 2633 Phase B reverse OUT Phase B reverse 2634 Phase C reverse OUT Phase C reverse 2635 Ground forward OUT Ground forward 2636 Ground reverse OUT Ground reverse 2637 67-1 BLOCKED OUT 67-1 is BLOCKED 104 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.3 Directional Overcurrent Protection 67, 67N No. Information Type of Information Comments 2642 67-2 picked up OUT 67-2 picked up 2646 67N-2 picked up OUT 67N-2 picked up 2647 67-2 Time Out OUT 67-2 Time Out 2648 67N-2 Time Out OUT 67N-2 Time Out 2649 67-2 TRIP OUT 67-2 TRIP 2651 67/67-TOC OFF OUT 67/67-TOC switched OFF 2652 67 BLOCKED OUT 67/67-TOC is BLOCKED 2653 67 ACTIVE OUT 67/67-TOC is ACTIVE 2655 67-2 BLOCKED OUT 67-2 is BLOCKED 2656 67N OFF OUT 67N/67N-TOC switched OFF 2657 67N BLOCKED OUT 67N/67N-TOC is BLOCKED 2658 67N ACTIVE OUT 67N/67N-TOC is ACTIVE 2659 67N-1 BLOCKED OUT 67N-1 is BLOCKED 2660 67-1 picked up OUT 67-1 picked up 2664 67-1 Time Out OUT 67-1 Time Out 2665 67-1 TRIP OUT 67-1 TRIP 2668 67N-2 BLOCKED OUT 67N-2 is BLOCKED 2669 67-TOC BLOCKED OUT 67-TOC is BLOCKED 2670 67-TOC pickedup OUT 67-TOC picked up 2674 67-TOC Time Out OUT 67-TOC Time Out 2675 67-TOC TRIP OUT 67-TOC TRIP 2676 67-TOC DiskPU OUT 67-TOC disk emulation is ACTIVE 2677 67N-TOC BLOCKED OUT 67N-TOC is BLOCKED 2678 67-3 TRIP OUT 67-3 TRIP 2679 67N-2 TRIP OUT 67N-2 TRIP 2681 67N-1 picked up OUT 67N-1 picked up 2682 67N-1 Time Out OUT 67N-1 Time Out 2683 67N-1 TRIP OUT 67N-1 TRIP 2684 67N-TOCPickedup OUT 67N-TOC picked up 2685 67N-TOC TimeOut OUT 67N-TOC Time Out 2686 67N-TOC TRIP OUT 67N-TOC TRIP 2687 67N-TOC Disk PU OUT 67N-TOC disk emulation is ACTIVE 2691 67/67N pickedup OUT 67/67N picked up 2692 67 A picked up OUT 67/67-TOC Phase A picked up 2693 67 B picked up OUT 67/67-TOC Phase B picked up 2694 67 C picked up OUT 67/67-TOC Phase C picked up 2695 67N picked up OUT 67N/67N-TOC picked up 2696 67/67N TRIP OUT 67/67N TRIP 2697 67-3 picked up OUT 67-3 picked up 2698 67N-3 picked up OUT 67N-3 picked up 2699 67-3 Time Out OUT 67-3 Time Out 2700 67N-3 Time Out OUT 67N-3 Time Out SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 105 Functions 2.4 Dynamic Cold Load Pickup 2.4 Dynamic Cold Load Pickup With the cold load pickup function, pickup and delay settings of directional and non-directional time overcurrent protection can be changed over dynamically. Applications i 2.4.1 * It may be necessary to dynamically increase the pickup values if, during starting and for a short time thereafter, certain elements of the system have an increased power consumption after a long period of zero voltage (e.g. air-conditioning systems, heating installations). Thus a raise of pickup thresholds can be avoided by taking into consideration such starting conditions. * As a further option, the pickup thresholds may be modified by an automatic reclosure function in accordance with its ready or not ready state. NOTE Dynamic cold load pickup must not be confused with the changeover option of the 4 setting groups (A to D). It is an additional feature. It is possible to change pickup thresholds and delay times. Functional Description Effect There are two methods by which the device can determine if the protected equipment is de-energized: Via binary inputs, the device is informed of the position of the circuit breaker (address 1702 Start Condition = Breaker Contact). * * As a criterion a set current threshold is undershot (address 1702 Start Condition = No Current). If the device determines that the protected equipment is de-energized via one of the above methods, a time, CB Open Time, is started and after its expiration the increased thresholds take effect. In addition, switching between parameters can be triggered by two other events: * By signal "79M Auto Reclosing ready" of the internal automatic reclosure function (address 1702 Start Condition = 79 ready). Thus the protection thresholds and the tripping times can be changed if automatic reclosure is ready for reclosing (see also Section 2.15 Automatic Reclosing System 79). * Irrespective of the setting of parameter 1702 Start Condition, the release of cold load pickup may always be selected via the binary input >ACTIVATE CLP. Figure 2-35 shows the logic diagram for dynamic cold load pickup function. If it is detected via the auxiliary contact or the current criterion that the system is de-energized, i.e. the circuit breaker is open, the CB Open Time is started. As soon as it has elapsed, the greater thresholds are enabled. When the protected equipment is re-energized (the device receives this information via the binary inputs or when threshold BkrClosed I MIN is exceeded), a second time delay referred to as the Active Time is initiated. Once it elapses, the pickup values of the relay elements return to their normal settings. This time may be reduced when current values fall below all normal pickup values for a set Stop Time after startup, i.e. after the circuit breaker has been closed. The starting condition of the fast reset time is made up of an ORcombination of the configured dropout conditions of all directional and non-directional overcurrent elements. When Stop Time is set to or when binary input >BLK CLP stpTim is active, no comparison is made with the "normal" thresholds. The function is inactive and the fast reset time, if applied, is reset. If overcurrent elements are picked up while time Active Time is running, the fault generally prevails until pickup drops out, using the dynamic settings. Only then the parameters are set back to "normal". If the dynamic setting values were activated via the binary input >ACTIVATE CLP or the signal "79M Auto Reclosing ready" and this cause drops out, the "normal" settings are restored immediately, even if a pickup is the result. 106 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.4 Dynamic Cold Load Pickup If the binary input >BLOCK CLP is enabled, all triggered timers are reset and, as a consequence, all "normal" settings are immediately restored. If blocking occurs during an on-going fault with dynamic cold load pickup functions enabled, the timers of all overcurrent relay elements are stopped and may then be restarted based on their "normal" duration. During power up of the protective relay with an open circuit breaker, the time delay CB Open Time is started, and is processed using the "normal" settings. Therefore, when the circuit breaker is closed, the "normal" settings are effective. The following figures show the timing sequenceand the logic diagram of the dynamic cold load pickup feature. [zeitablaeufe-der-dynamischen-parameterumschaltung-260602-kn, 1, en_US] Figure 2-34 Timing charts of the dynamic cold load pickup function SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 107 Functions 2.4 Dynamic Cold Load Pickup [7sj6x_dyn_parumschaltung-150502-kn, 1, en_US] Figure 2-35 2.4.2 Logic diagram of the dynamic cold load pickup function (50c, 50Nc, 51c, 51Nc, 67c, 67Nc) Setting Notes General The dynamic cold load pickup function can only be enabled if address 117 Coldload Pickup was set to Enabled during configuration of the protection functions. If not required, this function is set to Disabled. The function can be turned ON or OFF under address 1701 Coldload Pickup. Depending on the condition that should initiate the cold load pickup function address 1702 Start Condition is set to either No Current, Breaker Contact or to 79 ready. Naturally, the option Breaker Contact can only be selected if the device receives information regarding the switching state of the circuit breaker via at least one binary input. The option 79 ready modifies dynamically the pickup thresholds of the directional and non-directional time overcurrent protection when the automatic reclosing function is ready. To 108 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.4 Dynamic Cold Load Pickup initiate the cold load pickup, the automatic reclosing function provides the internal signal "79M Auto Reclosing ready". It is always active when the automatic reclosing function is available, activated, unblocked, and ready for a further cycle (see also margin heading "Controlling Directional/Non-Directional Overcurrent Protection Elements via Cold Load Pickup" in Section 2.15.6 Setting Notes). Time Delays There are no specific procedures on how to set the time delays at addresses 1703 CB Open Time, 1704 Active Time and 1705 Stop Time. These time delays must be based on the specific loading characteristics of the equipment being protected, and should be set to allow for brief overloads associated with dynamic cold load conditions. Non-Directional 50/51 Elements (phases) The dynamic pickup values and tripping times associated with the time overcurrent protection functions are set at address block 18 for the phase currents: The dynamic pickup and delay settings for the high-set elements are set at addresses 1801 50c-2 PICKUP or 1808 50c-3 PICKUP and 1802 50c-2 DELAY or 1809 50c-3 DELAY respectively; the dynamic pickup and delay settings for the 67N-1 element are set at addresses 1803 50c-1 PICKUP and 1804 50c-1 DELAY respectively; and the pickup, time multiplier (for IEC curves), and time dial (for ANSI curves) settings for the 67N-TOC element are set at addresses 1805 51c PICKUP, 1806 51c TIME DIAL and 1807 51c TIME DIAL respectively. Non-Directional 50N/51N Elements (ground) The dynamic pickup values and time delays associated with non-directional time overcurrent ground protection are set at address block 19: The dynamic pickup and delay settings for the high-set elements are set at addresses 1901 50Nc-2 PICKUP or 1908 50Nc-3 PICKUP and 1902 50Nc-2 DELAY or 1909 50Nc-3 DELAY respectively; the dynamic pickup and delay settings for the 67N-1 element are set at addresses 1903 50Nc-1 PICKUP and 1904 50Nc-1 DELAY respectively; and the pickup, time multiplier (for IEC curves), and time dial (for ANSI curves) settings for the 67N-TOC element are set at addresses 1905 51Nc PICKUP, 1906 51Nc T-DIAL and 1907 51Nc T-DIAL respectively. Directional 67/67-TOC Elements (phases) The dynamic pickup values and time delays associated with directional overcurrent phase protection are set at address block 20 Addresses 2001 67c-2 PICKUP or 2008 67c-3 PICKUP and 2002 67c-2 DELAY or 2009 67c-3 DELAY define the dynamic parameters for the high-current elements, 2003 67c-1 PICKUP and 2004 67c-1 DELAY for the directional definite time overcurrent element and 2005 67c-TOC PICKUP in combination with 2006 67c-TOC T-DIAL (for IEC characteristics) or 2006 67c-TOC T-DIAL (for ANSI characteristics) for the directional inverse time overcurrent protection element. Directional 67/67N Elements (ground) The dynamic pickup values and time delays associated with directional overcurrent ground protection are set at address block 21: Addresses 2101 67Nc-2 PICKUP or 2108 67Nc-3 PICKUP and 2102 67Nc-2 DELAY or 2109 67Nc-3 DELAY define the dynamic parameters for the high-current elements, 2103 67Nc-1 PICKUP and 2104 67Nc-1 DELAY for the directional definite time overcurrent element and 2105 67Nc-TOC PICKUP in combination with 2106 67Nc-TOC T-DIAL (for IEC characteristics) or 2107 67Nc-TOC T-DIAL (for ANSI characteristics) for the directional inverse time overcurrent protection element. 2.4.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 109 Functions 2.4 Dynamic Cold Load Pickup Addr. Parameter 1701 Setting Options Default Setting Comments COLDLOAD PICKUP OFF ON OFF Cold-Load-Pickup Function 1702 Start Condition No Current Breaker Contact 79 ready No Current Start Condition 1703 CB Open Time 0 .. 21600 sec 3600 sec Circuit Breaker OPEN Time 1704 Active Time 0 .. 21600 sec 3600 sec Active Time 1705 Stop Time 1801 50c-2 PICKUP 1802 50c-2 DELAY 1803 50c-1 PICKUP 1804 50c-1 DELAY 1805 51c PICKUP C 1 .. 600 sec; 600 sec Stop Time 1A 0.10 .. 35.00 A; 10.00 A 50c-2 Pickup 5A 0.50 .. 175.00 A; 50.00 A 0.00 .. 60.00 sec; 0.00 sec 50c-2 Time Delay 1A 0.10 .. 35.00 A; 2.00 A 50c-1 Pickup 5A 0.50 .. 175.00 A; 10.00 A 0.00 .. 60.00 sec; 0.30 sec 50c-1 Time Delay 1A 0.10 .. 4.00 A 1.50 A 51c Pickup 5A 0.50 .. 20.00 A 7.50 A 1806 51c TIME DIAL 0.05 .. 3.20 sec; 0.50 sec 51c Time dial 1807 51c TIME DIAL 0.50 .. 15.00 ; 5.00 51c Time dial 1808 50c-3 PICKUP 1A 1.00 .. 35.00 A; A 50c-3 Pickup 5A 5.00 .. 175.00 A; A 1809 50c-3 DELAY 1901 50Nc-2 PICKUP 1902 50Nc-2 DELAY 1903 50Nc-1 PICKUP 1904 50Nc-1 DELAY 1905 51Nc PICKUP 0.00 .. 60.00 sec; 0.00 sec 50c-3 Time Delay 1A 0.05 .. 35.00 A; 7.00 A 50Nc-2 Pickup 5A 0.25 .. 175.00 A; 35.00 A 0.00 .. 60.00 sec; 0.00 sec 50Nc-2 Time Delay 1A 0.05 .. 35.00 A; 1.50 A 50Nc-1 Pickup 5A 0.25 .. 175.00 A; 7.50 A 0.00 .. 60.00 sec; 0.30 sec 50Nc-1 Time Delay 1A 0.05 .. 4.00 A 1.00 A 51Nc Pickup 5A 0.25 .. 20.00 A 5.00 A 1906 51Nc T-DIAL 0.05 .. 3.20 sec; 0.50 sec 51Nc Time Dial 1907 51Nc T-DIAL 0.50 .. 15.00 ; 5.00 51Nc Time Dial 1908 50Nc-3 PICKUP 0.05 .. 35.00 A; A 50Nc-3 Pickup 1909 50Nc-3 DELAY 0.00 .. 60.00 sec; 0.00 sec 50Nc-3 Time Delay 2001 67c-2 PICKUP 1A 0.10 .. 35.00 A; 10.00 A 67c-2 Pickup 5A 0.50 .. 175.00 A; 50.00 A 0.00 .. 60.00 sec; 0.00 sec 67c-2 Time Delay 1A 0.10 .. 35.00 A; 2.00 A 67c-1 Pickup 5A 0.50 .. 175.00 A; 10.00 A 2002 67c-2 DELAY 2003 67c-1 PICKUP 2004 67c-1 DELAY 2005 67c-TOC PICKUP 2006 67c-TOC T-DIAL 2007 67c-TOC T-DIAL 2008 67c-3 PICKUP 2009 67c-3 DELAY 110 1A 0.00 .. 60.00 sec; 0.30 sec 67c-1 Time Delay 1A 0.10 .. 4.00 A 1.50 A 67c Pickup 5A 0.50 .. 20.00 A 7.50 A 0.05 .. 3.20 sec; 0.50 sec 67c Time Dial 0.50 .. 15.00 ; 5.00 67c Time Dial 1A 1.00 .. 35.00 A; A 67c-3 Pickup 5A 5.00 .. 175.00 A; A 0.00 .. 60.00 sec; 0.00 sec 67c-3 Time Delay SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.4 Dynamic Cold Load Pickup Addr. Parameter C Setting Options Default Setting Comments 2101 67Nc-2 PICKUP 1A 0.05 .. 35.00 A; 7.00 A 67Nc-2 Pickup 5A 0.25 .. 175.00 A; 35.00 A 0.00 .. 60.00 sec; 0.00 sec 67Nc-2 Time Delay 1A 0.05 .. 35.00 A; 1.50 A 67Nc-1 Pickup 5A 0.25 .. 175.00 A; 7.50 A 2102 67Nc-2 DELAY 2103 67Nc-1 PICKUP 2104 67Nc-1 DELAY 2105 67Nc-TOC PICKUP 0.00 .. 60.00 sec; 0.30 sec 67Nc-1 Time Delay 1A 0.05 .. 4.00 A 1.00 A 67Nc-TOC Pickup 2106 67Nc-TOC T-DIAL 5A 0.25 .. 20.00 A 5.00 A 0.05 .. 3.20 sec; 0.50 sec 67Nc-TOC Time Dial 2107 2108 67Nc-TOC T-DIAL 0.50 .. 15.00 ; 5.00 67Nc-TOC Time Dial 67Nc-3 PICKUP 0.25 .. 35.00 A; A 67Nc-3 Pickup 2109 67Nc-3 DELAY 0.00 .. 60.00 sec; 0.00 sec 67Nc-3 Time Delay 2.4.4 Information List No. Information Type of Information Comments 1730 >BLOCK CLP SP >BLOCK Cold-Load-Pickup 1731 >BLK CLP stpTim SP >BLOCK Cold-Load-Pickup stop timer 1732 >ACTIVATE CLP SP >ACTIVATE Cold-Load-Pickup 1994 CLP OFF OUT Cold-Load-Pickup switched OFF 1995 CLP BLOCKED OUT Cold-Load-Pickup is BLOCKED 1996 CLP running OUT Cold-Load-Pickup is RUNNING 1997 Dyn set. ACTIVE OUT Dynamic settings are ACTIVE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 111 Functions 2.5 Single-Phase Overcurrent Protection 2.5 Single-Phase Overcurrent Protection The single-phase overcurrent protection evaluates the current that is measured by the sensitive NS- or the normal N input. Which input is used depends on the device version according to the order number. Applications * * 2.5.1 Plain ground fault protection at a power transformer Sensitive tank leakage protection. Functional Description The single-phase definite time overcurrent ground protection is illustrated by the tripping characteristic as shown in Figure 2-36. The current to be measured is filtered by numerical algorithms. Because of the high sensitivity a particularly narrow band filter is used. The current pickup thresholds and tripping times can be set. The detected current is compared to the pickup value 50 1Ph-1 PICKUP or 50 1Ph-2 PICKUP and reported if this is violated. After expiry of the respective delay time 50 1Ph-1 DELAY or 50 1Ph-2 DELAY, the trip command is issued. The two elements together form a two-stage protection. The dropout value is approximately 95% of the pickup value for currents greater than I > 0.3 * INom. The current filter is bypassed if currents are extremely high in order to achieve a short tripping time. This occurs automatically as soon as the instantaneous value of the current exceeds the set value of the 50 1Ph-2 PICKUP element by at least factor 2 * 2. [ueb-einph-kennlinie-020926-rei, 1, en_US] Figure 2-36 Two-stage characteristic of the single-phase time-overcurrent protection The following figure shows the logic diagram of the single-phase overcurrent protection function. 112 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.5 Single-Phase Overcurrent Protection [logikdia-umz-1ph-strom-141103-kn, 1, en_US] Figure 2-37 2.5.2 Logic diagram of the single-phase time overcurrent protection High-impedance Ground Fault Unit Protection Application Examples The high impedance protection concept is based on measuring the voltage across the paralleled CT's to a common high-resistive resistor. The CTs must be of the same design and feature at least a separate core for high-impedance protection. In particular, they must have the same transformer ratios and approximately identical knee-point voltage. With 7SJ80, the high-impedance principle is particularly well suited for detecting ground faults in grounded networks at transformers, generators and shunt reactors. Figure 2-38 shows an application example for a grounded transformer winding or a grounded motor/generator. The right-hand example depicts an ungrounded transformer winding or an ungrounded motor/generator where the grounding of the system is assumed somewhere else. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 113 Functions 2.5 Single-Phase Overcurrent Protection [ueb-einph-hochimpedanz-020926-rei, 1, en_US] Figure 2-38 Ground fault protection according to the high-impedance principle Function of the High-Impedance Principle The high-impedance principle is explained on the basis of a grounded transformer winding. No zero sequence current will flow during normal operation, i.e. the neutral point current is SP = 0 and the phase currents are 3 0 = A + B + C = 0. In case of an external ground fault (left in Figure 2-39), whose fault current is supplied via the grounded neutral point, the same current flows through the transformer neutral point and the phases. The corresponding secondary currents (all current transformers have the same transformation ratio) compensate each other; they are connected in series. Across resistor R only a small voltage is generated. It originates from the inner resistance of the transformers and the connecting cables of the transformers. Even if any current transformer experiences a partial saturation, it will become low-ohmic for the period of saturation and creates a low-ohmic shunt to the high-ohmic resistor R. Thus, the high resistance of the resistor also has a stabilizing effect (the so-called resistance stabilization). [ueb-einph-hochimpedanz2-020926-rei, 1, en_US] Figure 2-39 Principle of ground fault protection according to the high-impedance principle When a ground fault occurs in the protected zone Figure 2-39 right), there is always a neutral point current SP. The grounding conditions in the rest of the network determine how strong a zero sequence current from the system is. A secondary current which is equal to the total fault current tries to pass through the resistor R. Since the latter is high-resistive, a high voltage emerges immediately. Therefore, the current transformers get saturated. The RMS voltage across the resistor approximately corresponds to the knee-point voltage of the current transformers. Resistance R is sized such that, even with the very lowest ground fault current to be detected, it generates a secondary voltage, which is equal to half the saturation voltage of current transformers (see also notes on "Dimensioning" in Subsection 2.5.4 Setting Notes). 114 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.5 Single-Phase Overcurrent Protection High-impedance Protection with 7SJ80 With 7SJ80 the sensitive measuring input NS or the measuring input N is used for high-impedance protection. As this is a current input, the protection detects current through the resistor instead of the voltage across the resistor R. Das Figure 2-40 illustrates the connection scheme. The protection device is connected in series to resistor R and measures its current. Varistor B limits the voltage when internal faults occur. High voltage peaks emerging with transformer saturation are cut by the varistor. At the same time, voltage is smoothed without reduction of the mean value. [sj6x-ueb-einph-hochimpedanz3-141103, 1, en_US] Figure 2-40 Connection diagram of the ground fault differential protection according to the high-impedance principle For protection against overvoltages it is also important that the device is directly connected to the grounded side of the current transformers so that the high voltage at the resistor can be kept away from the device. For generators, motors and shunt reactors, the high-impedance differential protection can be used analogously. All current transformers at the overvoltage side, the undervoltage side and the current transformer at the neutral point have to be connected in parallel when using auto-transformers. In principle, this procedure can be applied to every protected object. When applied as busbar protection, for example, the device is connected to the parallel connection of all feeder current transformers via the resistor. 2.5.3 Tank Leakage Protection Application Example The tank leakage protection has the task to detect ground leakage -- even high-ohmic -- between a phase and the frame of a power transformer. The tank must be isolated from ground. A conductor links the tank to ground, and the current through this conductor is fed to a current input of the relay. When tank leakage occurs, a fault current (tank leakage current) will flow through the grounding conductor to ground. This tank leakage current is detected by the single-phase overcurrent protection as an overcurrent; an instantaneous or delayed trip command is issued in order to disconnect all sides of the transformer. A high-sensitivity single-phase current input is used for tank leakage protection. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 115 Functions 2.5 Single-Phase Overcurrent Protection [sj6x-ueb-einph-kesselschut-020926-rei, 1, en_US] Figure 2-41 2.5.4 Principle of tank-leakage protection Setting Notes General Single-phase time overcurrent protection can be set ON or OFF at address 2701 50 1Ph. The settings are based on the particular application. The pickup value for 50 1Ph-2 PICKUP is set in address2703, the pickup value for 50 1Ph-1 PICKUP at address 2706. If only one element is required, set the one not required to . A trip time delay can be set in address 2704 50 1Ph-2 DELAY for the 50-2 element and for the 50-1 element in address 2707 50 1Ph-1 DELAY. With setting 0 s no delay takes place. The selected times are additional time delays and do not include the operating time (measuring time, etc.) of the elements. The delay can also be set to ; the corresponding element will then not trip after pickup, but the pickup is reported. Special notes are given in the following for the use as high-impedance unit protection and tank leakage protection. Application as High-impedance Protection The application as high-impedance protection requires that neutral point current detection is possible in the system in addition to phase current detection (see example in Figure 2-40). Furthermore, a sensitive input transformer must be available at device input NS. In this case, only the pickup value for single-phase overcurrent protection is set at the 7SJ80 device for the current at input NS. The entire function of high-impedance protection is, however, dependent on the interaction of current transformer characteristics, external resistor R and voltage across R. The following section gives information on this topic. Current Transformer Data for High-impedance Protection All current transformers must have an identical transformation ratio and nearly equal knee-point voltage. This is usually the case if they are of equal design and identical rated data. The knee-point voltage can be approximately calculated from the rated data of a CT as follows: [ueb-einph-saetigungsspannung-021026-rei, 1, en_US] VKVP 116 Knee-point voltage SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.5 Single-Phase Overcurrent Protection Ri Internal burden of the CT PNom Nominal power of the CT INom Secondary nominal current of CT ALF Rated accuracy limit factor of the CT The nominal current, nominal power and accuracy limit factor are normally stated on the rating plate of the current transformer, e.g. Current transformer 800/5; 5P10; 30 VA That means Nom = 5 A (from 800/5) ALF PNom = 10 (from 5P10) = 30 VA The internal burden is often stated in the test report of the current transformer. If not, it can be derived from a DC measurement on the secondary winding. Calculation Example: CT 800/5; 5P10; 30 VA with Ri = 0.3 [ueb-einph-saettigungssp-beisp1-021026-rei, 1, en_US] or CT 800/1; 5P10; 30 VA with Ri = 5 [ueb-einph-saettigungssp-beisp2-021026-rei, 1, en_US] Besides the CT data, the resistance of the longest connection lead between the CTs and the 7SJ80 device must be known. Stability with High-impedance Protection The stability condition is based on the following simplified assumption: If there is an external fault, one of the current transformers gets totally saturated. The other ones will continue transmitting their (partial) currents. In theory, this is the most unfavorable case. Since, in practice, it is also the saturated transformer which supplies current, an automatic safety margin is guaranteed. Figure 2-42 shows a simplified equivalent circuit. CT1 and CT2 are assumed as ideal transformers with their inner resistances Ri1 and Ri2. Ra are the resistances of the connecting cables between current transformers and resistor R. They are multiplied by 2 as they have a forward and a return line. Ra2 is the resistance of the longest connecting cable. CT1 transmits current 1. CT2 shall be saturated. Because of saturation the transformer represents a low-resistance shunt which is illustrated by a dashed short-circuit line. R >> (2Ra2 + Ri2) is a further prerequisite.. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 117 Functions 2.5 Single-Phase Overcurrent Protection [ueb-einph-anordnung-020926-rei, 1, en_US] Figure 2-42 Simplified equivalent circuit of a circulating current system for high-impedance protection The voltage across R is then VR = 1 * ( 2Ra2 + Ri2 ) It is assumed that the pickup value of the 7SJ80 corresponds to half the knee-point voltage of the current transformers. In the balanced case results VR = VS / 2 This results in a stability limit SL, i.e. the maximum through-fault current below which the scheme remains stable: [ueb-einph-stabilitaetslimit-021026-rei, 1, en_US] Calculation Example: For the 5 A CT as above with VS = 75 V and Ri = 0.3 longest CT connection lead 22 m (24.06 yd) with 4 mm2 cross-section, this corresponds to Ra = 0.1 [ueb-einph-stabilitaetslimit-5a-021026-rei, 1, en_US] that is 15 x rated current or 12 kA primary. For the 1 A CT as above with VS = 350 V and Ri = 5 longest CT connection lead 107 m (117.02 yd) with 2.5 mm2 cross-section, this corresponds Ra = 0.75 [ueb-einph-stabilitaetslimit-1a-021026-rei, 1, en_US] that is 27 x rated current or 21.6 kA primary. Sensitivity with High-impedance Protection The voltage present at the CT set is forwarded to the protective relay across a series resistor R as proportional current for evaluation. The following considerations are relevant for dimensioning the resistor: As already mentioned, it is desired that the high-impedance protection should pick up at half the knee-point voltage of the CT's. The resistor R can calculated on this basis. Since the device measures the current flowing through the resistor, resistor and measuring input of the device must be connected in series. Since, furthermore, the resistance shall be high-resistance (condition: R >> 2Ra2 + Ri2, as mentioned above), the inherent resistance of the measuring input can be neglected. The resistance is then calculated from the pickup current pu and half the knee-point voltage: 118 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.5 Single-Phase Overcurrent Protection [ueb-einph-widerstand-021026-rei, 1, en_US] Calculation Example: For the 5 A CT as above desired pickup value pu = 0.1 A (equivalent to 16 A primary) [ueb-einph-widerstand-5a-021026-rei, 1, en_US] For the 1 A CT as above desired pickup valuepu = 0.05 A (equivalent to 40 A primary) [ueb-einph-widerstand-1a-021026-rei, 1, en_US] Series resistor R must be rated for a minimum permanent load Ppermanent: [fohochimppcont5a-20120514, 1, en_US] [fohochimppcont1a-20120514, 1, en_US] Furthermore, series resistor R must be rated for a fault current applying for approx. 0.5 s. This time is usually sufficient for the backup protection to clear the fault. The thermal load of the series resistor depends on the voltage Vrms,stab applying during an internal fault. It is calculated according to the following formulas: [fohochimpvrmsstab5a-20120514, 1, en_US] [fohochimpvrmsstab1a-20120514, 1, en_US] where Ik,max,int corresponds to the maximum fault current during an internal fault. For the 5 A current transformer 800/5 with 40 kA primary, k,max,int equals 250 A secondary. For the 1 A current transformer 800/1 with 40 kA primary k,max,int 50 A secondary. This yields a short-time load over 0.5 s for the series resistor of: [fohochimpp-5a-20120514, 1, en_US] SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 119 Functions 2.5 Single-Phase Overcurrent Protection [fohochimpp-1a-20120514, 1, en_US] Please bear in mind that when choosing a higher pickup value pu, the resistance must be decreased and, in doing so, power loss will increase significantly. The varistor B (see following figure) must be dimensioned such that it remains high-resistive until reaching knee-point voltage, e.g. approx. 100 V for 5 A CT, approx. 500 V for 1 A CT. [sj6x-ueb-einph-hochimpedanz3-141103, 1, en_US] Figure 2-43 Connection diagram of the ground fault differential protection according to the high-impedance principle Even with an unfavorable external circuit, the maximum voltage peaks should not exceed 2 kV for safety reasons If performance makes it necessary to switch several varistors in parallel, preference should by given to types with a flat characteristic to avoid asymmetrical loading. therefore recommend the following types from METROSIL: 600A/S1/S256 (k = 450, = 0.25) 600A/S1/S1088 (k = 900, = 0.25) The pickup value (0.1 A or 0.05 A in the example) is set in address 2706 50 1Ph-1 PICKUP in the device. The 50-2 element is not required (address 2703 50 1Ph-2 PICKUP = ). The trip command of the protection can be delayed via address 2707 50 1Ph-1 DELAY. Normally, such delay is set to 0. If a higher number of CTs is connected in parallel, e.g. as busbar protection with several feeders, the magnetizing currents of the transformers connected in parallel cannot be neglected anymore. In this case, the magnetizing currents at half the knee-point voltage (corresponds to the setting value) have to be summed up. These magnetizing currents reduce the current through the resistor R. Therefore the actual pickup value will be correspondingly higher. Application as Tank Leakage Protection The use as tank leakage protection requires that a sensitive input transformer is available at the device input NS. In this case, only the pickup value for single phase overcurrent protection is set at the 7SJ80 device for the current at input NS. The tank leakage protection is a sensitive overcurrent protection which detects the leakage current between the isolated transformer tank and ground. Its sensitivity is set in address 2706 50 1Ph-1 PICKUP. The 50-2 element is not required (address 2703 50 1Ph-2 PICKUP = ). The trip command of the element can be delayed in address 2707 50 1Ph-1 DELAY. It is normally set to 0. 120 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.5 Single-Phase Overcurrent Protection 2.5.5 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 2701 50 1Ph 2703 50 1Ph-2 PICKUP C Setting Options Default Setting Comments OFF ON OFF 50 1Ph 1A 0.001 .. 1.600 A; 0.300 A 50 1Ph-2 Pickup 5A 0.005 .. 8.000 A; 1.500 A 2704 50 1Ph-2 DELAY 2706 50 1Ph-1 PICKUP 0.00 .. 60.00 sec; 0.10 sec 50 1Ph-2 Time Delay 1A 0.001 .. 1.600 A; 0.100 A 50 1Ph-1 Pickup 2707 50 1Ph-1 DELAY 5A 0.005 .. 8.000 A; 0.500 A 0.00 .. 60.00 sec; 0.50 sec 2.5.6 Information List No. Information Type of Information Comments 5951 >BLK 50 1Ph SP >BLOCK 50 1Ph 5952 >BLK 50 1Ph-1 SP >BLOCK 50 1Ph-1 5953 >BLK 50 1Ph-2 SP >BLOCK 50 1Ph-2 5961 50 1Ph OFF OUT 50 1Ph is OFF 5962 50 1Ph BLOCKED OUT 50 1Ph is BLOCKED 5963 50 1Ph ACTIVE OUT 50 1Ph is ACTIVE 5966 50 1Ph-1 BLK OUT 50 1Ph-1 is BLOCKED 5967 50 1Ph-2 BLK OUT 50 1Ph-2 is BLOCKED 5971 50 1Ph Pickup OUT 50 1Ph picked up 5972 50 1Ph TRIP OUT 50 1Ph TRIP 5974 50 1Ph-1 PU OUT 50 1Ph-1 picked up 5975 50 1Ph-1 TRIP OUT 50 1Ph-1 TRIP 5977 50 1Ph-2 PU OUT 50 1Ph-2 picked up 5979 50 1Ph-2 TRIP OUT 50 1Ph-2 TRIP 5980 50 1Ph I: VI 50 1Ph: I at pick up SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 50 1Ph-1 Time Delay 121 Functions 2.6 Voltage Protection 27, 59 2.6 Voltage Protection 27, 59 Voltage protection has the task to protect electrical equipment against undervoltage and overvoltage. Both operational states are abnormal as overvoltage may cause for example insulation problems or undervoltage may cause stability problems. There are two elements each available for overvoltage protection and undervoltage protection. Applications 2.6.1 * 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 rejection of a generator from the system. * The undervoltage protection function detects voltage collapses on transmission lines and electrical machines and prevents inadmissible operating states and a possible loss of stability. Measurement Principle Connection/Measured Values The voltages supplied to the device may correspond to the three phase-to-ground voltages VA-N, VB-N, VC-N or the two phase-to-phase voltages (VA-B, VB-C) and the displacement voltage (ground voltage VN) or - in the case of a single-phase connection - any phase-to-ground voltage. The connection type has been specified during the configuration in parameter 213 VT Connect. 3ph (see Section ). The following table indicates which voltages can be evaluated by the function. The settings for this are made in the P.System Data 1 (see Section ). Furthermore, it is indicated to which value the threshold must be set. All voltages are fundamental frequency values. Table 2-8 Connection, threephase (parameter213) Overvoltage Van, Vbn, Vcn Vab, Vab, Vab, Vab, Vbc, VGnd Vbc Vbc, VSyn Vbc, Vx Vph-g, VSyn Undervoltage Van, Vbn, Vcn 122 Voltage protection, selectable voltages Selectable voltage parameter 614/ 615 Threshold to be set as Vphph (largest phase-to-phase voltage) Phase-to-phase voltage Vph-n ((largest phase-to-ground voltage) Phase-to-ground voltage V1(positive sequence voltage) Positive sequence voltage calculated from phase-to-groundvoltage or phase-tophase voltage / 3 V2 (negative sequence voltage) Negative sequence voltage Vphph (largest phase-to-phase voltage) Leiter-Leiter-Spannung V1(positive sequence voltage) Positive sequence voltage V2 (negative sequence voltage) Negative sequence voltage None (direct evaluation of the voltage connected to voltage input 1) Direct voltage value Vphph (smallest phase-to-phase voltage) Phase-to-phase voltage Vph-n (smallest phase-to-ground voltage) Phase-to-ground voltage V1 (positive sequence voltage) Positive sequence voltage* 3 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.6 Voltage Protection 27, 59 Connection, threephase Selectable voltage (parameter213) parameter 614/ 615 Vab, Vbc, VGnd Vphph (smallest phase-to-phase voltage) Vab, Vbc V1 ((positive sequence voltage) Vab, Vbc, VSyn Vab, Vbc, Vx Vph-g, VSyn None (direct evaluation of the voltage connected to voltage input 1) Threshold to be set as Phase-to-phase voltage Positive sequence voltage* 3 Direct voltage value The positive and negative sequence voltages stated in the table are calculated from the phase-to-ground voltages. Current Criterion Depending on the system, the primary voltage transformers are arranged either on the supply side or the load side of the associated circuit breaker. These different arrangements lead to different behaviour of the voltage protection function when a fault occurs. When a tripping command is issued and a circuit breaker is opened, full voltage remains on the supply side while the load side voltage becomes zero. When voltage supply is suppressed, undervoltage protection, for instance, will remain picked up. If pickup is to drop out, the current can be used as an additional criterion for pickup of undervoltage protection (current supervision CS). Undervoltage pickup can only be maintained when the undervoltage criterion satisfied and a settable minimum current level (BkrClosed I MIN) are exceeded. Here, the largest of the three phase currents is used. When the current decreases below the minimum current setting after the circuit breaker has opened, undervoltage protection drops out. i 2.6.2 NOTE If parameter CURRENT SUPERV. is set to disabled in address 5120, the device picks up immediately without measurement voltage and the undervoltage protection function in pickup. Apply measuring voltage or block the voltage protection to continue with configuration. Moreover you have the option of setting a flag via device operation for blocking the voltage protection. This initiates the reset of the pickup and device configuration can be resumed. Overvoltage Protection 59 Function The overvoltage protection has two elements. In case of a high overvoltage, tripping switch off is performed with a short-time delay, whereas in case of less severe overvoltages, the tripping is performed with a longer time delay. When one of the adjustable settings is exceeded, the 59 element picks up and trips after an adjustable time delay has elapsed. The time delay is not dependent on the magnitude of the overvoltage. The dropout ratio for the two overvoltage elements (= Vdropout value/Vpickup value) can be set. The following figure shows the logic diagram of the overvoltage protection function. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 123 Functions 2.6 Voltage Protection 27, 59 [7sj80-ueberspgs-schutz-20061219, 1, en_US] Figure 2-44 2.6.3 Logic diagram of the overvoltage protection Undervoltage Protection 27 Function Undervoltage protection consists of two definite time elements (27-1 PICKUP and 27-2 PICKUP). Therefore, tripping can be time-coordinated depending on how severe voltage collapses are. Voltage thresholds and time delays can be set individually for both elements. The dropout ratio for the two undervoltage elements (= Vdropout value/Vpickup value) can be set. Like the other protection functions, the undervoltage protection operates in an extended frequency range. This ensures that the protection function is ensured even for the protection of decelerating motors, for instance. However, the r.m.s. value of the positive voltage component is considered too small when the frequency deviates considerably so that the device will tend to overfunction. Figure 2-45 shows a typical voltage profile during a fault for source side connection of the voltage transformers. Because full voltage is present after the circuit breaker has been opened, current supervision CS described above is not necessary in this case. After the voltage has dropped below the pickup setting, tripping is initiated after time delay 27-1 DELAY. As long as the voltage remains below the dropout setting, reclosing is blocked. Only after the fault has been cleared, i.e. when the voltage increases above the dropout level, the element drops out and allows reclosing of the circuit breaker. 124 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.6 Voltage Protection 27, 59 [stoerfallverlauf-ohne-stromkriterium-260602-kn, 1, en_US] Figure 2-45 Typical fault profile for source side connection of the voltage transformer (without current supervision) Figure 2-46shows a fault profile for a load side connection of the voltage transformers. When the circuit breaker is open, the voltage disappears (the voltage remains below the pickup setting), and current supervision is used to ensure that pickup drops out after the circuit breaker has opened (BkrClosed I MIN). After the voltage has dropped below the pickup setting, tripping is initiated after time delay 27-1 DELAY. When the circuit breaker opens, voltage decreases to zero and undervoltage pickup is maintained. The current value also decreases to zero so that current criterion is reset as soon as the release threshold (BkrClosed I MIN) is exceeded. Pickup of the protection function is also reset by the action of the AND-combination of voltage and current. As a consequence, energization is admitted anew when the minimum command time elapsed. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 125 Functions 2.6 Voltage Protection 27, 59 [stoerfallverlauf-mit-stromkriterium-260602-kn, 1, en_US] Figure 2-46 Typical fault profile for load side connection of the voltage transformers (with current supervision) Upon the closing of the circuit breaker, current criterion is delayed for a short period of time. If the voltage criterion drops out during this time period (about 60 ms), the protection function does not pick up. Therefore no fault record is created when voltage protection is activated in a healthy system. It is important to understand, however, that if a low voltage condition exists on the load after the circuit breaker is closed (unlike Figure 2-46), the desired pickup of the element will be delayed by 60 ms. The following figure shows the logic diagram of the undervoltage protection function. 126 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.6 Voltage Protection 27, 59 [7sj80-unterspgs-schutz-20061219, 1, en_US] Figure 2-47 2.6.4 Logic diagram of the undervoltage protection Setting Notes General Voltage protection is only effective and accessible if address 150 27/59 is set to Enabled during configuration of protection functions. If this function is not required, then Disabled is set. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 127 Functions 2.6 Voltage Protection 27, 59 The voltage to be evaluated is selected in Power System Data 1 (see Chapter 2.6 Voltage Protection 27, 59, Table 2-8). Overvoltage protection can be turned ON or OFF, or set to Alarm Only at address 5001 FCT 59. Undervoltage protection can be turned ON or OFF or set to Alarm Only at address 5101 FCT 27. With the protection function ON, tripping, the clearing of a fault and fault recording are initiated when the thresholds are exceeded and the set time delays have expired. With setting Alarm Only no trip command is given, no fault is recorded and no immediate fault annunciation is shown on the display Overvoltage Protection with Phase-to-phase or Phase-to-ground Voltages The largest of the applied voltages is evaluated for the phase-to-phase or phase-to-ground overvoltage protection. The threshold values are set in the value to be evaluated (see Chapter 2.6 Voltage Protection 27, 59, Table 2-8). The overvoltage protection has two elements. The pickup value of the lower threshold (address 5002 or 5003, 59-1 PICKUP, depending on the phase-to-ground or the phase-to-phase voltages, can be assigned a longer time delay (address 5004, 59-1 DELAY) and the upper threshold element (address 5005 or 5006, 59-2 PICKUP) a shorter (address 5007, 59-2 DELAY) time delay. There are no specific procedures on how the pickup values are set. However, as the function is mainly used to prevent high insulation damage to system components and users, the threshold value 5002 , 5003 59-1 PICKUP lies generally between 110 % and 115 % of the nominal voltage and setting value 5005 , 5006 59-2 PICKUP at approximately 130 %. The time delays of the overvoltage elements are entered at addresses 5004 59-1 DELAY and 5007 59-2 DELAY, and should be selected in such manner that they make allowance for brief voltage peaks that are generated during switching operations and also enable clearance of stationary overvoltages in due time. The choice between phase-to-ground and phase-to-phase voltage allows voltage asymmetries (e.g. caused by a ground fault) to be taken into account (phase-to-ground) or to remain unconsidered (phase-to-phase) during evaluation. Overvoltage Protection - Positive Sequence System V1 In a three-phase voltage transformer connection the positive sequence system can be evaluated for the overvoltage protection by means of configuring parameter 614 OP. QUANTITY 59 to V1. In this case, the threshold values of the overvoltage protection must be set in parameters 5019 59-1 PICKUP V1 or 5020 59-2 PICKUP V1. Overvoltage Protection - Negative Sequence System V2 In a three-phase transformer connection, parameter 614 OP. QUANTITY 59 can determine that the negative sequence system V2 can be evaluated as a measured value for the overvoltage protection. The negative sequence system detects voltage unbalance and can be used for the stabilization of the time overcurrent protection. In backup protection of transformers or generators, the fault currents lie, in some cases, only slightly above the load currents. In order to obtain a pickup threshold of the time overcurrent protection that is as sensitive as possible, its stabilization via the voltage protection is necessary to avoid false tripping. Overvoltage protection comprises two elements. Thus, with configuration of the negative system, a longer time delay (address 5004, 59-1 DELAY) may be assigned to the lower element (address 5015, 59-1-V2 PICKUP and a shorter time delay (address 5007, 59-2 DELAY) may be assigned to the upper element (address 5016, 59-2-V2 PICKUP). There are not clear cut procedures on how to set the pickup values 59-1-V2 PICKUP or 59-2-V2 PICKUP as they depend on the respective station configuration. The time delays of the overvoltage elements are entered at addresses 5004 59-1 DELAY and 5007 59-2 DELAY, and should be selected in such manner that they make allowance for brief voltage peaks that are generated during switching operations and also enable clearance of stationary overvoltages in due time. 128 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.6 Voltage Protection 27, 59 Dropout Threshold of the Overvoltage Protection The dropout thresholds of the 59-1 element and the 59-2 element can be configured via the dropout ratio r = VDropout/VPickup at addresses 5017 59-1 DOUT RATIO or 5018 59-2 DOUT RATIO. The following marginal condition applies to r: r * (configured pickup threshold) 150 V with connection of phase-to-phase voltages and phase-to-ground voltages or r * (configured pickup threshold) 260 V with calculation of the measured values from the connected voltages (e.g. phase-to-phase voltages calculated from the connected phase-to-ground voltages). The minimum hysteresis is 0.6 V. Undervoltage Protection - Positive Sequence System V1 The positive sequence component (V1) can be evaluated for the undervoltage protection. Especially in case of stability problems, their acquisition is advantageous because the positive sequence system is relevant for the limit of the stable energy transmission. Concerning the pickup values there are no specific notes on how to set them. However, because the undervoltage protection function is primarily intended to protect induction machines from voltage dips and to prevent stability problems, the pickup values will usually be between 60 % and 85 % of the nominal voltage. The threshold value is multiplied as positive sequence voltage and set to 3, thus realizing the reference to the nominal voltage. Undervoltage protection comprises two elements. The pickup value of the lower threshold is set at address 5110 or 5111, 27-2 PICKUP (depending on the voltage transformer connection, phase-to-ground or phaseto-phase), while time delay is set at address 5112, 27-2 DELAY (short time delay). The pickup value of the upper element is set at address 5102 or 5103, 27-1 PICKUP, while the time delay is set at address 5106, 27-1 DELAY (a somewhat longer time delay). Setting these elements in this way allows the undervoltage protection function to closely follow the stability behavior of the system. The time settings should be selected such that tripping occurs in response to voltage dips that lead to unstable operating conditions. On the other hand, the time delay should be long enough to avoid tripping on shortterm voltage dips. Undervoltage Protection with Phase-to-phase or Phase-to-ground Voltages In parameter 615 OP. QUANTITY 27 you can determine for undervoltage protection in a three-phase connection that instead of the positive-sequence system V1, the smallest of the phase-to-phase voltages Vphph or the smallest phase-to-ground voltage Vph-n is configured as a measured quantity. The threshold values are set in the quantity to be evaluated (see Section 2.6 Voltage Protection 27, 59, Table 2-8). Undervoltage protection comprises two elements. The pickup value of the lower threshold is set at address 5110 or 5111, 27-2 PICKUP (depending on the voltage transformer connection, phase-to-ground or phaseto- phase), while time delay is set at address 5112, 27-2 DELAY (short time delay). The pickup value of the upper element is set at address 5102 or 5103, 27-1 PICKUP, while the time delay is set at address 5106, 27-1 DELAY (a somewhat longer time delay). Setting these elements in this way allows the undervoltage protection function to closely follow the stability behavior of the system. The time settings should be selected such that tripping occurs in response to voltage dips that lead to unstable operating conditions. On the other hand, the time delay should be long enough to avoid tripping on shortterm voltage dips. Dropout Threshold of the Undervoltage Protection The dropout thresholds of the 59-1 element and the 59-2 element can be parameterized via the dropout ratio r = Vdropout/Vpickup (5113 27-1 DOUT RATIO or 5114 27-2 DOUT RATIO). The following marginal condition applies to r: r * (configured pickup threshold) 130 V with connection of phase-to-phase voltages and phase-to-ground voltages) or r* (configured pickup threshold) 225 V with calculation of the measured values from the connected voltages (e.g. calculated phase-to-phase voltages from the connected phase-to-ground voltages). The minimum hysteresis is 0.6 V. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 129 Functions 2.6 Voltage Protection 27, 59 i NOTE If a setting is selected such that the dropout threshold (= pickup threshold * dropout ratio) results in a greater value than 130 V/225 V, it will be limited automatically. No error message occurs. Current Criterion for Undervoltage Protection The 27-1 element and the 27-2 element can be supervised by the current flow monitoring setting. If the CURRENT SUPERV. is switched ON at address 5120 (factory setting), the release condition of the current criterion must be fulfilled in addition to the corresponding undervoltage condition, which means that a configured minimum current (BkrClosed I MIN, address 212) must be present to make sure that this protective function can pick up. Thus it can be achieved that pickup of the undervoltage protection drops out when the line is disconnected from voltage supply. Furthermore, this feature prevents an immediate general pickup of the device when the device is powered-up without measurement voltage being present. i NOTE If parameter CURRENT SUPERV.is set to disabled at address 5120, the device picks up immediately if the measuring-circuit voltage fails and the undervoltage protection is enabled. Furthermore, configuration can be performed by pickup of measuring-circuit voltage or blocking of the voltage protection. The latter can be initiated via device operation in DIGSI and via communication from the control center by means of a tagging command for blocking the voltage protection. This causes the dropout of the pickup and parameterization can be resumed. Please note that the pickup threshold BkrClosed I MIN (address 212) also affects the overload protection, the cold load pickup function and the CB maintenance. 2.6.5 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". Addr. Parameter Setting Options Default Setting Comments 5001 FCT 59 OFF ON Alarm Only OFF 59 Overvoltage Protection 5002 59-1 PICKUP 20 .. 260 V 110 V 59-1 Pickup 5003 59-1 PICKUP 20 .. 150 V 110 V 59-1 Pickup 5004 59-1 DELAY 0.00 .. 100.00 sec; 0.50 sec 59-1 Time Delay 5005 59-2 PICKUP 20 .. 260 V 120 V 59-2 Pickup 5006 59-2 PICKUP 20 .. 150 V 120 V 59-2 Pickup 5007 59-2 DELAY 0.00 .. 100.00 sec; 0.50 sec 59-2 Time Delay 5015 59-1 PICKUP V2 2 .. 150 V 30 V 59-1 Pickup V2 5016 59-2 PICKUP V2 2 .. 150 V 50 V 59-2 Pickup V2 5017A 59-1 DOUT RATIO 0.90 .. 0.99 0.95 59-1 Dropout Ratio 5018A 59-2 DOUT RATIO 0.90 .. 0.99 0.95 59-2 Dropout Ratio 5019 59-1 PICKUP V1 20 .. 150 V 110 V 59-1 Pickup V1 5020 59-2 PICKUP V1 20 .. 150 V 120 V 59-2 Pickup V1 5101 FCT 27 OFF ON Alarm Only OFF 27 Undervoltage Protection 5102 27-1 PICKUP 10 .. 210 V 75 V 27-1 Pickup 5103 27-1 PICKUP 10 .. 120 V 45 V 27-1 Pickup 5106 27-1 DELAY 0.00 .. 100.00 sec; 1.50 sec 27-1 Time Delay 130 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.6 Voltage Protection 27, 59 Addr. Parameter Setting Options Default Setting Comments 5110 27-2 PICKUP 10 .. 210 V 70 V 27-2 Pickup 5111 27-2 PICKUP 10 .. 120 V 40 V 27-2 Pickup 5112 27-2 DELAY 0.00 .. 100.00 sec; 0.50 sec 27-2 Time Delay 5113A 27-1 DOUT RATIO 1.01 .. 3.00 1.20 27-1 Dropout Ratio 5114A 27-2 DOUT RATIO 1.01 .. 3.00 1.20 27-2 Dropout Ratio 5120A CURRENT SUPERV. OFF ON ON Current Supervision 2.6.6 Information List No. Information Type of Information Comments 234.2100 27, 59 blk IntSP 27, 59 blocked via operation 6503 >BLOCK 27 SP >BLOCK 27 undervoltage protection 6505 >27 I SUPRVSN SP >27-Switch current supervision ON 6506 >BLOCK 27-1 SP >BLOCK 27-1 Undervoltage protection 6508 >BLOCK 27-2 SP >BLOCK 27-2 Undervoltage protection 6513 >BLOCK 59 SP >BLOCK 59 overvoltage protection 6530 27 OFF OUT 27 Undervoltage protection switched OFF 6531 27 BLOCKED OUT 27 Undervoltage protection is BLOCKED 6532 27 ACTIVE OUT 27 Undervoltage protection is ACTIVE 6533 27-1 picked up OUT 27-1 Undervoltage picked up 6534 27-1 PU CS OUT 27-1 Undervoltage PICKUP w/curr. superv 6537 27-2 picked up OUT 27-2 Undervoltage picked up 6538 27-2 PU CS OUT 27-2 Undervoltage PICKUP w/curr. superv 6539 27-1 TRIP OUT 27-1 Undervoltage TRIP 6540 27-2 TRIP OUT 27-2 Undervoltage TRIP 6565 59 OFF OUT 59-Overvoltage protection switched OFF 6566 59 BLOCKED OUT 59-Overvoltage protection is BLOCKED 6567 59 ACTIVE OUT 59-Overvoltage protection is ACTIVE 6568 59-1 picked up OUT 59-1 Overvoltage V> picked up 6570 59-1 TRIP OUT 59-1 Overvoltage V> TRIP 6571 59-2 picked up OUT 59-2 Overvoltage V>> picked up 6573 59-2 TRIP OUT 59-2 Overvoltage V>> TRIP SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 131 Functions 2.7 Negative Sequence Protection 46 2.7 Negative Sequence Protection 46 Negative sequence protection detects unbalanced loads on the system. Applications * This protection function can be used to detect interruptions, short-circuits and polarity problems in the connections to the current transformers. * It is also useful in detecting single-phase and two-phase faults with fault currents lower than the maximum load currents. Prerequisites The unbalanced load protection becomes effective when: at least one phase current is greater than 0.1 x Nom and all phase currents are smaller than 10 x Nom. 2.7.1 Definite Time characteristic The definite time characteristic consists of two elements. As soon as the first settable threshold 46-1 PICKUP is reached, a pickup message is output and time element 46-1 DELAY is started. When the second element 46-2 PICKUP is started, another message is output and time element 46-2 DELAY is initiated. Once either time delay elapses, a trip signal is initiated. [unabhaeng-ausl_charakt-des-schieflastschutzes-260602-kn, 1, en_US] Figure 2-48 Definite time characteristic for negative sequence protection Settable Dropout Times Pickup stabilization for the definite-time tripping characteristic 46-1, 46-2 can be accomplished by means of settable dropout times. This facility is used in power systems with possible intermittent faults. Used together with electromechanical relays, it allows different dropout responses to be adjusted and a time grading of numerical and electromechanical relays to be implemented. 2.7.2 Inverse Time characteristic The inverse time element is dependent on the ordered device version. It operates with IEC or ANSI characteristic tripping curves. The curves and associated formulas are given in the Technical Data. When programming 132 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.7 Negative Sequence Protection 46 the inverse time characteristic also definite time elements 46-2 PICKUP and 46-1 PICKUP are available (see a foregoing paragraph). Pickup and Tripping The negative sequence current is compared to the setting value 46-TOC PICKUP. When the negative sequence current exceeds 1.1 times the setting value, a pickup annunciation is generated. The tripping time is calculated from the negative sequence current according to the characteristic selected. When tripping time is reached, a tripping command is issued. The characteristic curve is illustrated in the following Figure. [abhaeng-ausl_charakt-des-schieflastschutzes-260602-kn, 1, en_US] Figure 2-49 Inverse time characteristic for negative sequence protection Dropout for IEC Curves The element drops out when the negative sequence current decreases to approx. 95% of the pickup setting. The time delay resets immediately to be ready for another pickup operation. Dropout for ANSI Curves When using an ANSI curve it can be selected whether the dropout of the element is to occur instantaneously or whether dropout is to be performed by means of the disk emulation mechanism. Instantaneous" means that the drop out will occur when a 95 % of the pickup value is reached. For a new pickup the time counter starts at zero. The disk emulation evokes a dropout process (timer counter is decrementing) which begins after de-energization. This process corresponds to the reset of a Ferraris-disk (explaining its denomination "disk emulation"). In case several faults occur in succession, the "history" is taken into consideration due to the inertia of the Ferraris-disk, and the time response is adapted. This ensures a proper simulation of the temperature rise of the protected object even for extremely fluctuating unbalanced load values. Reset begins as soon as 90 % of the setting value is reached, in accordance with the dropout curve of the selected characteristic. In the range between the dropout value (95 % of the pickup value) and 90 % of the setting value, the incrementing and decrementing process is in idle state. Disk emulation offers advantages when the behavior of the negative sequence protection must be coordinated with other relays in the system based on electromagnetic measuring principles. Logic The following figure shows the logic diagram for the negative sequence protection function. The protection may be blocked via a binary input. This resets pickup and time elements and clears measured values. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 133 Functions 2.7 Negative Sequence Protection 46 When the negative sequence protection criteria are no longer satisfied (i.e. all phase currents below 0.1 x N or at least one phase current is greater than 10 x Nom) all pickups issued by the negative sequence protection function are reset. [7sj80-schieflastschutz-20060109, 1, en_US] Figure 2-50 Logic diagram of the unbalanced load protection The pickup of the definite time overcurrent protection can be stabilized by the configured dropout time 4012 46 T DROP-OUT. This time is started and maintains the pickup condition if the current falls below the threshold. Therefore, the function does not drop out at high speed. The trip command delay time continues running. After the dropout delay time has elapsed, the pickup is reported OFF and the trip delay time is reset unless the threshold has been exceeded again. If the threshold is exceeded again during the dropout delay time, the time is canceled. The trip command delay time continues running. Should the threshold value be exceeded after its expiry, the trip command is issued immediately. If the threshold value is not exceeded at this time, there will be no reaction. If the threshold value is exceeded again after expiry of the trip-command delay time, while the dropout delay time is still running, tripping occurs immediately. The configured dropout times do not influence the tripping times of the inverse time elements as these depend dynamically on the measured current value. For purposes of dropout coordination, disc emulation is used with electro-mechanical relays. 134 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.7 Negative Sequence Protection 46 2.7.3 Setting Notes General The function type has been specified during configuration of the protection functions (see Section 2.1.1.2 Setting Notes, address 140, 46). If only the definite time elements are desired, the address 46 should be set to Definite Time. Selecting 46 = TOC IEC or TOC ANSI in address 140 will additionally make all parameters available that are relevant for the inverse time characteristics. If this function is not required, then Disabled is set. The function can be turned ON or OFF in address 4001 FCT 46. The default pickup settings and delay settings are generally sufficient for most applications. Definite Time Elements The unbalanced load protection function comprises two elements. Therefore, the upper element (address 4004 46-2 PICKUP) can be set to a short time delay 4005 46-2 DELAY) and the lower element (address 4002 46- 1 PICKUP) can be set to a somewhat longer time delay (address 4003 46-1 DELAY). This allows the lower element to act, e.g. as an alarm, while the upper element will cut the inverse time characteristic as soon as high inverse currents are present. If 46-2 PICKUP is set to about 60%, tripping is always performed with the thermal characteristic. On the other hand, with more than 60% of unbalanced load, a two-phase fault can be assumed. The delay time 46-2 DELAY must be coordinated with the system grading of phase-to-phase faults. If power supply with current I is provided via just two phases, the following applies to the inverse current: [formel-i2-058-260602-kn, 1, en_US] Examples: When protecting feeder or cable systems, unbalanced load protection may serve to identify low magnitude unsymmetrical faults below the pickup values of the directional and non-directional overcurrent elements. Here, the following must be observed: [formel-i2-058-260602-kn, 1, en_US] A phase-to-ground fault with current corresponds to the following negative sequence current: [formel-i2-033-260602-kn, 1, en_US] On the other hand, with more than 60% of unbalanced load, a phase-to-phase fault can be assumed. The delay time 46-2 DELAY must be coordinated with the system grading of phase-to-phase faults. For a power transformer, unbalanced load protection may be used as sensitive protection for low magnitude phase-to-ground and phase-to-phase faults. In particular, this application is well suited for delta-wye transformers where low side phase-to-ground faults do not generate high side zero sequence currents (e.g. vector group Dy). Since transformers transform symmetrical currents according to the transformation ratio "CTR", the relationship between negative sequence currents and total fault current for phase-to-phase faults and phase-toground faults are valid for the transformer as long as the turns ratio "CTR" is taken into consideration. Consider a transformer with the following data: Base Transformer Rating SNomT = 16 MVA Primary Nominal Voltage VNom = 110 kV Secondary Nominal Voltage VNom = 20 kV SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 (TRV = 110/20) 135 Functions 2.7 Negative Sequence Protection 46 Vector Groups High Side CT Dy5 100 A/1 A (CT = 100) The following fault currents may be detected at the low side: If 46-1 PICKUP on the high side of the devices is set to = 0.1, then a fault current of = 3 * TRV * TR * 46-1 PICKUP = 3 * 110/20 * 100 * 0.1 A = 165 A for single-phase faults and 3 * TRV * TR * 46-1 PICKUP = 95 A can be detected for two-phase faults at the low side. This corresponds to 36% and 20% of the transformer nominal current respectively. It is important to note that load current is not taken into account in this simplified example. As it cannot be recognized reliably on which side the thus detected fault is located, the delay time 46-1 DELAY must be coordinated with other downstream relays in the system. Pickup Stabilization (definite-time overcurrent protection) Pickup of the definite time elements can be stabilized by means of a configurable dropout time. This dropout time is set in 4012 46 T DROP-OUT. Inverse Time Tripping Curve Several IEC and ANSI curves are available if your operational equipment requires the use of a curve-dependent tripping characteristic. They are selected at address 4006 46 IEC CURVE or at address 4007 46 ANSI CURVE It must be noted that a safety factor of about 1.1 has already been included between the pickup value and the setting value when an inverse time characteristic is selected. This means that a pickup will only occur if an unbalanced load of about 1.1 times the setting value 46-TOC PICKUP is present (address 4008). Dropout occurs as soon as the value falls below 95 % of the pickup value. When selecting the ANSI curve in address 401146-TOC RESET the Disk Emulation, dropout will be performed according to the dropout curve as explained in the function description. The associated time multiplier is specified at address 4010, 46-TOC TIMEDIAL or address 400946-TOC TIMEDIAL. The time multiplier can also be set to . After pickup the element will then not trip. Pickup, however, will be signaled. If the inverse time element is not required at all, address 140 46 should be set to Definite Time during the configuration of protection functions (Section 2.1.1.2 Setting Notes). 2.7.4 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 4001 FCT 46 4002 46-1 PICKUP 4003 46-1 DELAY 4004 46-2 PICKUP C Setting Options Default Setting Comments OFF ON OFF 46 Negative Sequence Protection 1A 0.05 .. 3.00 A 0.10 A 46-1 Pickup 5A 0.25 .. 15.00 A 0.50 A 0.00 .. 60.00 sec; 1.50 sec 46-1 Time Delay 1A 0.05 .. 3.00 A 0.50 A 46-2 Pickup 5A 0.25 .. 15.00 A 2.50 A 4005 46-2 DELAY 0.00 .. 60.00 sec; 1.50 sec 46-2 Time Delay 4006 46 IEC CURVE Normal Inverse Very Inverse Extremely Inv. Extremely Inv. IEC Curve 136 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.7 Negative Sequence Protection 46 Addr. Parameter 4007 46 ANSI CURVE 4008 46-TOC PICKUP C Setting Options Default Setting Comments Extremely Inv. Inverse Moderately Inv. Very Inverse Extremely Inv. ANSI Curve 1A 0.05 .. 2.00 A 0.90 A 46-TOC Pickup 5A 0.25 .. 10.00 A 4.50 A 4009 46-TOC TIMEDIAL 0.50 .. 15.00 ; 5.00 46-TOC Time Dial 4010 46-TOC TIMEDIAL 0.05 .. 3.20 sec; 0.50 sec 46-TOC Time Dial 4011 46-TOC RESET Instantaneous Disk Emulation Instantaneous 46-TOC Drop Out 4012A 46 T DROP-OUT 0.00 .. 60.00 sec 0.00 sec 46 Drop-Out Time Delay 2.7.5 Information List No. Information Type of Information Comments 5143 >BLOCK 46 SP >BLOCK 46 5151 46 OFF OUT 46 switched OFF 5152 46 BLOCKED OUT 46 is BLOCKED 5153 46 ACTIVE OUT 46 is ACTIVE 5159 46-2 picked up OUT 46-2 picked up 5165 46-1 picked up OUT 46-1 picked up 5166 46-TOC pickedup OUT 46-TOC picked up 5170 46 TRIP OUT 46 TRIP 5171 46 Dsk pickedup OUT 46 Disk emulation picked up SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 137 Functions 2.8 Frequency Protection 81 O/U 2.8 Frequency Protection 81 O/U The frequency protection function detects abnormally high and low frequencies in the system or in electrical machines. If the frequency lies outside the allowable range, appropriate actions are initiated, such as load shedding or separating a generator from the system. Applications 2.8.1 * Decrease in system frequency occurs when the system experiences an increase in the real power demand, or when a malfunction occurs with a generator governor or automatic generation control (AGC) system. The frequency protection function is also used for generators which (for a certain time) operate 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 frequency decrease protection. * Increase in system frequency occurs e.g. when large blocks of load (island network) are removed from the system, or again when a malfunction occurs with a generator governor. This entails risk of self-excitation for generators feeding long lines under no-load conditions. Functional Description Detection of Frequency The frequency is detected preferably from the positive sequence voltage. If this voltage is too low, the phaseto-phase voltage VA-B at the device is used. If the amplitude of this voltage is too small, one of the other phaseto-phase voltages is used instead. Through the use of filters and repeated measurements, the frequency evaluation is free from harmonic influences and very accurate. Overfrequency/Underfrequency Frequency protection consists of four frequency elements. To make protection flexible for different power system conditions, theses elements can be used alternatively for frequency decrease or increase separately, and can be independently set to perform different control functions. Operating Range The frequency can be determined as long as in a three-phase voltage transformer connection the positivesequence system of the voltages, or alternatively, in a single-phase voltage transformer connection, the respective voltage is present and of sufficient magnitude. If the measured voltage drops below a settable value Vmin, the frequency protection is blocked because no precise frequency values can be calculated from the signal. Time Delays / Logic Each frequency element has an associated settable time delay. When the time delay elapses, a trip signal is generated. When a frequency element drops out, the tripping command is immediately terminated, but not before the minimum command duration has elapsed. Each of the four frequency elements can be blocked individually via binary inputs. The following figure shows the logic diagram for the frequency protection function. 138 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.8 Frequency Protection 81 O/U [7sj6x_frequenzschutz-070906-he, 1, en_US] Figure 2-51 2.8.2 Logic diagram of the frequency protection Setting Notes General Frequency protection is only in effect and accessible if address 154 81 O/U is set to Enabled during configuration of protective functions. If the function is not required Disabled is set. The function can be turned ON or OFF under address 5401 FCT 81 O/U. By setting the parameters 5421 to 5424, the function of each of the elements 81-1 PICKUP to 81-4 PICKUP is set individually as overfrequency or underfrequency protection or set to OFF, if the element is not required. Minimum Voltage Address 5402 Vmin is used to set the minimum voltage. Frequency protection is blocked as soon as the minimum voltage is undershot. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 139 Functions 2.8 Frequency Protection 81 O/U The threshold value has to be set as phase-to-phase quantity if the connection is three-phase. With a singlephase phase-to-ground connection the threshold is set as phase voltage. Pickup Values The setting as overfrequency or underfrequency element does not depend on the parameter threshold values of the respective element. An element can also function, for example, as an overfrequency element if its threshold value is set below the nominal frequency and vice versa. If frequency protection is used for load shedding purposes, the setting values depend on the actual power system conditions. Normally, a time coordinated load shedding is required that takes into account the importance of the consumers or consumer groups. Further application examples exist in the field of power stations. Here too, the frequency values to be set mainly depend on the specifications of the power system / power station operator. The underfrequency protection safeguards the power station's own demand by disconnecting it from the power system on time. The turbo governor regulates the machine set to the nominal speed. Consequently, the station's own demands can be continuously supplied at nominal frequency. Under the assumption that the apparent power is reduced by the same degree, turbine-driven generators can, as a rule, be continuously operated down to 95% of the nominal frequency. However, for inductive consumers, the frequency reduction not only means an increased current input, but also endangers stable operation. For this reason, only a short-term frequency reduction down to about 48 Hz (for fN = 50 Hz) or 58 Hz (for fN = 60 Hz) is permissible. A frequency increase can, for example, occur due to a load shedding or malfunction of the speed regulation (e.g. in an island network). In this way, the frequency increase protection can, for example, be used as overspeed protection. Dropout Thresholds The dropout threshold is defined via the adjustable dropout-difference address 5415 DO differential. It can thus be adjusted to the network conditions. The dropout difference is the absolute-value difference between pickup threshold and dropout threshold. The default value of 0.02 Hz can usually remain. Should, however, frequent minor frequency fluctuations be expected, this value should be increased. Time Delays The delay times 81-1 DELAY to 81-4 DELAY (addresses 5405, 5408, 5411 and 5414) allow the frequency elements to be time coordinated, e.g. for load shedding equipment. The set times are additional delay times not including the operating times (measuring time, dropout time) of the protection function. 2.8.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". Addr. Parameter Setting Options Default Setting Comments 5401 FCT 81 O/U OFF ON OFF 81 Over/Under Frequency Protection 5402 Vmin 10 .. 150 V 65 V Minimum required voltage for operation 5402 Vmin 20 .. 150 V 35 V Minimum required voltage for operation 5403 81-1 PICKUP 40.00 .. 60.00 Hz 49.50 Hz 81-1 Pickup 5404 81-1 PICKUP 50.00 .. 70.00 Hz 59.50 Hz 81-1 Pickup 5405 81-1 DELAY 0.00 .. 100.00 sec; 60.00 sec 81-1 Time Delay 5406 81-2 PICKUP 40.00 .. 60.00 Hz 49.00 Hz 81-2 Pickup 5407 81-2 PICKUP 50.00 .. 70.00 Hz 59.00 Hz 81-2 Pickup 5408 81-2 DELAY 0.00 .. 100.00 sec; 30.00 sec 81-2 Time Delay 5409 81-3 PICKUP 40.00 .. 60.00 Hz 47.50 Hz 81-3 Pickup 140 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.8 Frequency Protection 81 O/U Addr. Parameter Setting Options Default Setting Comments 5410 81-3 PICKUP 50.00 .. 70.00 Hz 57.50 Hz 81-3 Pickup 5411 81-3 DELAY 0.00 .. 100.00 sec; 3.00 sec 81-3 Time delay 5412 81-4 PICKUP 40.00 .. 60.00 Hz 51.00 Hz 81-4 Pickup 5413 81-4 PICKUP 50.00 .. 70.00 Hz 61.00 Hz 81-4 Pickup 5414 81-4 DELAY 0.00 .. 100.00 sec; 30.00 sec 81-4 Time delay 5415A DO differential 0.02 .. 1.00 Hz 0.02 Hz Dropout differential 5421 FCT 81-1 O/U OFF ON f> ON f< OFF 81-1 Over/Under Frequency Protection 5422 FCT 81-2 O/U OFF ON f> ON f< OFF 81-2 Over/Under Frequency Protection 5423 FCT 81-3 O/U OFF ON f> ON f< OFF 81-3 Over/Under Frequency Protection 5424 FCT 81-4 O/U OFF ON f> ON f< OFF 81-4 Over/Under Frequency Protection 2.8.4 Information List No. Information Type of Information Comments 5203 >BLOCK 81O/U SP >BLOCK 81O/U 5206 >BLOCK 81-1 SP >BLOCK 81-1 5207 >BLOCK 81-2 SP >BLOCK 81-2 5208 >BLOCK 81-3 SP >BLOCK 81-3 5209 >BLOCK 81-4 SP >BLOCK 81-4 5211 81 OFF OUT 81 OFF 5212 81 BLOCKED OUT 81 BLOCKED 5213 81 ACTIVE OUT 81 ACTIVE 5214 81 Under V Blk OUT 81 Under Voltage Block 5232 81-1 picked up OUT 81-1 picked up 5233 81-2 picked up OUT 81-2 picked up 5234 81-3 picked up OUT 81-3 picked up 5235 81-4 picked up OUT 81-4 picked up 5236 81-1 TRIP OUT 81-1 TRIP 5237 81-2 TRIP OUT 81-2 TRIP 5238 81-3 TRIP OUT 81-3 TRIP 5239 81-4 TRIP OUT 81-4 TRIP SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 141 Functions 2.9 Undervoltage-controlled reactive power protection (27/Q) 2.9 Undervoltage-controlled reactive power protection (27/Q) The undervoltage-controlled reactive power protection protects the system for mains decoupling purposes. To prevent a voltage collapse in energy systems, the generating side, e.g. a generator, must be equipped with voltage and frequency protection devices. An undervoltage-controlled reactive power protection is required at the supply system connection point. It detects critical power system situations and ensures that the power generation facility is disconnected from the mains. Furthermore, it ensures that reconnection only takes place under stable power system conditions. The associated criteria can be parameterized. Applications * * * 2.9.1 High-voltage and extra-high voltage power systems Medium-voltage power systems Regenerative infeed types such as wind power stations, photovoltaics, cogeneration plants or hydropower Functional Description General To detect critical power system situations, the QU protection uses the phase-to-phase voltage, the positivesequence current and the reactive power. To release the reconnection, the results of voltage protection and frequency protection are additionally analyzed on the generating side. If the frequency and voltage values are outside the operating range, the QU protection does not work. It can also be blocked by the fuse-failure monitor or via a binary input. Pickup of the QU protection causes the device to pick up. Simultaneously, fault recording is activated. But tripping of the QU protection does not cause the device to trip and should be routed to a separate binary output. No other fault record is started. The QU protection can be used for all voltage connection types that enable detection of the displacement voltage (measured or calculated). The Appendix provides connection examples. Signal transmission in the high-voltage power system requires the power system connection point and the generating facility to be connected via telecommunication cables (optical fiber or copper cable). Radio links, GPRS or satellite transmission with signal transit times <3 s can alternatively be used in medium-voltage systems. Protection Function The QU protection trips under the following conditions: * All 3 phase-to-phase voltages are below the parameterized threshold value. * * The positive-sequence current 1 is above the parameterized threshold value. The facility requires more than the set reactive power. The pickup thresholds for undervoltage U< Pickup, the reactive power Q> Pickup and the release current I-Release can be set. After detection of the tripping criteria, time-delayed trip signals are sent to the circuit breaker of the power system connection point and to the circuit breaker of the generating facility. The time delay can be set separately for both circuit breakers. Time-graded tripping is thus possible. The tripping of the circuit breaker at the power system connection point ultimately de-energizes the entire generating facility. To prevent tripping of the QU protection during starting operations, parameterize and activate the inrush current detection. The inrush blocking of the QU protection can then be activated via parameter Inrush blk. The overcurrent protection detects the inrush. The QU protection evaluates the inrush indications of the overcurrent protection (see Figure 2-15). The following figure shows the logic diagram of the QU protection. 142 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.9 Undervoltage-controlled reactive power protection (27/Q) [7sj80_prot-lo-qvp, 1, en_US] Figure 2-52 Logic diagram of the QU protection Reconnection The release for reconnecting the generating facility is given under the following conditions: * All 3 phase-to-phase voltages are above the parameterized threshold value. * * The power system frequency is within the parameterized range. The delay time of the protection function has elapsed. The delay time is started by the first trip signal of any stage of the voltage or frequency protection. The release criteria for reconnection can be set. The following parameters are used: * Threshold for the release voltage at the power system connection point * * Frequency deviation in positive and negative direction Reconnection release can be delayed by a settable time. You also define whether the tripping of the circuit breaker at the power system connection point is included in the formation of the release signal. The tripping of the protection stages of voltage and frequency protection is always included. The following figure shows the logic diagram of the QU protection for reconnection. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 143 Functions 2.9 Undervoltage-controlled reactive power protection (27/Q) [lo-recl-rel-qvp-20120319, 2, en_US] Figure 2-53 2.9.2 Logic diagram of QU protection restarting Setting Notes General Configuration of the protection functions at address 155 27/Q-Protection defines whether the QU protection is Enabled or Disabled. At address 5501 27/Q-Protection the QU protection function can be switched ON or OFF. The release current is entered at address 5502 I-Release. The default setting is at 10 % of the rated current. The threshold is one of the pickup criteria for tripping. At address 5503 Inrush blk you can activate the blocking when inrush has been detected. 144 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.9 Undervoltage-controlled reactive power protection (27/Q) Pickup Values You can set the pickup value for the reactive power stage at address 5511 Q> Pickup. Example: Q > 5 % of the supply system rating VNomsec = 100 V INomsec = 1 A this yields the (default) setting value Q> Pickup for Q> Pickup 100 V * 1 A * 3 * 0.05 = 8.7 VAR At address 5512 U< Pickup, you can enter the pickup value for the voltage stage. Delays Address 5513 Delay Gen. CB is used to set the time delay for tripping the circuit breaker of the generation facility, e.g. at the generator. Enter the time delay for tripping the circuit breaker at the supply system connection point at address 5514 Delay Grid CB. Always set the delay time longer than delay time Delay Gen. CB. Close Release At address 5521 Recl. release the close release is switched ON or OFF. At address 5522 U> Reclose you can specify the release voltage. Set the value to approx. 95 % of the rated voltage value (default). Specify the delay time for releasing the generator reconnection at address 5523 T Reclose. Furthermore, enter the admitted deviation from the rated frequency. At address 5524 Pos. f-diff enter the frequency deviation in positive direction and at address 5525 Neg. f-diff in negative direction. If the measured frequency is within this range, this reconnection condition is satisfied. Address 5526 Incl. 27/Q Trip determines whether the tripping indication of the QU protection is taken into account for the reconnection release. 2.9.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 5501 27/Q-Protection 5502 I-Release C Setting Options Default Setting Comments OFF ON OFF 27 / Q dir. con. Protection 1A 0.02 .. 0.20 A; 0 0.10 A 5A 0.10 .. 1.00 A; 0 0.50 A Current-Rel. for Trip and Reclose 5503 Inrush blk NO YES NO blocking with inrush 5504 Q> Direction Forward Reverse Forward Reactive power direction 5511 Q> Pickup 1A 1.70 .. 10000.00 VAR 8.70 VAR 5A 8.50 .. 50000.00 VAR 43.50 VAR Reactive power threshold for pickup 5512 U< Pickup 10.00 .. 210.00 V 85.00 V Undervoltage threshold for pickup 5513 Delay Gen. CB 0.00 .. 60.00 sec 0.50 sec Trip time delay generator CB 5514 Delay Grid CB 0.00 .. 60.00 sec 1.50 sec Trip time delay grid CB SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 145 Functions 2.9 Undervoltage-controlled reactive power protection (27/Q) Addr. Parameter 5521 Setting Options Default Setting Comments Recl. release OFF ON OFF Reclosure release 5522 U> Reclose 10.00 .. 210.00 V 95.00 V Voltage threshold for reclosure rel. 5523 T Reclose 0.00 .. 3600.00 sec 0.00 sec Reclosure Delay Time 5524 Pos. f-diff 0.01 .. 5.00 Hz 0.05 Hz Pos. f-diff threshold for reclosure rel. 5525 Neg. f-diff -5.00 .. -0.01 Hz -2.50 Hz Neg. f-diff threshold for reclosure rel. 5526A Incl. 27/Q Trip NO YES NO Include 27/Q Trip for reclosure rel. 2.9.4 Information List No. Information Type of Information Comments 6401 >27/Q Block SP >QV-Protection Blocked 6411 27/Q OFF OUT 27/Q -Protection off 6412 27/Q block OUT 27/Q -Protection blocked 6413 27/Q ACT OUT 27/Q -Protection active 6421 27/Q Gen TRIP OUT 27/Q -Protection Gen TRIP 6422 27/Q Grid TRIP OUT 27/Q -Protection Grid TRIP 6423 27/Q PICKUP OUT 27/Q-Protection PICKUP 6424 Reclosure rel. OUT Reclosure release 6425 27/Q blk.b.Inr. OUT 27/Q pickup blocked by Inrush 146 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.10 Thermal Overload Protection 49 2.10 Thermal Overload Protection 49 The thermal overload protection is designed to prevent thermal overloads from damaging the protected equipment. The protection function represents a thermal replica of the equipment to be protected (overload protection with memory capability). Both the previous history of an overload and the heat loss to the environment are taken into account. Applications * The thermal condition particularly of generators and transformers can be monitored in this way. 2.10.1 Functional Description Thermal Replica The device calculates the overtemperature in accordance with a single-body thermal replica, based on the following differential equation: [thermdifferentialgleichung-260602-kn, 1, en_US] with Present overtemperature related to the final overtemperature at maximum allowed phase current k * Nom Obj. th Thermal time constant of the protected object's heating k Present true r.m.s value of phase current k-factor indicating the maximum permissible constant phase current referred to the nominal current of the protected object Nominal current of protected object Nom Obj. The protection function provides a thermal replica of the protected object (overload protection with memory capability). The history of an overload is taken into consideration. When the calculated overtemperature reaches the first settable threshold 49 ALARM, an alarm annunciation is issued, e.g. to allow time for the load reduction measures to take place. When the calculated overtemperature reaches the second threshold, the protected equipment may be disconnected from the system. The highest overtemperature calculated from the three phase currents is used as the criterion. The maximum thermally permissible continuous current max is described as a multiple of the object nominal currentNom Obj.: max = k * Nom Obj. In addition to the k factor (parameter 49 K-FACTOR) the TIME CONSTANT th and the alarm temperature 49 ALARM (in percent of the trip temperature TRIP) must be specified. Since the 7SJ80 does not offer a connection option for an RTD box, the current temperature is always equal to zero. Overload protection also features a current warning element (I ALARM) in addition to the temperature warning element. The current warning element may report an overload current prematurely, even if the calculated operating temperature has not yet attained the warning or tripping levels. Extension of Time Constants When using the device to protect motors, the varying thermal response at standstill or during rotation may be correctly evaluated. When running down or at standstill, a motor without external cooling looses heat more slowly, and a longer thermal time constant must be used for calculation. For a motor that is switched off, the 7SJ80 increases the time constant th by a programmable factor (k factor). The motor is considered to be off SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 147 Functions 2.10 Thermal Overload Protection 49 when the motor currents drop below a programmable minimum current setting BkrClosed I MIN (refer to "Current Flow Monitoring" in Section 2.1.3 Power System Data 1). For externally-cooled motors, cables and transformers, the K-FACTOR = 1. Blocking The thermal memory may be reset via a binary input (>RES 49 Image) and the current-related overtemperature value is thus reset to zero. The same is accomplished via the binary input (>BLOCK 49 O/L); in this case, the entire overload protection is blocked completely, including the current warning element. When motors must be started for emergency reasons, temperatures above the maximum permissible overtemperatures can be allowed by blocking the trip signal via a binary input (>EmergencyStart). Since the thermal replica may have exceeded the tripping temperature after initiation and dropout of the binary input, the protection function features a programmable run-on time interval (T EMERGENCY) which is started when the binary input drops out and continues suppressing a trip signal. Tripping via the overload protection is suppressed until this time interval has elapsed. The binary input affects only the trip command. There is no effect on the trip log nor does the thermal replica reset. Behavior in Case of Power Supply Failure Depending on the setting in address 235 ATEX100 of Power System Data 1 (see Section 2.1.3 Power System Data 1) the value of the thermal replica is either reset to zero (ATEX100 = NO) if the power supply voltage fails, or cyclically buffered in a non-volatile memory (ATEX100 = YES) so that it is maintained in the event of auxiliary supply voltage failure. In the latter case, the thermal replica uses the stored value for calculation and matches it to the operating conditions. The first option is the default setting (see /5/ Additional description for the protection of explosion-protected motors of protection type increased safety "e"). The following figure shows the logic diagram for the overload protection function. 148 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.10 Thermal Overload Protection 49 [7sj80_ueberlastschutz-061116, 1, en_US] Figure 2-54 Logic diagram of the overload protection 2.10.2 Setting Notes General Overload protection is only in effect if address 142 49 is set to No ambient temp during configuration. If this function is not required, select Disabled. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 149 Functions 2.10 Thermal Overload Protection 49 Transformers and cable are prone to damage by overloads that last for an extended period of time. Overloads cannot and should not be detected by fault protection. Time overcurrent protection should be set high enough to only detect faults since these must be cleared in a short time. Short time delays, however, do neither allow measures to discharge overloaded equipment nor do they permit to take advantage of its (limited) overload capacity. The 7SJ80 devices feature an overload protection function with thermal tripping characteristic adaptable to the overload capability of the equipment being protected (overload protection with memory function). Overload protection can be switched ON or OFF or set to Alarm Only at address 4201 FCT 49. If overload protection is ON, tripping, trip log and fault recording is possible. When setting Alarm Only no trip command is given, no trip log is initiated and no spontaneous fault annunciation is shown on the display. Since the 7SJ80 does not offer a connection option for an RTD box, the current temperature is always equal to zero. The overload protection is intended to protect lines and cables against thermal overload. i NOTE Changing the function parameters resets the thermal replica. The thermal model is frozen (kept constant), as soon as the current exceeds the setting value 1107 I MOTOR START. Overload Parameter k-factor The overload protection is set in reference values. The nominal current Nom Obj. of the protected object (motor, transformer, cable) is used as the basic current for overload protection. By means of the thermal consistently permissible current max, a factor kprim can be calculated: [formel-kfaktor-260602-kn, 1, en_US] The thermally admissible continuous current for the equipment being protected is generally obtainable from manufacturers specifications. For cables, the permissible continuous current is dependent on the crosssection, insulating material, design, and the cable routing, among other things. It can be taken from pertinent tables, or is specified by the cable manufacturer. If no specifications are available, select 1.1 times the nominal current. There are usually no specifications for overhead lines but we can also assume an admissible overload of 10% here. For the 49 K-FACTOR to be set in the device the following applies (address 4202) [fo_einstellwert-kfaktor-allg, 2, en_US] with i max prim Permissible thermal primary current of the motor Nom Obj. Nominal current of the protected object NomCT prim Nominal primary CT current NOTE The setting for 49 K-FACTOR (address 4202) has always to be made as a secondary value. Example: Belted cable 10 kV, 150 mm2: Permissible continuous current 150 max = 322 A SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.10 Thermal Overload Protection 49 Nominal current with k-factor 1.1 Nom Obj. = 293 A Current Transformer 600 A/1 A Setting value FACTOR K: [fo_einstellwert-k-faktor_02, 1, en_US] Time Constant In lines and cables it is only the thermal time constant that is decisive for reaching the temperature rise limit. For cable protection, the heat-gain time constant is determined by cable specifications and by the cable environment. If no time-constant specification is available, it may be determined from the short-term load capability of the cable. The 1-sec current, i.e. the maximum current permissible for a one-second period of time, is often known or available from tables. Then, the time constant may be calculated with the formula: [einstellwert-tau-260602-kn, 1, en_US] If the short-term load capability is given for an interval other than one second, the corresponding short-term current is used in the above formula instead of the 1-second current, and the result is multiplied by the given duration. For example, if the 0.5-second current rating is known: [einstellwert-tau-05s-260602-kn, 1, en_US] It is important to note, however, that the longer the effective duration, the less accurate the result. Example: Cable and current transformer with the following data: Permissible continuous current max = 500 A at u = 40 C Maximum current for 1 s 1s = 45 * max = 22.5 kA Current transformer 600 A/1 A Thus results: [fo_faktor-k, 1, en_US] [formel-tau-3375-260602-kn, 1, en_US] The settings are: 49 K-FACTOR = 0.54; TIME CONSTANT = 33.75 min Current Limitation To ensure that the overload protection, on occurrence of high fault currents (and with small time constants), does not result in extremely short trip times thereby perhaps affecting time grading of the fault protection, the thermal model is frozen (kept constant) as soon as the current exceeds the threshold value 1107 I MOTOR START. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 151 Functions 2.10 Thermal Overload Protection 49 Warning Elements By setting the thermal warning element 49 ALARM (address 4204), a warning message can be issued before reaching the tripping temperature. Tripping can thus be avoided by initiating early load reduction measures. This warning element simultaneously represents the dropout level for the trip signal. Only when this threshold is undershot, the tripping command will be reset and the protected equipment can be switched on again. The thermal element level is given in % of the tripping overtemperature. A current warning level is also available (parameter 4205 I ALARM). The setting is set as the secondary current in A (mperes) and should be equal to or slightly less than the permissible current k * Nom sec . It can be used instead of the thermal warning element by setting the thermal warning element to 100 % thus virtually disabling it. Dropout Time after Emergency Starting This function is not required for protection of lines and cables. Since it is activated by a binary input message, parameter T EMERGENCY (address 4208) is not in effect. The factory setting can be retained. 2.10.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 4201 C Setting Options Default Setting Comments FCT 49 OFF ON Alarm Only OFF 49 Thermal overload protection 4202 49 K-FACTOR 0.10 .. 4.00 1.10 49 K-Factor 4203 TIME CONSTANT 1.0 .. 999.9 min 100.0 min Time Constant 4204 49 ALARM 4205 I ALARM 4207A K-FACTOR 4208A T EMERGENCY 50 .. 100 % 90 % 49 Thermal Alarm Stage 1A 0.10 .. 4.00 A 1.00 A 5A 0.50 .. 20.00 A 5.00 A Current Overload Alarm Setpoint 1.0 .. 10.0 1.0 Kt-FACTOR when motor stops 10 .. 15000 sec 100 sec Emergency time 2.10.4 Information List No. Information Type of Information Comments 1503 >BLOCK 49 O/L SP >BLOCK 49 Overload Protection 1507 >EmergencyStart SP >Emergency start of motors 1511 49 O / L OFF OUT 49 Overload Protection is OFF 1512 49 O/L BLOCK OUT 49 Overload Protection is BLOCKED 1513 49 O/L ACTIVE OUT 49 Overload Protection is ACTIVE 1515 49 O/L I Alarm OUT 49 Overload Current Alarm (I alarm) 1516 49 O/L Alarm OUT 49 Overload Alarm! Near Thermal Trip 1517 49 Winding O/L OUT 49 Winding Overload 1521 49 Th O/L TRIP OUT 49 Thermal Overload TRIP 1580 >RES 49 Image SP >49 Reset of Thermal Overload Image 152 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.10 Thermal Overload Protection 49 No. Information Type of Information Comments 1581 49 Image res. OUT 49 Thermal Overload Image reset SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 153 Functions 2.11 Monitoring Functions 2.11 Monitoring Functions The device is equipped with extensive monitoring capabilities - both for hardware and software. In addition, the measured values are also constantly monitored for plausibility, therefore, the current transformer and voltage transformer circuits are largely integrated into the monitoring. 2.11.1 Measurement Supervision 2.11.1.1 General The device monitoring extends from the measuring inputs to the binary outputs. Monitoring checks the hardware for malfunctions and abnormal conditions. Hardware and software monitoring described in the following are enabled continuously. Settings (including the possibility to activate and deactivate the monitoring function) refer to the monitoring of external transformer circuits or the measurement voltage failure detection. 2.11.1.2 Hardware Monitoring Auxiliary and Reference Voltages Failure of or switching off the supply voltage removes the device from operation and a message is immediately generated by a normally closed contact. Brief auxiliary voltage interruptions of less than 50 ms do not disturb the readiness of the device (for nominal auxiliary voltage > 110 VDC). Buffer Battery The buffer battery, which ensures operation of the internal clock and storage of counters and messages if the auxiliary voltage fails, is periodically checked for charge status. If it is less than an allowed minimum voltage, then the Fail Battery message is issued. Memory Components All working memories (RAMs) are checked during startup. If a malfunction occurs then, the starting sequence is interrupted and an LED blinks. During operation the memories are checked with the help of their checksum. For the program memory, the cross sum is formed cyclically and compared to the stored program cross sum. For the settings memory, the cross sum is formed cyclically and compared to the cross sum that is freshly generated each time a setting process takes place. If a fault occurs the processor system is restarted. Scanning Scanning and the synchronization between the internal buffer components are constantly monitored. If any deviations cannot be removed by renewed synchronization, then the processor system is restarted. Measurement Value Acquisition - Currents The monitoring of the device-internal measured-value acquisition of the currents can be effected via the current sum monitoring. Up to four input currents are measured by the device. If the three phase currents and the ground current from the current transformer neutral point are connected with the device, the sum of the four digitized currents must be zero. This also applies in the event of a possible transformer saturation. For that reason - in order to eliminate pickup upon transformer saturation - this function is only available in a Holmgreen-connection (see also Section 2.1.3.2). Faults in the current circuits are recognized if F = | iA + iB + iC + iE | > I THRESHOLD + I FACTOR * | | I THRESHOLD (address 8106) and I FACTOR (address 8107) are setting parameters. The component I FACTOR * | | takes into account the permissible current proportional ratio errors of the input transducers 154 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions which are particularly prevalent during large short-circuit currents (Figure 2-55). The dropout ratio is about 97 %. [stromsummenueberwachung-020313-kn, 1, en_US] Figure 2-55 Current sum monitoring An error in the current sum results in the message Failure I (No. 162) and blocking of the protection function. Furthermore, a fault log is initiated for a period of 100 ms. The monitoring can be switched off. The monitoring is available subject to the following conditions: * The three phase currents are connected to the device (address 251 A, B, C, (Gnd)) * The ground current of the current transformer neutral point is connected to the fourth current input (4) (Holmgreen-connection). This is communicated to the device in the Power System Data 1 via address 280 YES. * The fourth current input is normally designed for a 4-transformer. In case of a sensitive transformer type, this monitoring is not available. * * The settings CT PRIMARY (address 204) and Ignd-CT PRIM (address 217) must be the same. The settings CT SECONDARY (address 205) and Ignd-CT SEC (address 218) must be the same. The following logic diagram illustrates the operational mode of the current sum monitoring. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 155 Functions 2.11 Monitoring Functions [7sj6x-stromsummenueberw-20070315, 1, en_US] Figure 2-56 i Logic Diagram of the fast current sum monitoring NOTE If the current input IN is configured as a sensitive transformer or if the connection mode A,G2,C,G; G>B or A,G2,C,G; G2->B was set for the current transformers at parameter 251 CT Connect., current sum monitoring is not possible. AD Transformer Monitoring The digitized sampled values are being monitored in respect of their plausibility. If the result is not plausible, message 181 Error A/D-conv. is issued. The protection is blocked, thus preventing unwanted operation. Furthermore, a fault record is generated for recording of the internal fault. 2.11.1.3 Software Monitoring Watchdog For continuous monitoring of the program sequences, a time monitor is provided in the hardware (hardware watchdog) that expires upon failure of the processor or an internal program, and causes a complete restart of the processor system. An additional software watchdog ensures that malfunctions during the processing of programs are discovered. This also initiates a restart of the processor system. If such a malfunction is not cleared by the restart, an additional restart attempt is begun. After three unsuccessful restarts within a 30 second window of time, the device automatically removes itself from service and the red "Error" LED lights up. The readiness relay drops out and indicates device malfunction" with its normally closed contact. Offset Monitoring This monitoring function checks all ring buffer data channels for corrupt offset replication of the analog/digital transformers and the analog input paths using offset filters. Possible offset errors are detected using DC filters, and the associated sampled values are corrected up to a specific limit. If this limit is exceeded, an indication is generated (191 Error Offset) and integrated into the warning group indication (160). As increased offset values impair the measurements, we recommend sending the device to the OEM plant for corrective action should this indication persist. 156 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions 2.11.1.4 Monitoring of the Transformer Circuits Open circuits or short circuits in the secondary circuits of the current and voltage transformers, as well as faults in the connections (important during commissioning!), are detected and reported by the device. The measured quantities are periodically checked in the background for this purpose, as long as no system fault is present. Current Symmetry During normal system operation, symmetry among the input currents is expected. The monitoring of the measured values in the device checks this balance. The smallest phase current is compared to the largest phase current. Asymmetry is detected if | min | / | max | < BAL. FACTOR I as long as max > BALANCE I LIMIT is valid. Thereby max is the largest of the three phase currents and Imin the smallest. The symmetry factor BAL. FACTOR I (address 8105) represents the allowable asymmetry of the phase currents while the limit value BALANCE I LIMIT (address 8104) is the lower limit of the operating range of this monitoring (see Figure 2-57). Both parameters can be set. The dropout ratio is about 97 %. This fault is signalled after settable delay time with Fail I balance. [stromsymmetrieueberwachung-020313-kn, 1, en_US] Figure 2-57 Current symmetry monitoring Voltage Symmetry During normal system operation, balance among the voltages is expected. Since the phase-to-phase voltages are insensitive to ground faults, the phase-to-phase voltages are used for balance monitoring. If the device is connected to the phase-to-ground voltages, then the phase-to-phase voltages are calculated accordingly, whereas, if the device is connected to phase-to-phase voltages and the displacement voltage V0, then the third phase-to-phase voltage is calculated accordingly. From the phase-to-phase voltages, the device generates the rectified average values and checks the balance of their absolute values. The smallest phase voltage is compared with the largest phase voltage. Asymmetry is recognized if | Vmin | / | Vmax | < BAL. FACTOR V as long as | Vmax | > BALANCE V-LIMIT. Where Vmax is the highest of the three voltages and Vmin the smallest. The symmetry factor BAL. FACTOR V (address 8103) represents the allowable asymmetry of the conductor voltages while the limit value BALANCE V-LIMIT (address 8102) is the lower limit of the operating range of this monitoring (see Figure 2-70). Both parameters can be set. The dropout ratio is about 97%. This fault is signalled after settable delay time with Fail V balance. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 157 Functions 2.11 Monitoring Functions [spannungssymmetrieueberwachung-020313-kn, 1, en_US] Figure 2-58 i Voltage symmetry monitoring NOTE If the connection mode Vph-g, VSyn was set for the voltage transformers at parameter 213 VT Connect. 3ph, voltage symmetry monitoring is not possible. Phase Sequence of Voltage and Current To detect swapped phase connections in the voltage and current input circuits, the phase sequence of the phase-to-phase measured voltages and the phase currents are checked by monitoring the sequence of same polarity zero crossing of the voltages. Direction measurement with normal voltages, path selection for fault location, and negative sequence detection all assume a phase sequence of "abc". Phase rotation of measurement quantities is checked by verifying the phase sequences. For that purpose, the phase-sequence monitoring uses the phase-to-phase voltages VA2, VB3, VC1. Voltages: VA2 before VB3 vor VC1 and Currents: A before B before C. Verification of the voltage phase rotation is done when each measured voltage is at least |VA2|, |VB3|, |VC1| > 40 V Verification of the current phase rotation is done when each measured current is at least: |A|, |B|, |C| > 0.5 N. For abnormal phase sequences, the messages Fail Ph. Seq. V or Fail Ph. Seq. I are issued, along with the switching of this message Fail Ph. Seq.. For applications in which an opposite phase sequence is expected, the protective relay should be adjusted via a binary input or the respective parameter PHASE SEQ. (address 209). If the phase sequence is changed in the relay, phases B and C internal to the relay are reversed, and the positive and negative sequence currents are thereby exchanged (see also Section 2.21.2 Setting Notes). The phase-related messages, malfunction values, and measured values are not affected by this. 2.11.1.5 Measurement Voltage Failure Detection Requirements The measuring voltage failure detection function - referred to as "Fuse Failure Monitor" (FFM) - only operates if parameter 213 VT Connect. 3ph is set to Van, Vbn, Vcn or Vab, Vbc, VGnd. With all other voltage transformer connection modes, FFM is not operative. 158 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions Purpose of the Fuse Failure Monitor In case of a measuring voltage failure caused by a fault or a broken wire in the voltage transformer secondary system, a zero voltage can be simulated to individual measuring loops. The displacement voltage element of the (sensitive) ground fault detection, the directional overcurrent protection and the undervoltage protection can thereby acquire incorrect measuring results. The blocking of this function by the FFM is configurable. The FFM can become effective in grounded as well as in isolated systems provided that the connection mode Van, Vbn, Vcn or Vab, Vbc, VGnd was set. Of course, the miniature circuit breaker and FFM can also be used for the detection of a measuring voltage failure at the same time. The displacement voltage element of the (sensitive) ground fault detection, the time overcurrent protection ground and the undervoltage protection can thereby obtain incorrect measuring results. Mode of Operation - Grounded System The device is informed of the application of the FFM in a grounded system via address 5301 FUSE FAIL MON. Solid grounded. i NOTE On systems where the ground fault current is very small or absent (e.g. ungrounded supply transformers), fuse failure monitoring must be disabled or set to Coil.gnd./isol.. The logic diagram on the operating mode in a grounded system is illustrated in Figure 2-59. Depending on the configuration and MLFB, the FFM operates with measured or calculated values VN or N. If zero sequence voltage occurs without a ground fault current being registered simultaneously, then there is an asymmetrical fault in the secondary circuit of the voltage transformer. The displacement voltage element of the (sensitive) ground fault detection, the directional overcurrent protection (phase and ground function) and the undervoltage protection are blocked if parameter 5310 BLOCK PROT. is set to YES. The FFM picks up if the ground voltage VN is higher than the set limit value under address5302 FUSE FAIL 3Vo and if the ground current IN lies below the set limit value under address 5303 FUSE FAIL RESID. Pickup occurs in accordance with the configured values. A hysteresis of 105% for the dropout is integrated for N or 95% for VN. In case of low-current asymmetrical faults in systems with week infeed, the ground current caused by the fault could lie below the pickup threshold of the Fuse Failure Monitor. Overfunctioning of the Fuse Failure Monitor can, however, cause the feeder protection device to underfunction since all protection functions that use voltage signals are blocked. In order to prevent overfunctioning of the FFM, the phase currents are also checked. If at least one phase current lies above the pickup threshold of 5303 FUSE FAIL RESID, it can be assumed that the zero current created by a fault will equally exceed this threshold. In order to immediately detect an existing fault after switching in, the following applies: If a ground current N is detected within 10 seconds after recognition of the Fuse Failure criterion, the protection assumes a fault and removes the blocking by the Fuse Failure Monitor for the duration of the fault. If, on the other hand, the voltage failure criterion is present for longer than approx. 10 s, the blocking is permanently activated. After this time has elapsed, it can be assumed that a fuse failure has actually occurred. Only 10 s after the voltage criterion has been removed by correction of the secondary circuit failure, will the blocking automatically reset, thereby releasing the blocked protection functions. The generation of the internal signal "Alarm FFM" for the operation in isolated systems is shown in Figure 2-60. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 159 Functions 2.11 Monitoring Functions [7sj80-fuse-failure-monitor-20061215, 1, en_US] Figure 2-59 Logic diagram of the Fuse Failure Monitor for grounded networks only Mode of Operation - Isolated System and 3-phase Fuse Failure The FFM can also function in isolated and compensated (grounded) systems where only low ground currents are expected. This is indicated to the device via address 5301 FUSE FAIL MON.. The logic diagram on the functioning in an isolated system and for 3-phase fuse failure is shown in Figure 2-60. The following is a description of the principles for 1-phase, 2-phase and 3-phase faults in a secondary voltage transformer system. If this part of the FFM logic picks up, the internal signal "Alarm FFM" is generated. The processing of this signal is shown in Figure 2-59. i 160 NOTE In isolated systems, only the following logic is used. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions [7sj80-ffm-messspg-ausfall-20120611, 2, en_US] Figure 2-60 Logic diagram of the Fuse Failure Monitor for isolated and grounded systems Single- and Two-phase Failures in Voltage Transformer Circuits The measuring voltage failure detection is based on the fact that a significant negative sequence system is formed in the voltage during single- or two-phase voltage failure, however without influencing the current. This enables a clear distinction from asymmetries impressed by the power system. If the negative sequence system is related to the current positive sequence system, the following rules apply to the Fault-free Case: [u2-u1-fehlerfreier-fall-020828-ho, 1, en_US] If a fault occurs in the voltage transformer secondary system, the following rules apply to the Single-phase Failure: SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 161 Functions 2.11 Monitoring Functions [u2-u1-einpoliger-ausfall-020828-ho, 1, en_US] If a fault occurs in the voltage transformer secondary system, the following rules apply to the Two-phase Failure: [u2-u1-zweipoliger-ausfall-020828-ho, 1, en_US] In case of a failure of one or two phases of the primary system, the current also shows a negative sequence system of 0.5 or 1. Consequently, the voltage monitoring does not respond since no voltage transformer fault can be present. In order to avoid occurrence of an overfunctioning of the measuring voltage failure detection due to inaccuracy, the function is blocked below a minimum threshold of the positive sequence systems of voltage (V1 < 0.1 VNom) and current (1 < 0.1 Nom). If the absolute values of the positive or negative sequence voltage are below 20 % of VNom /3, the 1-pole or 2pole FFM detection is blocked. Three-phase Failures in Voltage Transformer Circuits A 3-phase failure in the voltage transformer secondary system cannot be detected via the positive- and negative- sequence system as described above. The monitoring of the progress of current and voltage over time is required here. If a voltage dip to almost zero occurs (or if the voltage is zero), and the current remains unchanged, a 3-phase failure in the voltage transformer secondary system can be concluded. The jump detection is used for this purpose. The sensitivity of the jump detection for current can be increased via parameter FFM Idiff (3ph). 2.11.1.6 Broken Wire Monitoring of Voltage Transformer Circuits Requirements This function is only available in device version "World" or "Chinese" Ordering Information Pos. 10 = B or K), as it is only used in certain regions. Furthermore, the measurement of all three phase-to-ground voltages (Van, Vbn, Vcn) is a requirement. If only two phase-to-phase voltages were measured, it would not be possible to evaluate two of the required criteria. Task The "Broken Wire" monitoring function monitors the voltage transformer circuits of the secondary system with regard to failure. One distinguishes between single-phase, two-phase and three-phase failures. Mode of Operation / Logic All three phase-to-ground voltages, the displacement voltage and the three phase currents are measured. The required values are calculated for the respective criteria and eventually a decision is made. The resulting alarm message may be delayed. A blocking of the protection functions is however not effected. This is done by the measuring voltage failure detection. The "Broken Wire" monitoring is also active during a fault. The function may be enabled or disabled. The following logic diagram shows how "Broken Wire" monitoring functions. 162 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions [logik-broken-wire-070502-st, 1, en_US] Figure 2-61 2.11.1.7 Logic diagram for broken wire monitoring Setting Notes Measured Value Monitoring The sensitivity of measured value monitor can be modified. Default values which are sufficient in most cases are preset. If especially high operating asymmetries in the currents and/or voltages are to be expected during operation, or if it becomes apparent during operation that certain monitoring functions activate sporadically, then the setting should be less sensitive. Address 8102 BALANCE V-LIMIT determines the limit voltage (phase-to-phase) above which the voltage symmetry monitor is effective. Address 8103 BAL. FACTOR V is the associated symmetry factor; that is, the slope of the symmetry characteristic curve. In address 8110 T BAL. V LIMIT you set the delay time of fault message no. 167 Fail V balance. Address 8104 BALANCE I LIMIT determines the limit current above which the current symmetry monitor is effective. Address 8105 BAL. FACTOR I is the associated symmetry factor; that is, the slope of the symmetry characteristic curve. In address 8111 T BAL. I LIMIT you set the delay time for fault message no. 163 Fail I balance. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 163 Functions 2.11 Monitoring Functions Address 8106 I THRESHOLD determines the limit current above which the current sum monitoring is activated (absolute portion, only relative to Nom). The relative portion (relative to the maximum conductor current) for activating the current sum monitor is set at address 8107 I FACTOR. i NOTE Current sum monitoring can operate properly only when the residual current of the protected line is fed to the fourth current input (N) of the relay (see Power System Data 1). Furthermore, the fourth current input (N) may not be sensitive. i NOTE The connections of the ground paths and their adaption factors were set when configuring the general Power System Data. These settings must be correct for the measured values monitoring to function properly. Measured value monitoring can be set to ON or OFF at address 8101 MEASURE. SUPERV. Fuse Failure Monitor (FFM) Via address 5301 FUSE FAIL MON. you select under which system conditions the FFM works. Depending on that, make the required settings in the grounded system via the parameters 5302, 5303 and 5308. In a grounded/isolated system, only the parameter 5308 is relevant. The settings for the fuse failure monitor must be selected in such manner that reliable activation occurs if a phase voltage fails, but that false activation does not occur during ground faults in a grounded network. Address 5303 FUSE FAIL RESID must be set as sensitive as required (with ground faults, below the smallest fault current). The FFM picks up if the ground voltage VN is higher than the set limit value under address 5302 FUSE FAIL 3Vo and if the ground current IN lies below the set limit value under address 5303 FUSE FAIL RESID. In order to detect a three-phase failure, the progress in time of current and voltage is monitored. If the voltage sinks below the threshold value without a change in the current value, a three-phase failure is detected. This threshold value of the current element must be set under address 5308 FFM Idiff (3ph). The threshold value should be identical with the definite time overcurrent protection. Under address 5310 BLOCK PROT. it can be determined whether the protection functions should be blocked upon pickup by the FFM. i NOTE The setting under address 5310 BLOCK PROT. has no effect on the flexible protection functions. A separate blocking can be selected for that purpose. The function may be disabled in address 5301 FUSE FAIL MON., e.g. when performing asymmetrical tests. 2.11.1.8 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 5201 Setting Options Default Setting Comments VT BROKEN WIRE ON OFF OFF VT broken wire supervision 5202 V> 1.0 .. 100.0 V 8.0 V Threshold voltage sum 5203 Vph-ph max< 1.0 .. 100.0 V 16.0 V Maximum phase to phase voltage 164 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions Addr. Parameter 5204 C Setting Options Default Setting Comments Vph-ph min< 1.0 .. 100.0 V 16.0 V Minimum phase to phase voltage 5205 Vph-ph max-min> 10.0 .. 200.0 V 16.0 V Symmetry phase to phase voltages 5206 I min> 1A 0.04 .. 1.00 A 0.04 A Minimum line current 5A 0.20 .. 5.00 A 0.20 A 5208 T DELAY ALARM 0.00 .. 32.00 sec 1.25 sec Alarm delay time 5301 FUSE FAIL MON. OFF Solid grounded Coil.gnd./isol. OFF Fuse Fail Monitor 5302 FUSE FAIL 3Vo 5303 FUSE FAIL RESID 5308A FFM Idiff (3ph) 5310 BLOCK PROT. 8101 10 .. 100 V 30 V Zero Sequence Voltage 1A 0.10 .. 1.00 A 0.10 A Residual Current 5A 0.50 .. 5.00 A 0.50 A 1A 0.05 .. 1.00 A 0.10 A 5A 0.25 .. 5.00 A 0.50 A Differential Current Threshold (3phase) NO YES YES Block protection by FFM MEASURE. SUPERV OFF ON ON Measurement Supervision 8102 BALANCE V-LIMIT 10 .. 100 V 50 V Voltage Threshold for Balance Monitoring 8103 BAL. FACTOR V 0.58 .. 0.90 0.75 Balance Factor for Voltage Monitor 8104 BALANCE I LIMIT 1A 0.10 .. 1.00 A 0.50 A 5A 0.50 .. 5.00 A 2.50 A Current Threshold for Balance Monitoring 8105 BAL. FACTOR I 0.10 .. 0.90 0.50 Balance Factor for Current Monitor 8106 I THRESHOLD 1A 0.05 .. 2.00 A; 0.10 A 5A 0.25 .. 10.00 A; 0.50 A Summated Current Monitoring Threshold 8107 I FACTOR 0.00 .. 0.95 0.10 Summated Current Monitoring Factor 8109 FAST i MONIT OFF ON ON Fast Summated Current Monitoring 8110A T BAL. V LIMIT 0 .. 100 sec 5 sec T Balance Factor for Voltage Monitor 8111A T BAL. I LIMIT 0 .. 100 sec 5 sec T Current Balance Monitor 2.11.1.9 Information List No. Information Type of Information Comments 161 Fail I Superv. OUT Failure: General Current Supervision 162 Failure I OUT Failure: Current Summation 163 Fail I balance OUT Failure: Current Balance 167 Fail V balance OUT Failure: Voltage Balance 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 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 165 Functions 2.11 Monitoring Functions No. Information Type of Information Comments 175 Fail Ph. Seq. I OUT Failure: Phase Sequence Current 176 Fail Ph. Seq. V OUT Failure: Phase Sequence Voltage 197 MeasSup OFF OUT Measurement Supervision is switched OFF 253 VT brk. wire OUT Failure VT circuit: broken wire 255 Fail VT circuit OUT Failure VT circuit 256 VT b.w. 1 pole OUT Failure VT circuit: 1 pole broken wire 257 VT b.w. 2 pole OUT Failure VT circuit: 2 pole broken wire 258 VT b.w. 3 pole OUT Failure VT circuit: 3 pole broken wire 6509 >FAIL:FEEDER VT SP >Failure: Feeder VT 6510 >FAIL: BUS VT SP >Failure: Busbar VT 2.11.2 Trip Circuit Supervision 74TC Devices 7SJ80 are equipped with an integrated trip circuit supervision. 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 allocation of the required binary inputs does not match the selected supervision type, then a message to this effect is generated (74TC ProgFail). Applications * 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. Prerequisites A requirement for the use of trip circuit supervision is that the control voltage for the circuit breaker is at least twice the voltage drop across the binary input (VCt > 2 * VBImin). Since at least 19 V are needed for the binary input, the supervision can only be used with a system control voltage of over 38 V. 2.11.2.1 Functional Description Supervision with Two Binary Inputs When using two binary inputs, these are connected according to Figure 2-62, parallel to the associated trip contact on one side, and parallel to the circuit breaker auxiliary contacts on the other. 166 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions [prinzip-ausloesekreisueberwachung-2-binein-150502-kn, 1, en_US] Figure 2-62 Principle of the trip circuit supervision with two binary inputs 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 Table 2-9), or not activated (logical condition "L"). In healthy trip circuits the condition that both binary inputs are not actuated ("L") is only possible during a short transition period (trip contact is closed but the circuit breaker has not yet opened). 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 2-9 Condition table for binary inputs, depending on RTC and CB position No. Trip contact Circuit breaker 1 Open Closed 2 Open Open 3 Closed Closed 4 Closed Open 52a Contact 52b Contact BI 1 BI 2 Closed Open H L Open Closed H H Closed Open L L Open Closed L H The conditions of the two binary inputs are checked periodically. A check takes place about every 600 ms. If three consecutive conditional checks detect an abnormality (after 1.8 s), an annunciation is reported (see Figure 2-63). The repeated measurements determine the delay of the alarm message and avoid that an alarm is output during short transition periods. After the malfunction in the trip circuit is cleared, the fault annunciation is reset automatically after the same time period. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 167 Functions 2.11 Monitoring Functions [7sj6x_ausloesekreis_2_binaerein-150502-kn, 1, en_US] Figure 2-63 Logic diagram of the trip circuit supervision with two binary inputs Supervision with One Binary Input The binary input is connected according to the following figure in parallel with the associated trip contact of the protection relay. The circuit breaker auxiliary contact is bridged with a bypass resistor R. [prinzip-ausloesekreisueberwachung-1-binein-150502-kn, 1, en_US] Figure 2-64 Trip circuit supervision with one binary input 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 monitoring circuit is closed by either the 52a circuit breaker auxiliary contact (if the circuit breaker is closed) or through the bypass resistor R by the 52b circuit breaker auxiliary contact. Only as long as the trip contact is closed, the binary input is short circuited and thereby deactivated (logical condition "L"). If the binary input is continuously deactivated during operation, this leads to the conclusion that there is an interruption in the trip circuit or loss of control voltage. As the trip circuit supervision does not operate during system faults, the closed trip contact does not lead to a fault message. If, however, tripping contacts from other devices operate in parallel with the trip circuit, then the fault message must be delayed (see also Figure 2-65). The delay time can be set via parameter 8202 Alarm Delay. A message is only released after expiry of this time. After clearance of the fault in the trip circuit, the fault message is automatically reset. [7sj6x_ausloesekreis_1_binaerein-050906-he, 1, en_US] Figure 2-65 168 Logic diagram of trip circuit supervision with one binary input SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions The following figure shows the logic diagram for the message that can be generated by the trip circuit monitor, depending on the control settings and binary inputs. [7sj6x_ausloesekreis_meldelogik-150502-kn, 1, en_US] Figure 2-66 2.11.2.2 Message logic for trip circuit supervision Setting Notes General The function is only effective and accessible if address 182 (Section 2.1.1.2 Setting Notes) was set to either 2 Binary Inputs or 1 Binary Input during configuration, the appropriate number of binary inputs has been configured accordingly for this purpose and the function FCT 74TC is ON at address 8201. If the allocation of the required binary inputs does not match the selected supervision type, a message to this effect is generated (74TC ProgFail). If the trip circuit monitor is not to be used at all, then Disabled is set at address 182. In order to ensure that the longest possible duration of a trip command can be reliably bridged, and an indication is generated in case of an actual fault in the trip circuit, the indication regarding a trip circuit interruption is delayed. The time delay is set under address 8202 Alarm Delay. Supervision with One Binary Input Note: When using only one binary input (BI) for the trip circuit monitor, malfunctions, such as interruption of the trip circuit or loss of battery voltage are detected in general, but trip circuit failures while a trip command is active cannot be detected. Therefore, the measurement must take place over a period of time that bridges the longest possible duration of a closed trip contact. This is ensured by the fixed number of measurement repetitions and the time between the state checks. When using only one binary input, a resistor R is inserted into the circuit on the system side, instead of the missing second binary input. Through appropriate sizing of the resistor and depending on the system conditions, a lower control voltage is mostly sufficient. Information for dimensioning resistor R is given in the Chapter "Installation and Commissioning" under Configuration Notes in the Section "Trip Circuit Supervision". 2.11.2.3 Settings Addr. Parameter Setting Options Default Setting Comments 8201 FCT 74TC ON OFF ON 74TC TRIP Circuit Supervision SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 169 Functions 2.11 Monitoring Functions Addr. Parameter Setting Options Default Setting Comments 8202 Alarm Delay 1 .. 30 sec 2 sec Delay Time for alarm 2.11.2.4 Information List No. Information Type of Information Comments 6851 >BLOCK 74TC SP >BLOCK 74TC 6852 >74TC trip rel. SP >74TC Trip circuit superv.: trip relay 6853 >74TC brk rel. SP >74TC Trip circuit superv.: bkr relay 6861 74TC OFF OUT 74TC Trip circuit supervision OFF 6862 74TC BLOCKED OUT 74TC Trip circuit supervision is BLOCKED 6863 74TC ACTIVE OUT 74TC Trip circuit supervision is ACTIVE 6864 74TC ProgFail OUT 74TC blocked. Bin. input is not set 6865 74TC Trip cir. OUT 74TC Failure Trip Circuit 2.11.3 Malfunction Responses of the Monitoring Functions In the following malfunction responses of monitoring equipment are clearly listed. 2.11.3.1 Description Malfunction Responses Depending on the type of malfunction discovered, an annunciation is sent, a restart of the processor system is initiated, or the device is taken out of service. After three unsuccessful restart attempts, the device is taken out of service. The operational readiness NC contact operates to indicate the device is malfunctioning. Also, the red LED "ERROR" lights up on the front cover, if the internal auxiliary voltage is present, and the green "RUN" LED goes out. If the internal auxiliary voltage fails, all LEDs are dark. Table 2-10 provides a summary of the monitoring functions and the malfunction responses of the relay. Table 2-10 Summary of malfunction responses by the protection relay Monitoring Possible Causes Malfunction Response Message (No.) Output AC/DC supply voltage loss External (Nominal voltage) internal (power supply) Device shutdown All LEDs dark DOK2) drops out Buffer battery Internal (buffer battery) Message Fail Battery (177) Hardware watchdog Internal (processor failure) Device shutdown1) LED "ERROR" DOK2) drops out Software watchdog Internal (processor failure) Restart attempt 1) LED "ERROR" DOK2) drops out Working memory ROM Internal (hardware) Relay aborts restart, device shutdown LED blinkt DOK2) drops out Program memory RAM Internal (hardware) During boot sequence LED "ERROR" DOK2) drops out Detection during oper- LED "ERROR" ation: Restart attempt1) 170 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.11 Monitoring Functions Monitoring Possible Causes Malfunction Response Message (No.) Output Settings memory Internal (hardware) Restart attempt 1) LED "ERROR" DOK2) drops out Sampling frequency Internal (hardware) Device shutdown LED "ERROR" DOK2) drops out Measured value acquisition External (hardware) Blocking by the protec- Error A/D-conv. tion function (181), LED "ERROR" DOK2) drops out Error in the I/O-board Internal (hardware) Device shutdown DOK2) drops out Offset monitoring Internal (hardware) Device shutdown I/O-Board error (178), LED "ERROR" Error Offset (191) Current sum Internal (measured value acquisition) Device shutdown Failure I (162) DOK2) drops out Current symmetry External (power system or current transformer) Message Fail I balance (163) As allocated Voltage symmetry External (power system or voltage transformer) Message Fail V balance (167) As allocated Voltage phase sequence External (power system or connection) Message Fail Ph. Seq. V 176) As allocated Current phase sequence External (power system or connection) Message Fail Ph. Seq. I (175) As allocated Fuse Failure Monitor External Message (voltage transformer) As allocated Trip circuit monitoring External (trip circuit or control voltage) Message Secondary voltage transformer circuit monitoring External (voltage transformer circuit interruption) Message VT FuseFail>10s (169) VT FuseFail (170) 74TC Trip cir. (6865) VT brk. wire (253) Calibration data fault Internal (hardware) Message Alarm NO calibr (193) As allocated 1) After 2) DOK DOK2) drops out As allocated As allocated three unsuccessful restart attempts, the device is shut down. = "Device Okay" = Ready for service relay drops off, protection and control functions are blocked. Group Alarms Certain messages of the monitoring functions are already combined to group alarms. A listing of the group alarms and their composition is given in the Appendix F.4 Group Alarms. In this case, it must be noted that message 160 Alarm Sum Event is only issued when the measured value monitoring functions (8101 MEASURE. SUPERV) are activated. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 171 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) Depending on the variant, the fourth current input of the multi-functional protection relays Depending on the variant, the fourth current input of the multi-functional protection relays 7SJ62/64 is equipped either with a sensitive input transformer or a standard transformer for 1/5 A. is equipped either with a sensitive input transformer or a standard transformer for 1/5 A. In the first case, the protective function is designed for ground fault detection in isolated or compensated systems due to its high sensitivity. It is not really suited for ground fault detection with large ground currents since the linear range is transcended at about 1.6 A at the sensitive ground fault detection relay terminals. If the relay is equipped with a standard transformer for 1/5 A currents, large currents can also be detected correctly. This function can operate in two modes. The standard procedure, the "cos-- / sin- measurement", evaluates the part of the ground current perpendicular to the settable directional characteristic. The second procedure, the "U0/I0- measurement", calculates the angle between ground current and displacement voltage. For this procedure, two different directional characteristics can be set. Applications * Sensitive ground fault detection may be used in isolated or compensated systems to detect ground faults, to determine phases affected by ground faults, and to specify the direction of ground faults. * In solidly or low-resistance grounded systems, sensitive ground fault detection is used to detect high impedance ground faults. * This function can also be used as supplementary ground fault protection. 2.12.1 Ground Fault Detection for cos- / sin- Measurement (Standard Method) Voltage Element The voltage element relies on a pickup initiated by the displacement voltage V0 or 3 * V0. Additionally, the faulty phase is determined. The displacement voltage V0 can be directly applied to the device, or the summation voltage 3 * V0 can be calculated according to the connection type of the voltage transformer (see also Parameter 213 VT Connect. 3ph in Section 2.1.3 Power System Data 1). When setting Van, Vbn, Vcn, the calculation of the summation voltage 3 * V0 is based on the three phase-to-ground voltages. The three voltage inputs must therefore be connected to the voltage transformers in a grounded-wye configuration. When setting Vab, Vbc, VGnd, the three phase-to-ground voltages of both connected phase-to-phase voltages and the connected displacement voltage are calculated. If the device is only provided with phase-tophase voltages, it is not possible to calculate a displacement voltage from them. In this case the direction cannot be determined. If the displacement voltage is calculated, then: 3 * V0 = VA + VB + VC If the displacement voltage is directly applied to the device, then V0 is the voltage at the device terminals. It is not affected by parameter Vph / Vdelta (address 206). The displacement voltage is used both to detect a ground fault and to determine direction. When the voltage element picks up, a preset time delay must elapse before detection of the displacement voltage is reported to be able to record stable measurement quantities. The time delay can be configured (T-DELAY Pickup) and its factory setting is 1 s. Pickup performed by the displacement voltage can be delayed (64-1 DELAY) for tripping. It is important to note that the total tripping time then consists of the displacement voltage measurement time (about 50 ms) plus the pickup time delay T-DELAY Pickup Pickup plus the tripping delay 64-1 DELAY. After the voltage element picks up due to detection of a displacement voltage, the grounded phase is identified, if possible. For this purpose, the individual phase-to-ground voltages are measured or calculated, irrespective of the connection type of the voltage transformers. If the voltage magnitude for any given phase falls 172 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) below the set threshold VPH MIN, that phase is detected as the grounded phase as long as the remaining phase-to- ground voltages exceed the set threshold VPH MAX. [7sj6x_erdschlussbehaftete_phase-150502-kn, 1, en_US] Figure 2-67 Determination of Grounded Phase Current Elements The current elements for ground faults operate with the magnitudes of the ground current. It is sensible to employ them only where the magnitude of the ground current can be used to specify the ground fault. This may be the case on grounded systems (solid or low-resistance) or on electrical machines which are directly connected to the busbar of an isolated power system, when in case of a network ground fault the machine supplies only a negligible ground fault current across the measurement location, which must be situated between the machine terminals and the network, whereas in case of a machine ground fault the higher ground fault current produced by the total network is available. Ground current protection is mostly used as backup protection for high resistance ground faults in solid or low resistance grounded systems when the main fault protection does not pickup. For ground current detection,a two-element current/time characteristic can be set. Analogeous to the time overcurrent protection, the high-set current stage is designated as 50Ns-2 PICKUP and 50Ns-2 DELAY and is provided with a definite time characteristic. The overcurrent element may be operated with either a definite time delay (50Ns-1 PICKUP and 50Ns-1 DELAY) or with a user-defined Curve (51Ns PICKUP and 51NsTIME DIAL). The characteristics of these current elements can be configured. Each of these elements may be directional or non-directional. The pickup of the definite time overcurrent protection can be stabilized by the configured dropout delay time (address 3121 50Ns T DROP-OUT). The dropout delay only works if the current stage is operated independently of the voltage stage. Parameter 3130 PU CRITERIA is set to Vgnd OR INs. Determination of Direction When determining the sensitive ground fault direction it is not the current value that is crucial, but the part of the current which is perpendicular to a settable directional characteristic (axis of symmetry). As a prerequisite for determining the direction, the displacement voltage V0 must be exceeded as well as a configurable current part influencing the direction (active or reactive component). The following figure illustrates an example using a complex vector diagram in which the displacement voltage V0 is the reference magnitude of the real axis. The active part 30real of current 30 is calculated with reference SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 173 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) to the displacement voltage V0 and compared with setting value RELEASE DIRECT.. The example is therefore suitable for ground fault direction in resonant grounded systems where quantity 30 * cos is relevant. The directional limit lines are perpendicular to axis 30real. [7sj6-richtungskennlinie-bei-cos-messung-101210, 1, en_US] Figure 2-68 Directional characteristic for cos--measurement The directional limit lines may be rotated by a correction angle (address PHI CORRECTION) up to 45. Therefore, in grounded systems it is possible e.g. to increase sensitivity in the resistive-inductive range with a rotation of -45, or in case of electric machines connected to the busbar of an ungrounded power system in the resistive- capacitive range with a rotation of +45 (see the following Figure). Furthermore the directional limit lines may be rotated by 90 to determine ground faults and their direction in isolated systems. 174 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [richtungskennlinien-260602-kn, 1, en_US] Figure 2-69 Directional characteristic for cos--measurement Fault direction is calculated with the zero sequence values from the ground current 30 and displacement voltage V0 or 3 * V0. With these quantities ground active power and ground reactive power is calculated. The calculation algorithm used filters the measured values so that it is highly accurate and insensitive to higher harmonics (particularly the 3rd and 5th harmonics - which are often present in zero sequence currents). Direction determination relies on the sign of active and reactive power. Since active and reactive components of the current - not the power - are relevant for pickup, current components are calculated from the power components. When determining the ground fault direction the active or reactive components of the ground current in reference to the displacement voltage as well as the direction of the active and reactive power are evaluated. For measurements of sin (for ungrounded systems) the following applies * * Ground fault (forward direction), if Q0 < 0 and Eb > setting value (RELEASE DIRECT.), Ground fault (reverse direction), if Q0 >0 and Eb > setting value (RELEASE DIRECT.). For measurements cos (for resonant grounded systems) the following applies * * Ground fault (forward direction), if P0 > 0 and EEw > setting value (RELEASE DIRECT.), Ground fault (reverse direction), if P0 < 0 and EEw > setting value (RELEASE DIRECT.). If PHI CORRECTION is unequal 0, the angle of the directional limit lines is calculated by adding up active and reactive power components. The forward and reverse zone can be reduced at its boundaries at address 3160 1 red.dir.area and address 3161 2 red.dir.area (see Figure 2-68). Logic The following figure illustrates the activation criteria of the sensitive ground fault protection. The operational mode of the ground fault detection can be set under address 3101. If set to ON, tripping is possible and a fault log is generated. If set to Alarm Only, tripping is not possible and only a ground fault log is generated. The pickup of the displacement voltage element V0 starts the ground fault recording. As the pickup of the V0 element drops out, fault recording is terminated (see logic diagrams Figure 2-71 and Figure 2-72). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 175 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) The entire function can be blocked under the following conditions: * A binary input is set, * the Fuse Failure Monitor or the voltage transformer protection breaker pick up and parameter 3130 PU CRITERIA is set to Vgnd AND INs, * the Fuse Failure Monitor or the voltage transformer protection breaker pick up and parameter 3130 PU CRITERIA is set to Vgnd OR INs, and both current elements are in directional operation mode. Switching off or blocking means that measurement is deactivated. Therefore, time delays and pickup messages are reset. All elements can be blocked individually via binary inputs. In this case pickup and, if possible, direction and grounded phase will still be reported, however, tripping does not take place since the time elements are blocked. [7sj80-aktiv-cos-sin-empf-ef-070309, 1, en_US] Figure 2-70 Activation of the sensitive ground-fault detection for cos- -/sin- measurement Generation of a pickup message, for both current elements, is dependent on the direction selection for each element and the setting of parameters 3130 PU CRITERIA. If the element is set to Non-Directional and parameter PU CRITERIA = Vgnd OR INs, a pickup message is generated as soon as the current threshold is exceeded, irrespective of the status of the V0 element. If, however, the setting of parameter PU CRITERIA is Vgnd AND INs, the V0-element must have picked up also for non-directional mode. However, if a direction is programmed, the current element must be picked up and the direction determination results must be present to generate a message. Once again, a condition for valid direction determination is that the voltage element V0 be picked up. Parameter PU CRITERIA specifies, whether a fault is generated by means of the AND-function or the ORcombination of displacement voltage and pickup of the ground current. The former may be advantageous if the pickup setting of displacement voltage element V0 was chosen to be very low. 176 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7sj80-erdfehler-ue-cos-sin-20061206, 1, en_US] Figure 2-71 Logic diagram of the V0> element for cos- -/sin- measurement SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 177 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7sj80-erdfehler-iee-cos-sin-20061206, 1, en_US] Figure 2-72 Logic diagram of the Ns elements for cos- -/sin- measurement 2.12.2 Ground Fault Detection for V0/I0- Measurement Voltage Element The voltage element relies on a pickup initiated by the displacement voltage V0 or 3 * V0. Additionally, the faulty phase is determined. The displacement voltage V0 can be directly applied to the device, or the summation voltage 3 * V0 can be calculated according to the connection type of the voltage transformer (see also Parameter 213 VT Connect. 3ph in Section 2.1.3 Power System Data 1). When setting Van, Vbn, Vcn, the calculation of the summation voltage 3 * V0 is based on the three phase-to-Ground voltages. The three voltage inputs must therefore be connected to the voltage transformers in a grounded-wye configuration. When setting Vab, Vbc, VGnd, the three phase-to-Ground voltages of both connected phase-to-phase voltages and the connected displacement voltage are calculated. If the device is only provided with phase-tophase voltages, it is not possible to calculate a displacement voltage from them. In this case, the direction cannot be determined. 178 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) If the displacement voltage is calculated, then: 3 * V0 = VA + VB + VC If the displacement voltage is directly applied to the device, then V0 is the voltage at the device terminals. It is not affected by parameter Vph / Vdelta (address 206). Pickup performed by the displacement voltage can be delayed (64-1 DELAY) for tripping. It is important to note that the total trip-command time then consists of the displacement voltage measurement time (about 50 ms) plus the pickup delay time 64-1 DELAY. After the voltage element picks up due to detection of a displacement voltage, the grounded phase is identified, if possible. To do this, the individual phase-to-ground voltages are measured. Of course, this is only possible if three phase-to-ground voltages are obtained from voltage transformers connected in a grounded wye configuration. If the voltage magnitude for any given phase is below the setting value VPh min, that phase is detected as the grounded phase as long as the remaining phase-to-ground voltages are simultaneously above the setting value VPh max. [7sj6x_erdschlussbehaftete_phase-150502-kn, 1, en_US] Figure 2-73 Determination of Ground-faulted Phase Current Elements There are two current elements. Both elements operate directionally, whereby the tripping zones can be set individually for each element (see margin heading "Tripping Area"). Both current elements are provided with a definite time characteristic. Two current/time elements are used for ground fault protection. Analog to the time overcurrent protection function, the overcurrent element is named 50Ns-1 PICKUP and 50Ns-1 DELAY and the high-set element 50Ns-2 PICKUP and 50Ns-2 DELAY. The pickup of the definite time overcurrent protection can be stabilized by the configured dropout delay time (address 3121 50Ns T DROP-OUT). Tripping Area The U0/I0- characteristic is illustrated as a sector in the U0/I0 phasor diagram (see Figure 2-74). This sector corresponds to the tripping area. If the cursor of the ground current is in this sector, the function picks up. The tripping area is defined via several parameters: Via the angle (parameter 3154 50Ns-1 Phi or 3151 50Ns-2 Phi), the center of the zone with reference to the displacement voltage V0 is set. Via the angle (parameter 3155 50Ns-1 DeltaPhi or 3152 50Ns-2 DeltaPhi), the zone is extended to both sides of the center. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 179 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) The zone is further limited downwards by minimum values of the displacement voltage and ground current. These settable threshold values must be exceeded in order to be picked up. Negative angle settings turn the tripping area in the "inductiv" direction, i.e. ground current inductive compared to ground voltage. [enel-character, 1, en_US] Figure 2-74 Tripping range of V0-0- characteristic Logic The following figure illustrates the activation criteria of the sensitive ground fault protection. The operational mode of the ground fault detection can be set under address 3101. If set to ON, tripping is possible and a fault log is generated. If set to ON with GF log, tripping is possible, a fault log and a ground fault log are generated. If set to Alarm Only, tripping is not possible and only a ground fault log is generated. The pickup of the displacement voltage V0 or pickup of the 50Ns-2 element or pickup of the 50Ns-1 or 51Ns element start the ground fault recording. As the pickup of the element drops out, fault recording is terminated (see the following logic diagrams). The entire function can be blocked under the following conditions: * A binary input is set, * the Fuse Failure Monitor or the voltage transformer protection breaker pick up. Switching off or blocking means that measurement is deactivated. Therefore, time delays and pickup messages are reset. All elements can be blocked individually via binary inputs. In this case pickup and, if possible, direction and grounded phase will still be reported, however, tripping does not take place since the time elements are blocked. To support the commissioning, a message is issued if the current and voltage threshold of an element is exceeded but the ground fault phasor is not inside of the trip range. 180 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7sj80-aktiv-empf-erdfehler-20061218, 1, en_US] Figure 2-75 Activation of the sensitive ground fault detection for V0/I0- measurement [7sj80-erdfehler-ue-u0-i0-messung-20061206, 1, en_US] Figure 2-76 Logic diagram during V0-/0 - measurement, part 1 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 181 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7sj80-erdfehler-iee-u0-i0-messung-20061206, 1, en_US] Figure 2-77 Logic diagram for V0-/I0 - measurement, part 2 2.12.3 Extended Ground Fault Protection EPTR/TNP 2.12.3.1 General Information Additionally to the sensitive and non-sensitive ground-fault detection, the 7SJ80 device offers further functions for detecting ground faults in the 20-kV power system. * Protection against ground faults in grounded feeders (EPTR) * Protection against thermal overload of transformers with grounded neutral point (TNP) The functions can only be used as an alternative. They work independently from the setting of address 130 S.Gnd.F.Dir.Ch. The following figure shows the used input variables and the activation criteria of the functions. 182 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7sj80-eptr-tss, 2, en_US] Figure 2-78 2.12.3.2 Activation of the Functions EPTR or Transformer Neutral Point (TNP) Ground-Fault Protection EPTR - B For low fault currents (< 0.95 * 1.4 n),the function works with the ground current measured on the 4th current input. For higher fault currents ( 1.4 n), ), the current 3I0 built from the phase currents is used. You can find a connection example in the Appendix (C.1 Connection Examples for Current and Voltage Transformers). If you use the function EPTR, you must set the connection type (CT Connect., address 251 ) to A, B, C, (Gnd). If you use the function EPTR, you must set the connection type (). The pickup current of the function and the course of the characteristic curve can be set. You can find information on the setting values in Section 2.12.5 Setting Notes. Logic The following figure shows the logic diagram of the function EPTR. [7sj80-lo-eptr, 2, en_US] Figure 2-79 Logic of the Ground-Fault Detection EPTR SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 183 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) 2.12.3.3 Transformer Neutral-Point Protection TNP General Information The function analyzes low fault currents. The transformer neutral-point current E2 measured on the 4th current input is used as an input variable. You can find a connection example in the Appendix (C.1 Connection Examples for Current and Voltage Transformers, Figure C-12). If you use the function TNP, you must set the connection type (CT Connect., address 251 ) to A,G2,C,G; G->B or A,G2,C,G; G2->B. The Transformer neutral-point protection works in a non-directional way with an inverse-time logarithmicinverse knee-point characteristic curve (). The pickup current of the function and the course of the characteristic curve can be set. You can find information on the setting values in Section 2.12.5 Setting Notes. Logic The following figure shows the logic diagram of the function TNP. [7sj80-lo-tss, 2, en_US] Figure 2-80 Logic of the Ground-Fault Detection for a Transformer with Grounded Neutral Point 2.12.4 Ground Fault Location Application Example Directional determination may often be used to locate ground faults. In radial systems, locating the ground fault is relatively simple. Since all feeders from a common bus (Figure 2-81) deliver a capacitive charging current, nearly the total ground fault current of the system is available at the measuring point of the faulty line in the ungrounded system. In the resonant grounded system it is the residual wattmetric current of the Petersen coil that flows via the measuring point. Therefore, on the faulty cables a clear "forward" decision is made whereas in other feeders either "reverse" direction is sent back or no measurement is carried out in case ground current is too low. Definitely the faulty line can be determined clearly. 184 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [erdschlussortung-im-strahlennetz-260602-kn, 1, en_US] Figure 2-81 Location of ground faults in a radial network In meshed or looped systems, the measuring points of the faulty line also receive the maximum ground fault current (residual current). Only in this line, "forward" direction is signaled at both ends (Figure 2-82). The rest of the direction indications in the system may also be useful for ground fault detection. However, some indications may not be given when the ground current is too low. [ortung-des-erdschlusses-260602-kn, 1, en_US] Figure 2-82 Determination of the ground fault location basing on directional indicators in the meshed system 2.12.5 Setting Notes General Settings During configuration of the protection functions (Section 2.1.1 Functional Scope, under address 131 Sens. Gnd Fault it was determined with which parameters the ground fault detection is functioning. If address Sens. Gnd Fault = Definite Time is selected, then the settings for the definite-time elements are available here. If Sens. Gnd Fault = User Defined PU is selected, a user-specified characteristic can be used for the overcurrent protection elements 50Ns-1 or 51Ns. The superimposed high-current element 50Ns-1 is available in all these cases. If this function is not required, then Disabled is set. The user characteristics are only available, if the standard measurement procedure cos / sin has been set at address 130. The characteristic for determining the direction is set at address 130 S.Gnd.F.Dir.Ch. It is optional to select either the standard measurement method cos / sin or the V0/I0 mea. with one sector characteristic. At address 3101 Sens. Gnd Fault, the function ON or OFF can be set to either ON with GF log or Alarm Only. If settings ON and ON with GF log are applied, tripping is also possible, otherwise a fault log SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 185 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) is created. A ground fault log is created for ON with GF log and Alarm Only. Setting ON with GF log is only available if characteristic V0/I0 mea. has been selected at address 130 S.Gnd.F.Dir.Ch. The parameters 3111 T-DELAY Pickup and 3130 PU CRITERIA are only visible if the standard measurement method cos / sin has been selected when setting the direction characteristic. The ground fault is detected and reported when the displacement voltage was sustained a certain time T-DELAY Pickup). Address 3130 PU CRITERIA specifies whether ground fault detection is enabled only for pickups of VN and NS (Vgnd AND INs) or as soon as one of the two has picked up (Vgnd OR INs). The pickup can be stabilized for ground fault protection with definite time curve by a settable dropout time delay (address 3121 50Ns T DROP-OUT). This facility is used in power systems with intermittent faults. Used together with electro-mechanical relays, it allows different dropout responses to be adjusted and time grading of digital and electro-magnetic relays to be implemented. The setting depends on the dropout time delay of the electro-magnetic relay. If no coordination is required, the preset value (zero = no dropout time delay) remains. i NOTE Please not that under address 213 VT Connect. 3ph the connection type of the voltage transformer Van, Vbn, Vcn or Vab, Vbc, VGnd must be set. Additionally, adjustment factor Vph/Vdelta for the displacement voltage must be set correctly under address 206. Depending on the type of connection of the current transformer, the primary and secondary rated current in the ground path must be set under address 217 and 218, and, if required, the primary and secondary rated current of the second ground current transformer must be set under address 238 and 239. Overcurrent Elements Definite Time/Inverse Time A two-element current/time characteristic can be set at addresses 3113 to 3120. These elements operate with the amounts of the ground current. They are therefore only useful where the magnitude of the ground current and maybe its direction can be used to specify the ground fault. This may be the case for grounded systems (solid or low-resistant) or on electrical machines connected to the busbar of an ungrounded power system, when in case of a network ground fault the machine supplies only a negligible ground fault current across the measurement location, which must be situated between the machine terminals and the network, whereas in case of a machine ground fault the total ground fault current produced by the total network is available. User-defined characteristic (Inverse Time) User-defined characteristics are only used for the standard measurement method cos / sin (address 130 S.Gnd.F.Dir.Ch). During configuration of a user-defined characteristic, it should be noted that there is a safety factor of approx. 1.1 between pickup and setting value - as is standard for inverse curves. This means that pickup will only be initiated when current of 1.1 times the setting value flows. The value pairs (current and time) are entered as multiples of the values at addresses 3119 51Ns PICKUP and 3120 51NsTIME DIAL. Therefore, it is recommended that these addresses are initially set to 1.00 for simplicity reasons. Once the curve has been entered, the settings at addresses 3119 and/or 3120 can be modified if necessary. The default setting of current values is . They are, therefore, not enabled -- and no pickup or tripping of these protective functions will occur. Up to 20 value pairs (current and time) may be entered at address 3131 M.of PU TD. The device then approximates the characteristic, using linear interpolation. 186 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) The following must be observed: * The value pairs should be entered in increasing sequence. If desired, fewer than 20 pairs can be entered. In most cases, about 10 pairs is sufficient to define the characteristic accurately. A value pair which will not be used has to be made invalid by entering "" for the threshold! The user must ensure that the value pairs produce a clear and constant characteristic The current values entered should be those from Table 2-11, along with the matching times. Deviating values /p are rounded. This, however, will not be indicated. Current below the current value of the smallest curve point will not lead to an extension of the tripping time. The pickup curve (see Figure 2-83) continues, from the smallest current point parallel to the current axis. Current flows greater than the highest current value entered will not result in a reduced tripping time. The pickup curve (see Figure 2-83) continues, from the highest current point parallel to the current axis. Table 2-11 Preferential Values of Standardized Currents for User-specific Tripping Curves MofPU = 1 bis 1.94 MofPU = 2 bis 4.75 MofPU = 5 bis 7.75 MofPU = 8 bis 20 1.00 1.50 2.00 3.50 5.00 6.50 8.00 15.00 1.06 1.56 2.25 3.75 5.25 6.75 9.00 16.00 1.13 1.63 2.50 4.00 5.50 7.00 10.00 17.00 1.19 1.69 2.75 4.25 5.75 7.25 11.00 18.00 1.25 1.75 3.00 4.50 6.00 7.50 12.00 19.00 1.31 1.81 3.25 4.75 6.25 7.75 13.00 20.00 1.38 1.88 1.44 1.94 14.00 [verwendung-einer-anwenderspezifizierbaren-kennlinie-260602-kn, 1, en_US] Figure 2-83 Use of a user-defined characteristic Determination of Ground-Faulted Phase The ground-faulted phase may be identified in an ungrounded or resonant-grounded system, if the device is supplied by three voltage transformers connected in a grounded-wye configuration. The phase in which the voltage lies below setting VPH MIN at address 3106 is identified as the faulty phase as long as the other two phase voltages simultaneously exceed the setting VPH MAX at address 3107. The setting VPH MIN must be set less than the minimum expected operational phase-to-ground voltage. A typical setting for this address would be 40 V. Setting VPH MAX must be greater than the maximum expected operational phase-to-ground voltage, but less than the minimum expected operational phase-to-phase voltage. For VNom = 100 V, approximately 75 V is a typical setting. These settings have no significance in a grounded system. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 187 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) Displacement Voltage Element Vo The displacement voltage 64-1 VGND (address 3109) or 64-1 VGND (address 3110) is used to pick up ground fault detection. At the same time, pickup of the voltage element is a condition for initiation of direction determination (when setting the direction characteristic to cos / sin ). If the direction characteristic is set toV0/I0 mea., the displacement voltage element is not relying on the current elements at all. Depending on the configuration at address 213 VT Connect. 3ph, only the applicable limit value at address 3109 64-1 VGND or 3110 64-1 VGND is accessible. If two phase-to-phase voltages and the displacement voltage V0 are supplied to the device, the measured displacement voltage is used directly for ground fault recognition. The threshold for V0 is set at address 3109 64-1 VGND, where a more sensitive setting can be made than with a calculated displacement voltage. Please note that when the V0 voltage is connected, the factor (normally = 1.73; see also Section 2.1.3.2 Setting Notes) specified with parameter 206 Vph/Vdelta is used. For display of parameter 3109 64-1 VGND in primary values, the following conversion formula applies: [formel-uenprim-uensek-120503-kn, 1, en_US] If three phase-to-ground voltages are connected to the device, the displacement voltage 3 * V0 is calculated from the momentary values of phase-to-ground voltages, and address 3110 is where the threshold is to be set. For the display of parameter 3110 in primary values, the following applies: [formel-3u0prim-3u0sek-120503-kn, 1, en_US] If the secondary values of (for example) parameters 3109 and 3110 are set equally, then their primary values differ by adjustment value Vph/Vdelta. Example: Parameter 202 Parameter 203 Parameter 206 Vnom PRIMARY Vnom SECONDARY Vph/Vdelta = 12 kV = 100 V = 1.73 Parameter 213 VT Connect. 3ph = Vab, Vbc, VGnd Parameter 3109 64-1 VGND = 40 V The following applies when switching to primary values: [beispiel-uen-83kv-130503-kn, 1, en_US] With the following configuration Parameter 213 VT Connect. 3ph = Van, Vbn, Vcn Parameter 3110 64-1 VGND = 40 V the following applies when switching to primary values: [beispiel-3u0-48kv-130503-kn, 1, en_US] With regard to a ground fault in a ungrounded or resonant-grounded system, nearly the entire displacement voltage appears at the device terminals, therefore the pickup setting is not critical, and typically lies between 188 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) 30 V and 60 V (for 64-1 VGND with a standard V0-connection) or 50 V and 100 V (for 64-1 VGND). Large fault resistances may require higher sensitivity (i.e. a lower pickup setting). With regard to a grounded system, a more sensitive (lower) pickup value may be set, but it must be above the maximum anticipated displacement voltage during normal (unbalanced) system operation. Pickup of just the voltage element may initiate time delayed tripping assumed that ground fault detection is configured to perform tripping (address 3101 Sens. Gnd Fault = ON or ON with GF log) and moreover address 3130 PU CRITERIA is configured Vgnd OR INs. The tripping delay is then set at address 3112 64-1 DELAY. It is important to note that the total tripping time consists of the displacement voltage measurement time (about 50 ms) plus the pickup time delay (address 3111 T-DELAY Pickup) plus the tripping time delay (address 3112 64-1 DELAY). Direction Determination for cos-/ sin- Addresses 3115 to 3126 are important for direction determination. Address 3115 67Ns-2 DIRECT determines the direction of the definite high-set current element 50Ns-2 and can be set to either Forward or Reverse or Non-Directional, i.e. to both directions. The direction of the current element 50Ns-1 or or 51Ns can be set to Forward or Reverse or Non-Directional, i.e. to both directions, at address 3122 67Ns-1 DIRECT.. Current value RELEASE DIRECT. (address 3123) is the release threshold for directional determination. It is based on the current components which are perpendicular to the directional limit lines. The position of the directional limit lines themselves are based on the settings entered at addresses 3124 and 3125. The following applies to the determination of direction during ground faults: The pickup current 30 DIR. (=RELEASE DIRECT. address 3123) must be set as high as possible to avoid false pickup of the device provoked by asymmetrical currents in the system and by current transformers (especially in the Holmgreenconnection). If direction determination is used in conjunction with one of the current elements discussed above (50Ns-1 PICKUP, addresses 3117 ff, or 51Ns PICKUP, addresses 3119 ff), it is sensible to select a value for address RELEASE DIRECT. that is lower than or equal to the above pickup value. A corresponding message (reverse, forward, or undefined) is issued upon direction determination. To avoid chatter for this message resulting from extremely varying ground connection currents, a dropout delay RESET DELAY, entered at address 3126, is initiated when directional determination drops out, and the message is held for this period of time. When address 3124 PHI CORRECTION is set to 0.0, in address 3125 the following signifies * MEAS. METHOD = COS the resistive component of the ground current with respect to the displacement voltage is most relevant for the current value RELEASE DIRECT. (30 DIR.), MEAS. METHOD = SIN the reactive (capacitive) component of the ground current with respect to the displacement voltage is most relevant for the current value RELEASE DIRECT. (30 DIR.) (Figure 2-84). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 189 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7sj6-richtkennl-bei-sin-mess-20110113, 1, en_US] Figure 2-84 * Directional characteristic for sin--measurement In address 3124 PHI CORRECTION the directional line, in this respect, may be rotated within the range 45. Figure 2-69 "Directional characteristic for cos--measurement" in the functional description of the sensitive ground fault detection gives an example regarding this topic. The forward and reverse zone can be reduced at its boundaries at address 3160 1 red.dir.area and address 3161 2 red.dir.area (see Figure 2-84). Siemens recommends using the default setting of 2 (this corresponds to the behavior of versions without this setting option). In a grounded system in feeders with very high capacitive current, it can be reasonable to set a slightly larger angle 1 to prevent erroneous pickup due to transformer and algorithm tolerances. Direction Determination for V0/I0 Measurement With the minimum voltage 50Ns-2 Vmin, address 3150 and the level of the pickup current 50Ns-2 PICKUP, address 3113, the lower limit of the circuit segment of element 50Ns-2 is set. The thresholds of the tripping range in respect of the displacement voltage is set by means of the matching phase angle 50Ns-2 190 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) Phi, address 3151 and angle 50Ns-2 DeltaPhi, address 3152. The trip delay time is set under address 3114 50Ns-2 DELAY. The actual settings are based on the respective application. The minimum voltage 50Ns-1 Vmin of the high-current element 50Ns-1 is set under address 3153, the pickup current 50Ns-1 PICKUP under 3117. The respective phase angle 50Ns-1 Phi is set under address 3154, the angle 50Ns-1 DeltaPhi is entered under address 3155. The angle should be set to 180 so that the element functions non-directionally. The trip delay time is set under address 3118 50Ns-1 DELAY. Positive angle settings (address 3151 and 3154) turn the tripping area in the capacitive" direction, i.e. ground current capacitive compared to ground voltage. Negative angle settings turn the tripping area in the "inductiv" direction, i.e. ground current inductive compared to ground voltage. Angular Error Compensation ( Transformer) The high reactive component in a resonant grounded system and the inevitable air gap of the toroidal current transformer often require the angle error of the toroidal current transformer to be compensated. In addresses 3102 to 3105 the maximum angle error CT Err. F1 and the associated secondary current CT Err. I1 as well as another operating point CT Err. F2/CT Err. I2 are set for the actually connected burden. The device thus approximates the transformation characteristic of the transformer with considerable accuracy. In ungrounded or grounded systems angle compensation is not required. Ungrounded System In an ungrounded system with a ground fault on a cable, capacitive ground currents of the galvanically connected system flow via the measuring point, except for the ground current generated in the grounded cable, since the current last-mentioned will flow directly to the fault location (i.e. not via the measuring point). A setting equal to about half the ground current is to be selected. The measurement method should be SIN , since capacitive ground current is most relevant here. Resonant-Grounded System In resonant-grounded systems, directional determination on the occurrence of a ground fault is more difficult since the low residual wattmetric current for measurement is usually dwarfed by a reactive current (be it capacitive or inductive) which is much higher. Therefore, depending on the system configuration and the position of the arc-compensating coil, the total ground current supplied to the device may vary considerably in its values with regard to magnitude and phase angle. The relay, however, must evaluate only the active component of the ground fault current, that is, Ns cos . This demands extremely high accuracy, particularly with regard to phase angle measurement of all instrument transformers. Furthermore, the device must not be set to operate too sensitive. When applying this function in resonant-grounded systems, a reliable direction determination can only be achieved when toroidal current transformers are connected. Here the following rule of thumb applies: Set pickup values to about half of the expected measured current, thereby considering only the residual wattmetric current. Residual wattmetric current predominantly derives from losses of the Petersen coil. Here, the COS measurement method is used since the resistive residual wattmetric current is most relevant. Grounded System In grounded systems, a value is set below the minimum anticipated ground fault current. It is important to note that 3I0 DIR (current value RELEASE DIRECT.) only detects the current components that are perpendicular to the directional limit lines defined at addresses 3124 and 3125. COS is the method of measurement used, and the correction angle is set to -45, since the ground fault current is typically resistive-inductive (right section of Figure 2-81 "Directional curve for cos--measurement" in the functional description of the sensitive ground fault detection). Electrical Machines One may set the value COS for the measurement method and use a correction angle of +45 for electrical motors supplied from a busbar in an ungrounded system, since the ground current is often composed of an overlap of the capacitive ground current from the system and the resistive current of the load resistance (left SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 191 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) part of Figure "Directional characteristic for cos--measurement" in the functional description of the sensitive ground fault detection). Information on the Configuration of the Current Threshold With devices with sensitive ground fault input, generally settings may be entered in primary values with consideration given to the ratio of the applicable current transformer. However, problems related to the resolution of the pickup currents can occur when very small settings and small nominal primary currents are involved. The user is therefore encouraged to enter settings for the sensitive ground fault detection in secondary values. EPTR, TNP - General Information The function EPTR is switched on or off at address 3501 EPTR. The function TNP is switched on or off at address 3502 Trans. Neutral. You can switch between the functions using the connection-type setting CT Connect., address 251). If A, B, C, (Gnd) is set, EPTR works. If A,G2,C,G; G->B or A,G2,C,G; G2->B is set, TNP works. EPTR, TNP - Logarithmic-Inverse Knee-Point Characteristic Curve (AMZ) The logarithmic-inverse characteristic curve for EPTR is set at the following addresses: 3503 Pickup current 3505 EPTR I Tmax, pickup current with maximum delay 3507 EPTR I Tmin, pickup current with minimum delay 3509 EPTR I Tknee, current at the knee-point 3511 T knee, tripping time for the knee-point, the transition of the 2 characteristic-curve sections with different slope. 3512 T min, minimum delay when the current threshold EPTR I Tmin picks up. 3513 T max, picks up EPTR I Tmax picks up T min and T max determine the range of the tripping time. The logarithmic-inverse characteristic curve for TNP is set at the following addresses: 3504 Pickup current 3506 TNP I Tmax, pickup current with maximum delay 3508 TNP I Tmin, pickup current with minimum delay 3510 TNP I Tknee, Strom an Kniepunkt 3511 T knee, tripping time for the knee-point, the transition of the 2 characteristic-curve sections with different slope. 3512 T min, minimum delay when the current threshold TNP I Tmin picks up. 3513 T max, maximum delay when the current threshold TNP I Tmax picks up. T min and T max determine the range of the tripping time. With address 3514 T Function you set the time delay for the complete function. 192 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) [7SJ80_knickpkt-kennlinie, 1, en_US] Figure 2-85 Tripping Time Characteristic Curves of the Inverse-Time Ground-Fault Protection with Logarithmic-Inverse Knee-Point Characteristic Curve, Example EPTR 2.12.6 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 3101 Sens. Gnd Fault 3102 CT Err. I1 3102 CT Err. I1 3103 CT Err. F1 3104 CT Err. I2 3104 CT Err. I2 C Setting Options Default Setting Comments OFF ON ON with GF log Alarm Only OFF (Sensitive) Ground Fault 1A 0.001 .. 1.600 A 0.050 A 5A 0.005 .. 8.000 A 0.250 A Current I1 for CT Angle Error 1A 0.05 .. 35.00 A 1.00 A 5A 0.25 .. 175.00 A 5.00 A Current I1 for CT Angle Error 0.0 .. 5.0 0.0 CT Angle Error at I1 1A 0.001 .. 1.600 A 1.000 A 5A 0.005 .. 8.000 A 5.000 A Current I2 for CT Angle Error 1A 0.05 .. 35.00 A 10.00 A 5A 0.25 .. 175.00 A 50.00 A Current I2 for CT Angle Error 3105 CT Err. F2 0.0 .. 5.0 0.0 CT Angle Error at I2 3106 VPH MIN 10 .. 100 V 40 V L-Gnd Voltage of Faulted Phase Vph Min 3107 VPH MAX 10 .. 100 V 75 V L-Gnd Voltage of Unfaulted Phase Vph Max 3109 64-1 VGND 1.8 .. 200.0 V; 40.0 V 64-1 Ground Displacement Voltage SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 193 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) Addr. Parameter 3110 Setting Options Default Setting Comments 64-1 VGND 10.0 .. 225.0 V; 70.0 V 64-1 Ground Displacement Voltage 3111 T-DELAY Pickup 0.04 .. 320.00 sec; 1.00 sec Time-DELAY Pickup 3112 64-1 DELAY 0.10 .. 40000.00 sec; 10.00 sec 64-1 Time Delay 3113 50Ns-2 PICKUP 1A 0.001 .. 1.600 A 0.300 A 50Ns-2 Pickup 5A 0.005 .. 8.000 A 1.500 A 1A 0.05 .. 35.00 A 10.00 A 5A 0.25 .. 175.00 A 50.00 A 3113 50Ns-2 PICKUP C 50Ns-2 Pickup 3114 50Ns-2 DELAY 0.00 .. 320.00 sec; 1.00 sec 50Ns-2 Time Delay 3115 67Ns-2 DIRECT Forward Reverse Non-Directional Forward 67Ns-2 Direction 3117 50Ns-1 PICKUP 1A 0.001 .. 1.600 A 0.100 A 50Ns-1 Pickup 5A 0.005 .. 8.000 A 0.500 A 3117 50Ns-1 PICKUP 1A 0.05 .. 35.00 A 2.00 A 5A 0.25 .. 175.00 A 10.00 A 3118 50Ns-1 DELAY 0.00 .. 320.00 sec; 2.00 sec 50Ns-1 Time delay 3119 51Ns PICKUP 1A 0.001 .. 1.400 A 0.100 A 51Ns Pickup 5A 0.005 .. 7.000 A 0.500 A 1A 0.05 .. 4.00 A 1.00 A 5A 50Ns-1 Pickup 3119 51Ns PICKUP 0.25 .. 20.00 A 5.00 A 3120 51NsTIME DIAL 0.10 .. 4.00 sec; 1.00 sec 51Ns Time Dial 3121A 50Ns T DROP-OUT 0.00 .. 60.00 sec 0.00 sec 50Ns Drop-Out Time Delay 3122 67Ns-1 DIRECT. Forward Reverse Non-Directional Forward 67Ns-1 Direction 3123 RELEASE DIRECT. 1A 0.001 .. 1.200 A 0.010 A Release directional element 5A 0.005 .. 6.000 A 0.050 A 3123 RELEASE DIRECT. 1A 0.05 .. 30.00 A 0.50 A 5A 0.25 .. 150.00 A 2.50 A 3124 PHI CORRECTION -45.0 .. 45.0 0.0 Correction Angle for Dir. Determination 3125 MEAS. METHOD COS SIN COS Measurement method for Direction 3126 RESET DELAY 0 .. 60 sec 1 sec Reset Delay 3130 PU CRITERIA Vgnd OR INs Vgnd AND INs Vgnd OR INs Sensitive Ground Fault PICKUP criteria 3131 M.of PU TD 1.00 .. 20.00 MofPU; 0.01 .. 999.00 TD 3150 50Ns-2 Vmin 10.0 .. 90.0 V 10.0 V 50Ns-2 minimum voltage 3150 50Ns-2 Vmin 0.4 .. 50.0 V 2.0 V 50Ns-2 minimum voltage 3151 50Ns-2 Phi -180.0 .. 180.0 -90.0 50Ns-2 angle phi 3152 50Ns-2 DeltaPhi 0.0 .. 180.0 30.0 50Ns-2 angle delta phi 3153 50Ns-1 Vmin 10.0 .. 90.0 V 15.0 V 50Ns-1 minimum voltage 3153 50Ns-1 Vmin 0.4 .. 50.0 V 6.0 V 50Ns-1 minimum voltage 3154 50Ns-1 Phi -180.0 .. 180.0 -160.0 50Ns-1 angle phi 3155 50Ns-1 DeltaPhi 0.0 .. 180.0 100.0 50Ns-1 angle delta phi 194 51Ns Pickup Release directional element Multiples of PU Time-Dial SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) Addr. Parameter 3160 3161 C Setting Options Default Setting Comments 1 red.dir.area 1 .. 15 2 Alpha1 (reduction directional area) 2 red.dir.area 1 .. 15 2 Alpha2 (reduction directional area) 2.12.7 Settings EPTR, TNP Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 3501 EPTR OFF ON OFF EPTR 3502 Trans. Neutral OFF ON OFF Transformer Neutral protection(TNP) 3503 Pickup current 1A 0.001 .. 1.400 A 0.008 A Pickup current 5A 0.005 .. 7.000 A 0.040 A 0.05 .. 4.00 A 0.12 A Pickup current 0.001 .. 1.400 A 0.008 A Current at Maximum Time Delay 3504 Pickup current 3505 EPTR I Tmax 3506 TNP I Tmax 3507 EPTR I Tmin 3508 TNP I Tmin 3509 EPTR I Tknee C 1A 5A 0.005 .. 7.000 A 0.040 A 0.05 .. 4.00 A 0.12 A Current at Maximum Time Delay 1A 0.003 .. 4.000 A 3.333 A 5A 0.015 .. 20.000 A 16.665 A Current at Minimum Time Delay 0.05 .. 20.00 A 1.00 A Current at Minimum Time Delay 1A 0.003 .. 1.400 A 0.100 A Current at Knee Point 5A 0.015 .. 7.000 A 0.500 A 3510 TNP I Tknee 0.05 .. 17.00 A 0.20 A Current at Knee Point 3511 T knee 0.20 .. 100.00 sec 26.70 sec Time Delay at Knee Point 3512 T min 0.10 .. 30.00 sec 0.80 sec Minimum Time Delay 3513 T max 0.50 .. 300.00 sec 139.90 sec Maximum Time Delay 3514 T Function -0.50 .. 30.00 sec 0.00 sec Delay time T of the whole function 2.12.8 Information List No. Information Type of Information Comments 1201 >BLOCK 64 SP >BLOCK 64 1202 >BLOCK 50Ns-2 SP >BLOCK 50Ns-2 1203 >BLOCK 50Ns-1 SP >BLOCK 50Ns-1 1204 >BLOCK 51Ns SP >BLOCK 51Ns 1207 >BLK 50Ns/67Ns SP >BLOCK 50Ns/67Ns 1211 50Ns/67Ns OFF OUT 50Ns/67Ns is OFF 1212 50Ns/67Ns ACT OUT 50Ns/67Ns is ACTIVE 1215 64 Pickup OUT 64 displacement voltage pick up SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 195 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) No. Information Type of Information Comments 1217 64 TRIP OUT 64 displacement voltage element TRIP 1221 50Ns-2 Pickup OUT 50Ns-2 Pickup 1223 50Ns-2 TRIP OUT 50Ns-2 TRIP 1224 50Ns-1 Pickup OUT 50Ns-1 Pickup 1226 50Ns-1 TRIP OUT 50Ns-1 TRIP 1227 51Ns Pickup OUT 51Ns picked up 1229 51Ns TRIP OUT 51Ns TRIP 1230 Sens. Gnd block OUT Sensitive ground fault detection BLOCKED 1264 IEEa = VI Corr. Resistive Earth current 1265 IEEr = VI Corr. Reactive Earth current 1266 IEE = VI Earth current, absolute Value 1267 VGND, 3Vo VI Displacement Voltage VGND, 3Vo 1271 Sens.Gnd Pickup OUT Sensitive Ground fault pick up 1272 Sens. Gnd Ph A OUT Sensitive Ground fault picked up in Ph A 1273 Sens. Gnd Ph B OUT Sensitive Ground fault picked up in Ph B 1274 Sens. Gnd Ph C OUT Sensitive Ground fault picked up in Ph C 1276 SensGnd Forward OUT Sensitive Gnd fault in forward direction 1277 SensGnd Reverse OUT Sensitive Gnd fault in reverse direction 1278 SensGnd undef. OUT Sensitive Gnd fault direction undefined 16029 51Ns BLK PaErr OUT Sens.gnd.flt. 51Ns BLOCKED Setting Error 16030 (3Vo,INs) = VI Angle between 3Vo and INsens. 2.12.9 Information List EPTR, TNP No. Information Type of Information Comments 18901 >BLK E Flt(ext) SP >BLOCK Earth fault (extend) 18902 >BLOCK EPTR SP >BLOCK EPTR 18903 >BLOCK TNP SP >BLOCK Transformer Neutral (TNP) 18904 E Flt(ext) OFF OUT Earth fault (extend) is OFF 18905 E Flt(ext) ACT OUT Earth fault (extend) is ACTIVE 18906 EPTR OFF OUT EPTR is OFF 18907 EPTR ACT OUT EPTR is ACTIVE 18908 TNP OFF OUT Transformer Neutral(TNP) is OFF 18909 TNP ACT OUT Transformer Neutral(TNP) is ACTIVE 18910 EPTR picked up OUT EPTR picked up 18911 EPTR TRIP OUT EPTR TRIP 18912 TNP picked up OUT Transformer Neutral (TNP) picked up 18913 TNP TRIP OUT Transformer Neutral (TNP) TRIP 18914 E Flt(ext) PU OUT Earth fault (extend) picked up 18915 E Flt(ext) Trip OUT Earth fault (extend) TRIP 18916 E Flt(ext) BLK OUT Earth fault (extend) is BLOCKED 18917 EPTR BLOCKED OUT EPTR is BLOCKED 18918 TNP BLOCKED OUT Transformer Neutral(TNP) is BLOCKED 196 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s) No. Information Type of Information Comments 18919 EF BLK PaErr OUT Earth fault (extend) BLOCK Setting Error SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 197 Functions 2.13 Intermittent Ground Fault Protection 2.13 Intermittent Ground Fault Protection A typical characteristic of intermittent ground faults is that they often disappear automatically to strike again after some time. They can last between a few milliseconds and several seconds. This is why such faults are not detected at all or not selectively by the ordinary time overcurrent protection. If pulse durations are extremely short, not all protection devices in a short-circuit path may pick up; selective tripping is thus not ensured. Due to the time delay of the overcurrent protection function such faults are too short to initiate shutdown of the faulted cable. Only when they have become permanent such ground faults can be removed selectively by the short-circuit protection. But such intermittent ground faults already bear the risk of causing thermal damage to equipment. This is why devices 7SJ80 feature a protective function that is able to detect such intermittent ground faults and accumulates their duration. If the sum reaches a configurable value within a certain time, the limit of the thermal load capacity has been reached. If the ground faults are distributed over a long period of time or if the ground fault goes off and does not re-ignite after some time, the equipment under load is expected to cool down. Tripping is not necessary in this case. Applications * Protection from intermittent ground faults which occur, e.g. in cables due to poor insulation or water ingress in cable joints. 2.13.1 Functional Description Acquisition of Measured Quantities The intermittent ground fault can either be detected via the ordinary ground current input (N), the sensitive ground current input (N), or it is calculated from the sum of the three phase currents (30). Unlike the overcurrent protection which uses the fundamental wave, the intermittent ground fault sprotection creates the r.m.s. value of this current and compares it to a settable threshold Iie>. This method accounts for higher order harmonics contents (up to 400 Hz) and for the direct component since both factors contribute to the thermal load. Pickup/Tripping If the pickup value Iie> is exceeded, the pickup indication IIE Fault det (see Figure 2-86) is generated. The pickups are also counted; when the counter content reaches the value of parameter Nos.det., the indication Intermitt.EF is output. A stabilized pickup is obtained by prolonging the pickup indication IIE Fault det by a settable time T-det.ext.. This stabilization is especially important for the coordination with existing static or electromechanical overcurrent relays. The duration of the stabilized pickups IIE stab.Flt is summated with an integrator T-sum det.. If the accumulated pickup time reaches a settable threshold value, a corresponding message is generated (IEF Tsum exp.). Tripping takes place, however, only while a ground fault is present (message IEF Trip). The trip command is maintained during the entire minimum tripping time specified for the device, even if the ground fault is of short duration. After completion of the tripping command all memories are reset and the protection resumes normal condition. The (much longer) resetting time T-reset (message IEF Tres run.) is launched simultaneously with Tsum det. when a ground fault occurs. Unlike T-sum det., each new ground fault resets this time to its initial value and it expires anew. If T-reset expires and no new ground fault is recorded during that time, all memories are reset and the protection resumes normal position. T-reset thus determines the time during which the next ground fault must occur to be processed yet as intermittent ground fault in connection with the previous fault. A ground fault that occurs later will be considered a new fault event. The message IIE Fault det will be entered in the fault log and reported to the system interface only until the message Intermitt.EF is issued. This prevents a burst of messages. If the message is allocated to an LED or a relay, this limitation does not apply. This is accomplished by doubling the message (message numbers 6924, 6926). 198 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.13 Intermittent Ground Fault Protection Interaction with the Automatic Reclosure Function Automatic reclosure is not an effective measure against intermittent ground faults as the function only trips after repeated detection of a fault or after expiration of the summation monitoring time T-sum det. and besides this, its basic design is to prevent thermal overload. For these reasons, the intermittent ground fault protection is not implemented as starting feature of the automatic reclosing function. Interaction with Breaker Failure Protection A pickup that is present when the time delay TRIP-Timer has expired is interpreted by the breaker failure protection as a criterion for a tripping failure. Since permanent pickup is not ensured after a tripping command by the intermittent ground fault protection, cooperation with the breaker failure protection is not sensible. Therefore, this function is not activated by the intermittent ground fault protection. Logic Diagram The following figure shows the logic diagram for the intermittent ground fault protection function. [7sj6x_intermit_erdfehler-150502-kn, 1, en_US] Figure 2-86 Logic diagram of the intermittent ground fault protection - principle Fault Logging A fault event and thus fault logging is initiated when the non-stabilized E element picks up for the first time. A message IIE Fault det is produced. The message IIE Fault det is issued and entered in the fault log (and reported to the system interface) so often until the number of pickups IIE Fault det has reached the value set for parameter Nos.det.. When this happens, the message Intermitt.EF is issued and IIE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 199 Functions 2.13 Intermittent Ground Fault Protection Fault det is blocked for the fault log and the system interface. This method accounts for the fact that the E element may also pick up for a normal short-circuit. In this case the pickup does not launch the alarm Intermitt.EF. Intermittent ground faults may cause other overcurrent elements to pick up (e.g. 50-1, 50N-1, 50Ns-1), which may result in a burst of messages. In order to avoid an overflow of the fault log, its messages are no longer entered in the fault log after detection of intermittent ground faults (indication Intermitt.EF), unless they cause a trip command. If an intermittent ground fault has been detected, the following pickup messages of the time overcurrent protection will still be reported without restraint (see Intermitt.EF): Table 2-12 Unrestricted Messages FNo. Message Description 1800 50-2 picked up 67-2 picked up 50-1 InRushPU 50N-1 InRushPU 51 InRushPU 51N InRushPU 67-1 InRushPU 67N-1 InRushPU 67-TOC InRushPU 67N-TOCInRushPU Ia InRush PU Ib InRush PU Ic InRush PU Gnd InRush PU 50-2 picked up 2642 7551 7552 7553 7554 7559 7560 7561 7562 7565 7566 7567 7564 67-2 picked up 50-1 InRush picked up 50N-1 InRush picked up 51 InRush picked up 51N InRush picked up 67-1 InRush picked up 67N-1 InRush picked up 67-TOC InRush picked up 67N-TOC InRush picked up Phase A InRush picked up Phase B InRush picked up Phase C InRush picked up ground InRush picked up Table 2-13 shows all messages subject to a restraint mechanism avoiding a message burst during an intermittent ground fault: Table 2-13 FNo. Message Description 1761 50(N)/51(N) PU 50/51 Ph A PU 50/51 Ph B PU 50/51 Ph C PU 50-3 picked up 50-1 picked up 51 picked up 50N/51NPickedup 50N-3 picked up 50N-2 picked up 50N-1 picked up 51N picked up 67/67N pickedup 67-3 picked up 67-1 picked up 67-TOC pickedup 67 A picked up 67 B picked up 67 C picked up 50(N)/51(N) picked up 1762 1763 1764 1767 1810 1820 1765 1768 1831 1834 1837 2691 2697 2660 2670 2692 2693 2694 200 Buffered Messages 50/51 Phase A picked up 50/51 Phase B picked up 50/51 Phase C picked up 50-3 element picked up 50-1 element picked up 51 element picked up 50N element picked up 50N-3 element picked up 50N-2 element picked up 50N-1 element picked up 51N element picked up 67/67N picked up 67-3 element picked up 67-1 element picked up 67-TOC element picked up 67/67-TOC Phase A picked up 67/67-TOC Phase B picked up 67/67-TOC Phase C picked up SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.13 Intermittent Ground Fault Protection FNo. Message Description 2698 67N-3 picked up 67N-2 picked up 67N-1 picked up 67N-TOCPickedup 67N picked up 46-2 picked up 46-1 picked up 46-TOC pickedup 64 Pickup 50Ns-2 Pickup 50Ns-1 Pickup 51Ns Pickup 48 pickup 67N-3 element picked up 2646 2681 2684 2695 5159 5165 5166 1215 1221 1224 1227 6823 67N-2 element picked up 67N-1 element picked up 67N-TOC element picked up 67N/67N-TOC element picked up 46-2 picked up 46-1 picked up 46-TOC picked up 64 displacement voltage pick up 50Ns-2 elementpicked up 50Ns-1 elementpicked up 51Ns elementpicked up 48 Startup supervision Pickup Before they are entered in the fault log (event buffer) and transmitted to the system interface or CFC, the indications of Table 2-13 are buffered (starting with the incoming indication Intermitt.EF). The buffering does not apply to signaling to relays and LEDs as it is required by time-graded protection systems for reverse interlocking. The buffer can store a maximum of two status changes (the most recent ones) for each indication. Buffered messages are signaled to the fault log, CFC and to the system interface with the original time flag only when a TRIP command is initiated by a protection function other than the intermittent ground fault protection. This ascertains that a pickup, although delayed, is always signaled in association with each TRIP command. All pickup messages which usually do not occur during an intermittent ground fault are not affected by this mechanism. Among others this includes the pickup and TRIP commands of the following protective functions: * Breaker failure protection, * * * * Overload protection, Frequency protection Voltage protection QU protection. The pickup signals of these functions will still be logged immediately. A TRIP command of one of these protective functions will cause the buffered messages to be cleared since no connection exists between tripping function and buffered message. A fault event is cleared when the time T-reset has expired or the TRIP command IEF Trip has been terminated. Terminating a fault event for the intermittent ground fault protection thus is a special case. It is the time Treset that keeps the fault event opened and not the pickup. 2.13.2 Setting Notes General The protection function for intermittent ground faults can only take effect and is only accessible if the current to be evaluated was configured in address 133, INTERM.EF (with Ignd or with with 3I0 or with Ignd,sens.). If not required, this function is set to Disabled. The function can be turned ON or OFF under address 3301 INTERM.EF. The pickup threshold (r.m.s. value) is set in address 3302 Iie>. A rather sensitive setting is possible to respond also to short ground faults since the pickup time shortens as the current in excess of the setting increases. The setting range depends on the selection of the current to be evaluated at address 133 INTERM.EF. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 201 Functions 2.13 Intermittent Ground Fault Protection The pickup time can be prolonged at address 3303 T-det.ext.. This pickup stabilization is especially important for the coordination with existing analog or electromechanical overcurrent relays. The time T-det.ext. can also be disabled (T-det.ext. = 0). The stabilized pickup starts the counter T-sum det.. This counter is stopped but not reset when the picked up function drops out. Based on the last counter content the counter resumes counting when the stabilized function picks up next. This sum of individual pickup times, which are to initiate tripping, is set at address 3304 T-sum det.. It represents one of the four selectivity criteria (pickup value Iie>, detection extension time T-det.ext., counter T-sum det. and reset time T-reset) for coordinating the relays on adjacent feeders and is comparable to the time grading of the time overcurrent protection. The relay in the radial network which is closest to the intermittent fault and picks up, will have the shortest summation time T-sum det.. The reset time, after which the summation is reset in healthy operation and the protection resumes normal status, is configured to T-reset at address 3305. [selektivitaetskrit-intermitt-erdfehler-120902-oz, 1, en_US] Figure 2-87 Example of selectivity criteria of the intermittent ground fault protection Address 3306 Nos.det. specifies the number of pickups after which a ground fault is considered intermittent. 2.13.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 3301 INTERM.EF 3302 Iie> 3302 Iie> C Setting Options Default Setting Comments OFF ON OFF Intermittent earth fault protection 1A 0.05 .. 35.00 A 1.00 A 5A 0.25 .. 175.00 A 5.00 A Pick-up value of interm. E/F stage 1A 0.05 .. 35.00 A 1.00 A 5A 0.25 .. 175.00 A 5.00 A Pick-up value of interm. E/F stage 3302 Iie> 0.005 .. 1.500 A 1.000 A Pick-up value of interm. E/F stage 3303 T-det.ext. 0.00 .. 10.00 sec 0.10 sec Detection extension time 3304 T-sum det. 0.00 .. 100.00 sec 20.00 sec Sum of detection times 3305 T-reset 1 .. 600 sec 300 sec Reset time 3306 Nos.det. 2 .. 10 3 No. of det. for start of int. E/F prot 202 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.13 Intermittent Ground Fault Protection 2.13.4 Information List No. Information Type of Information Comments 6903 >IEF block SP >block interm. E/F prot. 6921 IEF OFF OUT Interm. E/F prot. is switched off 6922 IEF blocked OUT Interm. E/F prot. is blocked 6923 IEF enabled OUT Interm. E/F prot. is active 6924 IIE Fault det OUT Interm. E/F detection stage Iie> 6925 IIE stab.Flt OUT Interm. E/F stab detection 6926 IIE Flt.det FE OUT Interm.E/F det.stage Iie> f.Flt. ev.Prot 6927 Intermitt.EF OUT Interm. E/F detected 6928 IEF Tsum exp. OUT Counter of det. times elapsed 6929 IEF Tres run. OUT Interm. E/F: reset time running 6930 IEF Trip OUT Interm. E/F: trip 6931 Iie/In= VI Max RMS current value of fault = 6932 Nos.IIE= VI No. of detections by stage Iie>= SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 203 Functions 2.14 Dir. Intermittent earth fault protection 2.14 Dir. Intermittent earth fault protection The directional intermittent ground fault protection is designed to selectively detect intermittent ground faults in compensated or grounded cable systems. Intermittent ground faults are usually characterized by the following properties: - Very short high ground current pulses (up to several hundred amperes) with a duration of less than 1 ms; - They are self-extinguishing and re-ignite within one half period up to several periods, depending on the power system conditions and the fault characteristic. - They can persist over longer periods (many seconds to minutes) and develop into static faults. Such intermittent ground faults are frequently caused by weak insulation, e.g. due to decreased water resistance of old cables. Ground fault functions based on fundamental component measured values are primarily designed to detect static ground faults and do not always operate correctly in the event of intermittent ground faults. The function described here evaluates specifically the ground current pulses and puts them into relation with the displacement voltage to determine the direction. Applications * Directional protection against intermittent ground faults which occur, e.g. in cables due to poor insulation or water ingress in cable joints. 2.14.1 Functional Description Activating the Function The function is only available if the device is equipped with a sensitive ground current input. For voltage connection 213 VT Connect. 3ph = Vab, Vbc oder Vab, Vbc, Vx or Vab, Vbc, VSyn oder Vph-g, VSyn and for 250 50/51 2-ph prot = ON, the directional intermittent ground fault protection is ineffective. V0 cannot be formed for these connection types. The function is blocked in case of a measuring voltage failure under the condition that the fuse-failure monitor is configured for the functioning in a grounded system (see Section 2.11.1 Measurement Supervision, FuseFailure Monitor). Furthermore, the function can be blocked externally using the binary input signal >dIEF block. 204 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.14 Dir. Intermittent earth fault protection [7sx8-iefger-aktiv-20120611, 1, en_US] Figure 2-88 Activation of the directional intermittent ground fault protection Measurand Acquisition The intermittent ground fault current 3I0 is measured exclusively via the sensitive ground current input INs (4th current transformer input) of the device. Also the displacement voltage V0 or 3 * V0 is required to determine the direction. The displacement voltage V0 can be applied directly to the device, or the summation voltage 3 * V0 can be calculated from the three phaseto-ground voltages. If the displacement voltage is calculated, then: 3 * V0 = VA + VB + VC If the displacement voltage is directly applied to the device, then V0 is the voltage at the device terminals. It is not affected by parameter Vph / Vdelta (address 206). Fault Log, Ground Fault Log, Fault Recording Parameter Dir. Interm. EF allows you to define the type of fault handling and fault logging. If set to ON, tripping is possible and a fault log is generated. If set to ON with ON with GF log, tripping is possible, a fault log and a ground fault log are generated. If set to Alarm Only, no tripping is possible. Only an alarm is generated. Furthermore, only a ground fault log is created. The raising pickup of the function (indication 6972 dIEF pick up) is the criterion for opening the ground fault log. Logic Diagram The following figure shows the logic diagram of the directional intermittent ground fault protection function. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 205 Functions 2.14 Dir. Intermittent earth fault protection [7sj62-64-iefger-logik-20120611, 1, en_US] Figure 2-89 Logic diagram of the directional intermittent ground fault protection Direction Determination The ground fault is detected by evaluating the fundamental component of the displacement voltage. The sensitivity is determined using the settable threshold value Vgnd> / 3V0>. Direction determination is started after the ground fault has been detected. For this purpose, the igniting current pulses are extracted from the ground current signal. The igniting current pulse and the associated maximum displacement voltage over time are compared with regard to their phase relationship. The fault direction forward or reverse is derived from this comparison. Each detected ignition pulse receives a direction information. If no clear direction determination is possible, the direction information pertaining to the pulse is undefined. The direction results of the recurring ignition pulses are counted and are available as value indication if their value is different than zero. Pickup The setting of parameter Pickup defines under which conditions pickup is detected and fault recording started. For with with Vgnd/3V0>, pickup is initiated once the threshold Vgnd> / 3V0> has been exceeded. For with oper. dir., pickup is initiated when a pulse is detected in the direction specified at 206 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.14 Dir. Intermittent earth fault protection address 3402. The pickup disappears when the displacement voltage has fallen below the threshold Vgnd> / 3V0> and the time Monitoring time has expired. Alarm/Trip The setting of parameter Direction defines whether the function operates in forward or in reverse direction. The pulses in the specified direction are counted. If the pulse counter reaches the threshold value set in parameter No. of pulses, the function trips or generates an alarm. It is possible that not every ignition pulse is recognized as such. If two ignition pulses are very close to one another in respect of time, they may not be detected separately. This is not relevant from the protection perspective, because during an intermittent fault many ignition pulses occur and the counter threshold is certainly reached. The directional pulse counter is reset under the following conditions: * A different direction than the set Direction is detected. An undefined direction result does not reset the counter. * The monitoring time Monitoring time has elapsed. No other pulse in the set direction was detected during that time. This time can be understood as a criterion for the disappearing of the intermittent fault. The function thus also drops out if the intermittent fault develops into a static fault. * V0 is lower than the set threshold Vgnd> / 3V0> and the time Monitoring time has expired. Interaction with other Functions The directional intermittent ground fault protection does not interact with the automatic reclosing function. The function cannot start the automatic reclosing function. The directional intermittent ground fault protection interacts with the circuit-breaker failure protection. The function starts the circuit-breaker failure protection. 2.14.2 Setting Notes General Configuration of the protection functions at address 134 Dir. Interm. EF defines whether the directional intermittent ground fault protection is Enabled Disabled. At address 3401 Dir. Interm. EF the directional ground fault protection is switched on or off. The following setting options are available: * ON enables the function with tripping and fault record log. * * * ON with GF log enables the function with tripping, fault record log and ground fault log. Alarm Only generates the ground fault log only. Tripping and fault record log are not possible. OFF disables the function. The pickup threshold for the displacement voltage is set at address 3405 Vgnd> / 3V0>. Exceeding this threshold is the criterion for detecting the intermittent ground fault. The direction to be protected Forward or Reverse is set in address 3402 Direction. Address 3403 No. of pulses allows you to specify how many pulses must be detected in the set direction before the alarm or tripping is initiated. It is possible that not every ignition pulse is recognized as such. If two ignition pulses are very close to one another in respect of time, they may not be detected separately. This is not relevant from the protection perspective, because during an intermittent fault many ignition pulses occur and the counter threshold is certainly reached. At address 3404 Monitoring time you set the monitoring time after detection of the direction pulse in the direction parameterized at 3402. If the time has expired before the number set at 3403 No. of pulses has been reached, the associated counter is reset. This time is a criterion for the disappearing of the intermittent fault. At address 3406 Pickup you can set the criterion for the pickup of the function. For with with Vgnd/3V0> pickup takes place as soon as the threshold Vgnd> / 3V0> has been exceeded, regardless of whether a real SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 207 Functions 2.14 Dir. Intermittent earth fault protection intermittent ground fault is present or not. For with oper. dir., recording starts when a direction pulse in the direction parameterized at 3402 has been detected. 2.14.3 Settings Addr. Parameter Setting Options Default Setting Comments 3401 Dir. Interm. EF OFF ON ON with GF log Alarm Only OFF Dir. Intermittent earth fault protection 3402 Direction Forward Reverse Forward Direction to be protected 3403 No. of pulses 2 .. 50 5 Pulse no. for detecting the interm. E/F 3404 Monitoring time 0.04 .. 10.00 sec 2.00 sec Monitoring time after pickup detected 3405 Vgnd> / 3V0> 2.0 .. 100.0 V 20.0 V Vgnd> measured / 3V0> calculated 3406 Pickup with Vgnd/3V0> with oper. dir. with Vgnd/3V0> Pickup of the function 2.14.4 Information List No. Information Type of Information Comments 6951 >dIEF block SP >Block directional interm. E/F prot. 6961 dIEF OFF OUT Dir. Interm. E/F prot. is switched off 6962 dIEF blocked OUT Dir. Interm. E/F prot. is blocked 6963 dIEF active OUT Dir. Interm. E/F prot. is active 6972 dIEF pick up OUT dIEF: pick up 6973 dIEF TRIP OUT dIEF: Trip 6974 No.forward= VI dIEF: No. of detected forward pulses = 6975 No.reverse= VI dIEF: No. of detected reverse pulses = 6976 No.undef.= VI dIEF: No. of detected undefined pulses = 6979 dIEF ALARM OUT dIEF: Alarm 208 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 2.15 Automatic Reclosing System 79 From experience, about 85 % of insulation faults associated with overhead lines are arc short circuits which are temporary in nature and disappear when protection takes effect. This means that the line can be connected again. The reconnection is accomplished after a dead time via the automatic reclosure function. If the fault still exists after automatic reclosure (arc has not disappeared, there is a metallic fault), then the protective elements will re-trip the circuit breaker. In some systems, several reclosing attempts are performed. Applications * The automatic reclosure system integrated in the 7SJ80 can also be controlled by an external protection device (e.g. backup protection). For this application, a signal exchange must occur between 7SJ80 and the external protection device via binary inputs and outputs. * * It is also possible to allow the relay 7SJ80 to work in conjunction with an external reclosing device. * Since the automatic reclosing function is not applied when the 7SJ80 is used to protect generators, motors, transformers, cables and reactors etc., it should be disabled for this application. The automatic reclosure system can also operate in interaction with the integrated synchronization function or with an external synchrocheck. 2.15.1 Program Execution The 7SJ80 is equipped with an integrated three-pole, single-shot and multi-shot automatic reclosure (AR). Figure 2-100 shows an example of a timing diagram for a successful second reclosure. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 209 Functions 2.15 Automatic Reclosing System 79 [ablaufdiagramm-2-malige-wiedereinschaltung-erfolgreich-260602-kn, 1, en_US] Figure 2-90 Timing diagram showing two reclosing shots, first cycle unsuccessful, second cycle successful The following figure shows an example of a timing diagram showing for two unsuccessful reclosing shots, with no additional reclosing of the circuit breaker. The number of reclose commands initiated by the automatic reclosure function are counted. A statistical counter is available for this purpose for the first and all subsequent reclosing commands. 210 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 [ablaufdiagramm-2-malige-wiedereinschaltung-erfolglos-260602-kn, 1, en_US] Figure 2-91 Timing diagram showing two unsuccessful reclosing shots Initiation Initiation of the automatic reclosing function can be caused by internal protection functions or externally via binary inputs. The automatic reclosing function can be programmed in such manner that any of the elements of the following Table can initiate (Starts 79), not initiate (No influence), or block reclosing (Stops 79): Table 2-14 Anwurf AWE Non-directional start Directional start Start other 50-1 67-1 Senitive Ground Fault Protection (50Ns, 51Ns) 50N-1 67N-1 Negative Sequence Protection 46 50-2 67-2 BINARY INPUT 50-3 67-3 50N-2 67N-2 50N-3 67N-3 51 67-TOC 51N 67N-TOC On initiation, the automatic reclosure function is informed that a trip command was issued and the respective reclosing program is now being executed. The binary input messages 2715 >Start 79 Gnd and 2716 >Start 79 Ph for starting an automatic reclosure program can also be activated via CFC (fast PLC task processing). Automatic reclosure can thus be initiated via any messages (e.g. protective pickup) if address 7164 BINARY INPUTis set to Starts 79. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 211 Functions 2.15 Automatic Reclosing System 79 Action Time The action time (address 7117) monitors the time between a device pickup and the trip command of a protection function configured as starter. The action time is launched when pickup of any function is detected, which is set as source of the automatic reclosure program. Protection functions which are set to Alarm Only or which in principle should not start a reclosing program do not trigger the action time. If a protection function configured as starter initiates a trip command during the action time, the automatic reclosure program is started. Trip commands of a protection function configured as starter occurring in the time between expiration of the action time and dropout of the device pickup cause the dynamic blocking of the automatic reclosing program. Trip commands of protection functions which are not configured as starter do not affect the action time. If the automatic reclosure program interacts with an external protection device, the general device pickup for starting the operating time is communicated to the automatic reclosing program via binary input 2711 >79 Start. Delay of Dead Time Start After start of the automatic reclosure function, the dead time start can be delayed by pickup of the binary input message 2754 >79 DT St.Delay. The dead time is not initiated as long as the binary input is active. Start occurs only on cleared binary input. The delay of the dead time start can be monitored via parameter 7118 T DEAD DELAY. If the time elapses and the binary input is still active, the Automatic Reclosing System 79 changes to the status of the dynamic blocking via (2785 79 DynBlock). The maximum time delay of the dead time start is logged by message 2753 79 DT delay ex.. Reclosing Programs Depending on the type of fault, two different reclosing programs can be used. Here the following applies: * The single phase fault (ground fault) reclosing program applies if all fault protection functions that initiate automatic reclosure detected a phase-to-ground fault. The following conditions must apply: only one phase, only one phase and ground or only ground have picked up. This program can also be started via a binary input. * The multiple phase fault (phase fault) reclosing program applies to all other cases. That is, when elements associated with two or more phases pick up, with or without the pickup of ground elements, such as negative sequence elements. This program can be started via a binary input as well. The reclosure program evaluates only elements during pickup as elements dropping out may corrupt the result if they drop out at different times when opening the circuit breaker. Therefore, the ground fault reclosure program is executed only when the elements associated with one particular phase pick up until the circuit breaker is opened; all others conditions will initiate the phase fault program. For each of the programs, up to 9 reclosing attempts can be separately programmed. The first four reclosing attempts can be set differently for each of the two reclosing programs. The fifth and each of the following automatic reclosures will correspond to the fourth dead time. Reclosing Before Selectivity For the automatic reclosure sequence to be successful, faults on any part of the line must be cleared from the feeding line end(s) within the same - shortest possible - time. Usually, therefore, an instantaneous protection element is set to operate before an automatic reclosure. Fast fault termination has thus priority over selectivity aspects as the reclosing action aims at maintaining normal system operation. For this purpose, all protection functions which can initiate the automatic reclosure function are set in such manner that they may trip instantaneously or with a very small time delay before automatic reclosure. With the final reclosing attempt, i.e. when no automatic reclosing is expected, protection is to trip with delay according to the grading coordination chart of the system, since selectivity has priority.For details see also information at margin heading "Interaction with the Automatic Reclosing Function" which can be found with the setting notes of the overcurrent protection functions and the functional description of the intermittent ground fault protection. 212 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 Single-Shot Reclosing When a trip signal is programmed to initiate the automatic reclosure, the appropriate automatic reclosing program will be executed. Once the circuit breaker has opened, a dead time interval in accordance with the type of fault is started (see also margin heading "Reclosing Programs"). Once the dead time interval has elapsed, a closing signal is issued to reclose the circuit breaker. A blocking time interval TIME RESTRAINT is started at the same time. Within this restraint time it is checked whether the automatic reclosure was performed successfully. If a new fault occurs before the restraint time elapses, the automatic reclosing function is dynamically blocked causing the final tripping of the circuit breaker. The dead time can be set individually for each of the two reclosing programs. Criteria for opening the circuit breaker may either be the auxiliary contacts of the circuit breaker or the dropout of the general device pickup if auxiliary contacts are not configured. If the fault is cleared (successful reclosing attempt), the blocking time expires and automatic reclosing is reset in anticipation of a future fault. The fault is terminated. If the fault has not been cleared (unsuccessful reclosing attempt), then a final trip signal is initiated by one or more protective elements. Multi-shot Reclosing 7SJ80 permits up to 9 reclosings. The number can be set differently for the phase fault reclosing program and the ground fault reclosing program. The first reclose cycle is, in principle, the same as the single-shot auto-reclosing. If the first reclosing attempt is unsuccessful, this does not result in a final trip, but in a reset of the restraint time interval and start of the next reclose cycle with the next dead time. This can be repeated until the set number of reclosing attempts for the corresponding reclose program has been reached. The dead time intervals preceding the first four reclosing attempts can be set differently for each of the two reclosing programs. The dead time intervals preceding the fifth reclosing attempts will be equal to the dead time interval that precedes the fourth reclosing attempt. If one of the reclosing attempts is successful, i.e. the fault disappeared after reclosure, the restraint time expires and the automatic reclosing function is reset. The fault is cleared. If none of the reclosing attempts is successful, then a final circuit breaker trip (according to the grading coordination chart) will take place after the last allowable reclosing attempt has been performed by the protection function. All reclosing attempts were unsuccessful. After the final circuit breaker tripping, the automatic reclosing function is dynamically blocked (see below). Blocking Time The function of the blocking time has already been described under section "Single-/Multi-Shot Reclosing". The blocking time can be prolonged if the following conditions have been fulfilled. The time 211 TMax CLOSE CMD defines the maximum time during which a close command can apply. If a new trip command occurs before this time has run out, the close command will be canceled. If the time TMax CLOSE CMD is set longer than the restraint time TIME RESTRAINT, the restraint time will be extended to the remaining close command duration after expiry! A pickup from a protection function that is set to initiate the automatic reclosing function will also lead to an extension of the blocking time should it occur during this time! 2.15.2 Blocking Static Blocking Static blocking means that the automatic reclosing function is not ready to initiate reclosing, and cannot initiate reclosing as long as the blocking signal is present. A corresponding message 79 is NOT ready (FNo. 2784) is generated. The static blocking signal is also used internally to block the protection elements that are only supposed to work when reclosing is enabled (see also side title "Reclosing Before Selectivity" further above). The automatic reclosing function is statically blocked if: SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 213 Functions 2.15 Automatic Reclosing System 79 * The signal >BLOCK 79 FNo. 2703) is present at a binary input, as long as the automatic reclosing function is not initiated (associated message: >BLOCK 79), * The signal >CB Ready (FNo. 2730) indicates that the circuit breaker disappears via the binary input, if the automatic reclosing function is not initiated (associated message: >CB Ready), * The number of allowable reclosing attempts set for both reclosing programs is zero (associated message: 79 no cycle), * No protection functions (parameters 7150 to 7163) or binary inputs are set to initiate the automatic reclosing function (associated message: 79 no starter), * The circuit breaker position is reported as being "open" and no trip command applies (associated message: 79 BLK: CB open). This presumes that 7SJ80 is informed of the circuit breaker position via the auxiliary contacts of the circuit breaker. Dynamic Blocking Dynamic blocking of the automatic reclosing function occurs in those cases where the reclosing program is active and one of the conditions for blocking is fulfilled. The dynamic blocking is signaled by the message 79 DynBlock. The dynamic blocking is associated with the configurable blocking time SAFETY 79 ready. This blocking time is usually started by a blocking condition that has been fulfilled. After the blocking time has elapsed, the device checks whether or not the blocking condition can be reset. If the blocking condition is still present or if a new blocking condition is fulfilled, the blocking time is restarted. If, however, the blocking condition no longer exists after the blocking time has elapsed, the dynamic blocking will be reset. Dynamic blocking is initiated if: * The maximum number of reclosure attempts has been achieved. If a trip command now occurs within the dynamic blocking time, the automatic reclosure program will be blocked dynamically (indicated by 79 Max. No. Cyc). 214 * The protection function has detected a three-phase fault and the device is programmed not to reclose after three-phase faults (indicated by 79 BLK:3ph p.u.). * if the maximum waiting period T DEAD DELAY for the delay of the dead time initiation by binary inputs expires without binary input >79 DT St.Delay having been disabled during this time period. * The action time has elapsed without a TRIP command being issued. Each TRIP command that occurs after the action time has expired and before the picked-up element drops out, will initiate the dynamic blocking (indicated by 79 Tact expired). * A protection function trips which is to block the automatic reclosure function (as configured). This applies irrespective of the status of the automatic reclosure system (started / not started) if a TRIP command of a blocking element occurs (indicated by 79 BLK by trip). * * The circuit breaker failure function is initiated. The circuit breaker does not trip within the configured time T-Start MONITOR after a trip command was issued, thus leading to the assumption that the circuit breaker has failed. (The breaker failure monitoring is primarily intended for commissioning purposes. Commissioning safety checks are often conducted with the circuit breaker disconnected. The breaker failure monitoring prevents unexpected reclosing after the circuit breaker has been reconnected, indicated by 79 T-Start Exp). * wenn der Leistungsschalter nach Ablauf der Leistungsschalteruberwachungszeit nicht schaltbereit ist, vorausgesetzt die Leistungsschalterabfrage ist wirksam gestellt (Adresse 7113 CHECK CB? = Chk each cycle, signalisiert durch die Meldung 79 T-CBreadyExp), * The circuit breaker is not ready after maximum extension of the dead time Max. DEAD EXT.. The monitoring of the circuit breaker status and the synchrocheck may cause undesired extension of the dead time. To prevent the automatic reclosure system from assuming an undefined state, the extension of the dead time is monitored. The extension time is started when the regular dead time has elapsed. When it has elapsed, the automatic reclosure function is blocked dynamically and the lock-out time launched. The automatic reclosure system resumes normal state when the lock-out time has elapsed and new blocking conditions do not apply (indicated by 79 TdeadMax Exp) . SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 * Manual closing has been detected (externally) and parameter BLOCK MC Dur. (T 0) was set so that the automatic reclosing function responds to manual closing, * Via a correspondingly routed binary input (FNo. 2703 >BLOCK 79). If the blocking takes places while the automatic recloser is in normal state, the latter will be blocked statically (79 is NOT ready). The blocking is terminated immediately when the binary input has been cleared and the automatic reclosure function resumes normal state. If the automatic reclosure function is already running when the blocking arrives, the dynamic blocking takes effect (79 DynBlock). In this case, the activation of the binary input starts the dynamic blocking time SAFETY 79 ready. Upon its expiration, the device checks if the binary input is still activated. If this is the case, the automatic reclosure program changes from dynamic blocking to static blocking. If the binary input is no longer active when the time has elapsed and if no new blocking conditions apply, the automatic reclosure system resumes normal state. 2.15.3 Status Recognition and Monitoring of the Circuit Breaker Circuit Breaker Status The detection of the actual circuit breaker status is necessary for the correct functionality of the automatic reclosure function. The circuit breaker status is detected by the circuit breaker auxiliary contacts and is communicated to the device via binary inputs 4602 >52-b and 4601 >52-a. Here the following applies: * If binary input 4601 >52-a and binary input 4602 >52-b are used, the automatic reclosure function can detect whether the circuit breaker is open, closed or in intermediate position. If both auxiliary contacts detect that the circuit breaker is open, the dead time is started. If the circuit breaker is open or in intermediate position without a trip command being present, the automatic reclosure function is blocked dynamically if it is already running. If the automatic reclosure system is in normal state, it will be blocked statically. When checking whether a trip command applies, all trip commands of the device are taken into account irrespective of whether the function acts as starting or blocking element on behalf of the automatic reclosure program. * If only the binary input 4601 >52-a is allocated, the circuit breaker is considered open if the binary input is not active. If the binary input gets inactive while no trip command of (any) function applies, the automatic reclosure function is blocked. The blocking will be of static nature if the automatic reclosure function is in normal state at this time. If the automatic reclosing function is already running, there will be a dynamic blocking. The dead time is started if the binary input gets inactive following the trip command of a starting element (4601 >52-a = inactive). An intermediate position of the circuit breaker cannot be detected for this type of allocation. * If binary input 4602 >52-balone is allocated, the circuit breaker is considered open while the binary input is active. If the binary input gets active while no trip command of (any) function applies, the automatic reclosure function is blocked dynamically provided it is already running. Otherwise, there will be a static blocking. The dead time is started if the binary input gets active following the trip command of a starting element. An intermediate position of the circuit breaker cannot be detected for this type of allocation. * If neither binary input 4602 >52-b nor 4601 >52-a are allocated, the automatic reclosure program cannot detect the position of the circuit breaker. In this case, the automatic reclosure function will be controlled exclusively via pickups and trip commands. Monitoring for "52-b without TRIP" and starting the dead time in dependence of the circuit breaker feedback is not possible in this case. Circuit Breaker Monitoring The time needed by the circuit breaker to perform a complete reclose cycle can be monitored by the 7SJ80. Breaker failure is detected: A precondition for a reclosing attempt, following a trip command initiated by a protective relay element and subsequent initiation of the automatic reclosing function, is that the circuit breaker is ready for at least one TRIP-CLOSE-TRIP cycle. The readiness of the circuit breaker is monitored by the device using a binary input >CB Ready. In the case where this signal from the breaker is not available, the circuit breaker monitoring feature should be disabled, otherwise reclosing attempts will remain blocked. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 215 Functions 2.15 Automatic Reclosing System 79 * Especially when multiple reclosing attempts are programmed, it is a good idea to monitor the circuit breaker condition not only prior to the first but also to each reclosing attempt. A reclosing attempt 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 7SJ80. The monitoring time CB TIME OUT expires for as long as the circuit breaker does not indicate that it is ready via binary input >CB Ready (FNo. 2730). That means if the binary input >CB Ready is cleared, the monitoring time CB TIME OUT is started. If the binary input returns before the monitoring time has elapsed, the monitoring time will be canceled and the reclosure process is continued. If the monitoring time runs longer than the dead time, the dead time will be extended accordingly. If the monitoring time elapses before the circuit breaker signals its readiness, the automatic reclosure function will be blocked dynamically. Interaction with the synchronism check may cause the dead time to extend inadmissibly. To prevent the automatic reclosure function from remaining in an undefined state, dead time extension is monitored. The maximum extension of the dead time can be set at Max. DEAD EXT.. The monitoring time Max. DEAD EXT. is started when the regular dead time has elapsed. If the synchronism check responds before the time has elapsed, the monitoring time will be stopped and the close command generated. If the time expires before the synchronism check reacts, the automatic reclosure function will be blocked dynamically. Please make sure that the above mentioned time is not shorter than the monitoring time CB TIME OUT. The time 7114 T-Start MONITOR serves for monitoring the response of the automatic reclosure function to a breaker failure. It is activated by a trip command arriving before or during a reclosing operation and marks the time that passes between tripping and opening of the circuit breaker. If the time elapses, the device assumes a breaker failure and the automatic reclosure function is blocked dynamically. If parameter T-Start MONITOR is set to , the start monitoring is disabled. 2.15.4 Controlling Protection Elements Depending on the reclosing cycle it is possible to control elements of the directional and non-directional overcurrent protection by means of the automatic reclosure system (Protective Elements Control). There are three mechanisms: * Time overcurrent protection and the sensitive ground fault protection elements may trip instantaneously depending on the automatic reclosure cycle (T = 0), they may remain unaffected by the auto reclosing function AR (T = T) or may be blocked (T = ). For further information see side title "Cyclic Control". * The automatic reclosing states "Auto Reclosing ready" and "Auto Reclosing not ready" can activate or deactivate the dynamic cold load pickup function. This function is designed to influence overcurrent stages (see also Section 2.16.6 and Section 2.15.6 Setting Notes) regarding thresholds and tripping time delays. * The time overcurrent protection parameter 1X14A 50(N)-2 ACTIVE or 1X16A 50(N)-3 ACTIVE defines whether the elements 50(N)-2 or 50(N)-3 are to operate always or only with "79M Auto Reclosing ready"(see Section 2.2 Overcurrent Protection 50, 51, 50N, 51N). Cyclic Control Control of the time overcurrent protection and sensitive ground fault protection elements takes effect by releasing the cycle marked by the corresponding parameter. The cycle zone release is indicated by the messages 79 1.CycZoneRel to 79 4.CycZoneRel. If the automatic reclosure function is in normal state, the settings for the starting cycle apply. These settings always take effect when the automatic reclosure function assumes normal state. The settings are released for each following cycle when issuing the close command and starting the blocking time. Following a successful reclosure (blocking time expired) or after returning from the blocking, the automatic reclosure function goes into normal state. Control of the protection is again assumed by the parameters for the starting cycle. The following figure illustrates the control of the protection elements 50-2 and 50N-2. 216 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 [schutzstufensteuerung-bei-zweimaliger-erfolgreicher-awe-260602-kn, 1, en_US] Figure 2-92 Control of protection elements for two-fold, successful automatic reclosure Example Before the first reclosing, faults are to be eliminated quickly applying elements 50-2 or 50N-2. Fast fault termination thus has priority over selectivity aspects as the reclosing action aims at maintaining normal system operation. If the fault prevails, a second tripping is to take place instantaneously and subsequently, a second reclosing. After the second reclosing, however, elements 50-2 or 50N-2 are to be blocked so the fault can be eliminated by applying elements 50-1 or 50N-1 according to the grading coordination chart of the system giving priority to selectivity concerns. Addresses 7202 bef.1.Cy:50-2, 7214 bef.2.Cy:50-2 and 7203 bef.1.Cy:50N-2 und 7215 bef. 2.Cy:50N-2 are set to instant. T=0 to enable the elements after the first reclosing. Addresses 7226 bef. 3.Cy:50-2 and 7227 bef.3.Cy:50N-2, however, are set to blocked T=, to ensure that elements 50-2 and 50N-2 are blocked when the second reclosing applies. The back-up elements, e.g. 50-1 and 50N-1, must obviously not be blocked (addresses 7200, 7201, 7212, 7213, 7224 and 7225). The blocking applies only after reclosure in accordance with the set address. Hence, it is possible to specify again other conditions for a third reclosure. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 217 Functions 2.15 Automatic Reclosing System 79 The blocking conditions are also valid for the zone sequence coordination, provided it is available and activated (address 7140, see also margin heading "Zone Sequencing"). 2.15.5 Zone Sequencing / Fuse Saving Scheme Zone Sequencing / Fuse Saving Scheme is not available for models 7SJ6***-**A**-. It is the task of the zone sequence coordination to harmonize the automatic reclosure function of this device with that of another device that forms part of the same power system. It is a complementary function to the automatic reclosure function and allows, for example, to perform group reclosing operations in radial systems. In case of multiple reclosures, groups may also be in nested arrangement and further high-voltage fuses can be overgraded or undergraded. Zone sequencing works by blocking certain protection functions depending on the reclosing cycle. This is implemented by the protection elements control (see margin heading "Controlling Protection Elements"). As a special feature, changing from one reclosing cycle to the next is possible without trip command only via pickup/dropout of 50-1 or 50N-1. The following figure shows an example of a group reclosure at feeder 3. It is assumed that reclosure is performed twice. With fault F1 on feeder 5, protection devices in the infeed and on feeder 3 pick up. The time delay of the 50-2 element at protecting feeder 3 is set in such a way that the feeder 3 circuit breaker will clear the fault before the fuse at feeder 5 is damaged. If the fault is cleared, all functions are reset after the restraint time has expired and the fault is terminated. The fuse has therefore also been protected. If the fault continues to exist, a second reclosing cycle is performed in the same way. High speed element 50-2 is now blocked at relay protecting Feeder 3. If the fault still remains, only the 50-1 element continues to be active in Feeder 3 which, however, overgrades the fuse with a time delay of 0.4 s. After the fuse operated to clear the fault, the series-connected devices drop out. If the fuse fails to clear the fault, then the 50-1 element protecting Feeder 3 will operate as backup protection. The 50-2 element at the busbar relay is set with a delay of 0.4 seconds, since it supposed to trip the 50-2 elements and the fuses as well. For the second reclosing, the 50-2 element also has to be blocked to give preference to the feeder relay (50-1 element with 0.4 s). For this purpose, the device has to "know" that two reclosing attempts have already been performed. In this device, zone sequence coordination must be switched on: When pickup of 50-1 or 50N-1 drops out, zone sequence coordination provokes that the reclosing attempts are counted as well. If the fault still persists after the second reclosure, the 50-1 element, which is set to 0.9 seconds, would serve as backup protection. For the busbar fault F2, the 50-2 element at the bus would have cleared the fault in 0.4 seconds. Zone sequencing enables the user to set a relatively short time period for the 50-2 elements. The 50-1 element is only used as backup protection. If zone sequencing is not applied, the 50-1 element is to be used only with its relatively long time period (0.9 s). [ablaufkoordinierung-fehler-am-abgang-5-ss-260602-kn, 1, en_US] Figure 2-93 218 Zone sequencing with a fault occurring at Tap Line 5 and at the busbar SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 2.15.6 Setting Notes General Settings The internal automatic reclosure function will only be effective and accessible if address 171 79 Auto Recl. is set Enabled during configuration. If not required, this function is set to Disabled. The function can be turned ON or OFF under address 7101 FCT 79. If no automatic reclosures are performed on the feeder for which the 7SJ80 is used (e.g. cables, transformers, motors, etc.), the automatic reclosure function is disabled by configuration. The automatic reclosure function is then completely disabled, i.e. the automatic reclosure function is not processed in the 7SJ80. No messages exist for this purpose and binary inputs for the automatic reclosure function are ignored. All parameters of block 71 are inaccessible and of no significance. Blocking Duration for Manual-CLOSE Detection Parameter 7103 BLOCK MC Dur. defines the reaction of the automatic reclosure function when a manual closing signal is detected. The parameter can be set to specify how long the auto reclosure function will be blocked dynamically in case of an external Manual close-command being detected via binary input (356 >Manual Close). If the setting is 0, the automatic reclosure function will not respond to a Manual close signal. Restraint Time and Dynamic Blocking The blocking time TIME RESTRAINT(address 7105) defines the time that must elapse, after a successful reclosing attempt, before the automatic reclosing function is reset. If a protective function configured for initiation of the automatic reclosure function provokes a new trip before this time elapses, the next reclosing cycle is started in case of multiple reclosures. If no further reclosure is allowed, the last reclosure will be classed as unsuccessful. In general, a few seconds are 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 flashovers. A longer restraint time should be chosen if there is no possibility to monitor the circuit breaker (see below) during multiple reclosing (e.g. because of missing auxiliary contacts and information on the circuit breaker ready status). In this case, the restraint time should be longer than the time required for the circuit breaker mechanism to be ready. If a dynamic blocking of the automatic reclosing function was initiated, then reclosing functions remain blocked until the cause of the blocking has been cleared. The functional description gives further information on this topic, see side title "Dynamic Blocking". The dynamic blocking is associated with the configurable blocking time SAFETY 79 ready. Blocking time is usually started by a blocking condition that has picked up. Circuit Breaker Monitoring Reclosing after a fault clearance presupposes that the circuit breaker is ready for at least one TRIP-CLOSE-TRIP cycle at the time when the reclosing function is initiated (i.e. at the beginning of a trip command): The readiness of the circuit breaker is monitored by the device using a binary input >CB Ready (FNo. 2730). * It is possible to check the status of the circuit breaker before each reclosure or to disable this option (address 7113, CHECK CB?): CHECK CB? = No check, deactivates the circuit breaker check, CHECK CB? = Chk each cycle, to verify the circuit breaker status before each reclosing command. Checking the status of the circuit breaker is usually recommended. Should the breaker not provide such a signal, you can disable the circuit breaker check at address 7113 CHECK CB? (No check), as otherwise auto-reclosure would be impossible. The status monitoring time CB TIME OUT can be configured at address 7115 if the circuit breaker check was enabled at address 7113. This time is set slightly higher than the maximum recovery time of the circuit breaker following reclosure. If the circuit breaker is not ready after the time has expired, reclosing is omitted and dynamic blocking is initiated. Automatic reclosure thus is blocked. Time Max. DEAD EXT. serves for monitoring the dead time extension. The extension can be initiated by the circuit breaker monitoring time CB TIME OUT and by an external synchronism check. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 219 Functions 2.15 Automatic Reclosing System 79 The monitoring time Max. DEAD EXT. is started after the configured dead time has elapsed. This time must not be shorter than CB TIME OUT. When using the monitoring time CB TIME OUT, the time Max. DEAD EXT. should be set to a value CB TIME OUT. Since the synchronization is used as synchrocheck, the monitoring time can be set quite short, for example to a few seconds. The synchronization function merely "checks" the synchronism of the power systems. If synchronism is detected, it will be connected instantaneously, otherwise it will not. Generally, the monitoring time should be longer than the maximum duration of the synchronization process (parameter 6112). The breaker failure monitoring time 7114 T-Start MONITOR determines the time between tripping (closing the trip contact) and opening the circuit breaker (checkback of the CB auxiliary contacts or disappearing device pickup if no auxiliary contacts are allocated). This time is started each time a tripping operation takes place. When time has elapsed, the device assumes breaker failure and blocks the automatic reclosure function dynamically. Action Time The action time monitors the time between pickup of the device and trip command of a protective function configured as starter while the automatic reclosure function is ready but not yet running. A trip command issued by a protective function configured as starter occurring within the action time will start the automatic reclosing function. If this time differs from the setting value of T-ACTION (address 7117), the automatic reclosure function will be blocked dynamically. The trip time of inverse tripping characteristics is considerably determined by the fault location or fault resistance. The action time prevents reclosing in case of far remote or high-resistance faults with long tripping time. Trip commands of protective functions which are not configured as starter do not affect the action time. Delay of Dead Time Start The dead time start can be delayed by pickup of the binary input message 2754 >79 DT St.Delay. The maximum time for this can be parameterized under 7118 T DEAD DELAY. The binary input message must be deactivated again within this time in order to start the dead time. The exact sequence is described in the functional description at margin heading "Delay of Dead Time Start". Number of Reclosing Attempts The number of reclosing attempts can be set separately for the "phase program" (address7136, # OF RECL. PH) and "ground program" (address 7135 # OF RECL. GND). The exact definition of the programs is described in the functional description at margin heading "Reclosing Programs". Close Command: Direct or via Control Address 7137 Cmd.via control can be set to either generate directly the close command via the automatic reclosing function (setting Cmd.via control = none) or have the closing initiated by the control function. If the automatic reclosure function is to be closed via the control function, the manual closing command has to be suppressed during an automatic reclose command. The example in the Section 2.2.11 Setting Notes of a MANUAL CLOSE for commands via the integrated control function has to be extended in this case (see Figure 2-94). The messages 2878 79 L-N Sequence and 2879 79 L-L Sequence indicate that the AR has been started and wants to carry out a reclosure after the dead time. The annunciations set the flipflop and suspend the manual signal until the AR has finished the reclosure attempts. The flipflop is reset via the ORcombination of the annunciations 2784 79 is NOT ready, 2785 79 DynBlock and 2862 79 Successful. Manual closing is initiated if a CLOSE command comes from the control function. 220 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 [cfc-logik-handein-awe-steuerung-140503-kn, 1, en_US] Figure 2-94 CFC logic for Manual Close with automatic reclosing via control The selection list for parameter 7137 is created dynamically depending on the allocated switchgear components. If one of the switchgear components is selected, usually the circuit breaker52Breaker, reclosure is accomplished via control. In this case, the automatic reclosure function does not create a close command but issues a close request. It is forwarded to the control which then takes over the switching. Thus, the properties defined for the switchgear component such as interlocking and command times apply. Hence, it is possible that the close command will not be carried out due to an applying interlocking condition. If this behavior is not desired, the auto-reclose function can also generate the close command 79 Close directly which must be allocated to the associated contact. The CFC chart as in Figure 2-94 is not needed in this case. Connection to the Internal Synchronism Check The auto-reclose function can interact with the internal synchronization function of the device. If this is desired as well as the Manual Close functionality, the CFC chart illustrated in Figure 2-94 is a definite prerequisite since the synchronization function always interacts with the control function. Additionally, one of the four synchronization groups must be selected via parameter 7138 Internal SYNC. The synchronization conditions for automatic reclosure are are thereby specified. In that case the selected synchronization group defines the switchgear component to be used (usually the circuit breaker 52Breaker). The defined switchgear component and the one specified at 7137 Cmd.via control must be identical. Synchronous reclosing via the close command 79 Close is not possible. If interaction with the internal synchronization is not desired, the CFC Chart, as in Figure 2-94, is not required and the parameter 7138 is set to none. Automatic Reclosure with External Synchronism Check Parameter 7139 External SYNC can be set to determine that the automatic reclosure function operates with external synchrocheck. An external synchronization is possible if the parameter is set to YES and the device is connected to the external synchronization check via indication 2865 79 Sync.Request and the binary input >Sync.release. Note: The automatic reclosure function cannot be connected to the internal and external synchrocheck at the same time ! Initiation and Blocking of Automatic Reclosure by Protective Elements (configuration) At addresses 7150 through 7164, and 7166 through 7174, reclosing can be started or blocked for various types of protection functions. Together they constitute the wiring between protection elements and auto- SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 221 Functions 2.15 Automatic Reclosing System 79 matic reclosing function. Each address designates a protection element or protection function together with its ANSI synonym, for example 50-2 for the high-set element 50-2 of the non-directional time overcurrent protection (address 7152). The setting options have the following meaning: * Starts 79 the protective element initiates the automatic reclosure via its trip command; No influence the protective element does not start the automatic reclosure, it may however be initiated by other functions; Stops 79 the protective element blocks the automatic reclosure, it cannot be started by other functions; a dynamic blocking is initiated. Dead Times (1st AR) Addresses 7127 and 7128 are used to determine the duration of the dead times of the 1st cycle. The time defined by this parameter is started when the circuit breaker opens (if auxiliary contacts are allocated) or when the pickup drops out following the trip command of a starter. Dead time before first automatic reclosure for reclosing program "Phase" is set in address 7127 DEADTIME 1: PH, for reclosing program "ground" in address 7128 DEADTIME 1: G. The exact definition of the programs is described in the functional description at margin heading "Reclosing Programs". The length of the dead time should relate to the type of application. With longer lines, they should be long enough to make sure that the fault arc disappears and that the air surrounding it is de-ionized and auto-reclosure can successfully take place (usually 0.9 s to 1.5 s). For lines supplied by more than one side, mostly system stability has priority. Since the de-energized line cannot transfer synchronizing energy, only short dead times are allowed. Standard values are 0.3 s to 0.6 s. In radial systems, longer dead times are allowed. Cyclic Control of Protective Functions via Automatic Reclosure The addresses 7200 to 7211, 7248, 7249, 7256 and 7257 allow the different protection functions to be controlled cyclically by the AR. This enables protection elements to be blocked selectively, set to operate instantaneously or according to the configured delay times. The following settings are available: The following options are available: * Set value T=T The protection element is delayed as configured, i.e. the automatic reclosing function does not effect this element; instant. T=0 The protection element becomes instantaneous if the automatic reclosing function is ready to perform the mentioned cycle; blocked T= The protection element is blocked if the auto-reclose function reaches the cycle defined in the parameter. The element picks up, however, time expiry of the element is blocked by this setting. Dead Times (2nd to 4th AR) If more than one reclosing cycle was set, you can now configure the individual reclosing settings for the 2nd to 4th cycle. The same options are available as for the first cycle. For the 2nd cycle: Adsress 7129 DEADTIME 2: PH Dead time for the 2nd reclosing attempt phase Asdress 7130 DEADTIME 2: G Dead time for the 2nd reclosing attempt ground Addresses 7212 to 7223, 7250, 7251, 7258, 7259 Cyclic control of the various protection functions by the 2nd reclosing attempt For the 3rd cycle: Address 7131 DEADTIME 3: PH Dead time for the 3rd reclosing attempt phase Address 7132 DEADTIME 3: G Dead time for the 3rd reclosing attempt ground Addresses 7224 to 7235, 7252, 7253, 7260, 7261 Cyclic control of the various protection functions by the 3rd reclosing attempt For the 4th cycle: Address 7133 222 DEADTIME 4: PH Dead time for the 4th reclosing attempt phase SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 Address 7134 DEADTIME 4: G Addresses 7236 to 7247, 7254, 7255, 7262, 7263 Dead time for the 4th reclosing attempt ground Cyclic control of the various protection functions by the 4th reclosing attempt Fifth to Ninth Reclosing Attempt If more than four cycles are configured, the dead times set for the fourth cycle also apply to the fifth to ninth cycle. Blocking Three-Phase Faults Regardless of which reclosing program is executed, automatic reclosing can be blocked for trips following three-phase faults (address 7165 3Pol.PICKUP BLK). The pickup of all three phases for a overcurrent element is the criterion required. Blocking of Automatic Rreclosure via Internal Control The automatic reclosure function can be blocked, if control commands are issued via the integrated control function of the device. The information must be routed via CFC (interlocking task-level) using the CMD_Information function block (see the following figure). [blockierung-der-wiedereinschaltautomatik-26-06-02-kn, 1, en_US] Figure 2-95 Blocking of the automatic reclose function using the internal control function Zone Sequencing / Fuse Saving Scheme At address 7140 ZONE SEQ.COORD., the zone sequencing feature can be turned ON or OFF. If multiple reclosing operations are performed and the zone sequencing function is deactivated, only those reclosing cycles are counted which the device has conducted after a trip command. If the zone sequencing function is switched on, an additional sequence counter also counts such automatic reclosures which (in radial systems) are carried out by relays connected on load side. This presupposes that the pickup of the 50-1/50N-1 elements drops out without a trip command being issued by a protection function starting the automatic reclosing function. The parameters at addresses 7200 to 7263 (see paragraphs below at "Start and Blocking of Automatic Reclosing by Protection Functions" and "Controlling Directional/Non-Directional Overcurrent Protection Elements via Cold Load Pickup") can thus be set to determine which protection elements are active or blocked during what dead time cycles (for multiple reclosing attempts carried out by relays on the load side). In the example shown in Figure "Zone sequencing with a fault occurring at Tap Line 5 and the busbar" (see Figure 2-93) in the functional description, the zone sequencing was applied in the bus relay. Furthermore, as from the second automatic reclosure, the 50-2 elements (also applicable to the 50-3 elements) must be blocked, i.e. address 7214 bef.2.Cy:50-2 must be set to blocked T=. The zone sequencing of the feeder relays is switched off but the 50-2 elements must also be blocked after the second reclosing attempt. Moreover, it must be ensured that the 50-2 elements start the automatic reclosing function: Set address 7152 50-2 to Starts 79. All settings of the 50-2 and 50-3 elements apply analogously to the 50N-2 and 50N-3 elements. Controlling Overcurrent Protection Stages via Cold Load Pickup The dynamic cold load pickup function provides a further alternative to control the protection via the automatic reclosing function (see also Section 2.4 Dynamic Cold Load Pickup). This function contains the parameter 1702 Start Condition. It determines the starting conditions for the increased setting values of current and time of the dynamic cold load pickup that must apply for directional and non-directional overcurrent protection. If address 1702 Start Condition = 79 ready, the overcurrent protection always employs the increased setting values if the automatic reclosing system is ready. The auto-reclosure function provides the signal 79 ready for controlling the cold load pickup. The signal 79 ready is always active if the auto-reclosing system SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 223 Functions 2.15 Automatic Reclosing System 79 is available, active, unblocked and ready for another cycle. Control via the cold load pickup function is not ARcycle- related. Since control via cold load pickup and cyclic control via auto-reclosing system can run simultaneously, the overcurrent protection must coordinate the input values of the two interfaces. In this context the cyclic autoreclosing control has the priority and thus overwrites the release of the cold load pickup function. If the protective elements are controlled via the automatic reclosure function, changing the control variables (e.g. by blocking) has no effect on elements that are already running. The elements in question are continued. Note Regarding Settings List for Automatic Reclosure Function The setting options of address 7137 Cmd.via control are generated dynamically according to the current configuration. 2.15.7 Settings Addr. Parameter Setting Options Default Setting Comments 7101 FCT 79 OFF ON OFF 79 Auto-Reclose Function 7103 BLOCK MC Dur. 0.50 .. 320.00 sec; 0 1.00 sec AR blocking duration after manual close 7105 TIME RESTRAINT 0.50 .. 320.00 sec 3.00 sec 79 Auto Reclosing reset time 7108 SAFETY 79 ready 0.01 .. 320.00 sec 0.50 sec Safety Time until 79 is ready 7113 CHECK CB? No check Chk each cycle No check Check circuit breaker before AR? 7114 T-Start MONITOR 0.01 .. 320.00 sec; 0.50 sec AR start-signal monitoring time 7115 CB TIME OUT 0.10 .. 320.00 sec 3.00 sec Circuit Breaker (CB) Supervision Time 7116 Max. DEAD EXT. 0.50 .. 1800.00 sec; 100.00 sec Maximum dead time extension 7117 T-ACTION 0.01 .. 320.00 sec; sec Action time 7118 T DEAD DELAY 0.0 .. 1800.0 sec; 1.0 sec Maximum Time Delay of DeadTime Start 7127 DEADTIME 1: PH 0.01 .. 320.00 sec 0.50 sec Dead Time 1: Phase Fault 7128 DEADTIME 1: G 0.01 .. 320.00 sec 0.50 sec Dead Time 1: Ground Fault 7129 DEADTIME 2: PH 0.01 .. 320.00 sec 0.50 sec Dead Time 2: Phase Fault 7130 DEADTIME 2: G 0.01 .. 320.00 sec 0.50 sec Dead Time 2: Ground Fault 7131 DEADTIME 3: PH 0.01 .. 320.00 sec 0.50 sec Dead Time 3: Phase Fault 7132 DEADTIME 3: G 0.01 .. 320.00 sec 0.50 sec Dead Time 3: Ground Fault 7133 DEADTIME 4: PH 0.01 .. 320.00 sec 0.50 sec Dead Time 4: Phase Fault 7134 DEADTIME 4: G 0.01 .. 320.00 sec 0.50 sec Dead Time 4: Ground Fault 7135 # OF RECL. GND 0 .. 9 1 Number of Reclosing Cycles Ground 7136 # OF RECL. PH 0 .. 9 1 Number of Reclosing Cycles Phase 7137 Cmd.via control (Einstellmoglichkeiten anwendungsabhangig) none Close command via control device 7138 Internal SYNC (Einstellmoglichkeiten anwendungsabhangig) none Internal 25 synchronisation 7139 External SYNC YES NO NO External 25 synchronisation 7140 ZONE SEQ.COORD. OFF ON OFF ZSC - Zone sequence coordination 224 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 Addr. Parameter Setting Options Default Setting Comments 7150 50-1 No influence Starts 79 Stops 79 No influence 50-1 7151 50N-1 No influence Starts 79 Stops 79 No influence 50N-1 7152 50-2 No influence Starts 79 Stops 79 No influence 50-2 7153 50N-2 No influence Starts 79 Stops 79 No influence 50N-2 7154 51 No influence Starts 79 Stops 79 No influence 51 7155 51N No influence Starts 79 Stops 79 No influence 51N 7156 67-1 No influence Starts 79 Stops 79 No influence 67-1 7157 67N-1 No influence Starts 79 Stops 79 No influence 67N-1 7158 67-2 No influence Starts 79 Stops 79 No influence 67-2 7159 67N-2 No influence Starts 79 Stops 79 No influence 67N-2 7160 67 TOC No influence Starts 79 Stops 79 No influence 67 TOC 7161 67N TOC No influence Starts 79 Stops 79 No influence 67N TOC 7162 sens Ground Flt No influence Starts 79 Stops 79 No influence (Sensitive) Ground Fault 7163 46 No influence Starts 79 Stops 79 No influence 46 7164 BINARY INPUT No influence Starts 79 Stops 79 No influence Binary Input 7165 3Pol.PICKUP BLK YES NO NO 3 Pole Pickup blocks 79 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 225 Functions 2.15 Automatic Reclosing System 79 Addr. Parameter Setting Options Default Setting Comments 7166 50-3 No influence Starts 79 Stops 79 No influence 50-3 7167 50N-3 No influence Starts 79 Stops 79 No influence 50N-3 7168 67-3 No influence Starts 79 Stops 79 No influence 67-3 7169 67N-3 No influence Starts 79 Stops 79 No influence 67N-3 7200 bef.1.Cy:50-1 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50-1 7201 bef.1.Cy:50N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50N-1 7202 bef.1.Cy:50-2 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50-2 7203 bef.1.Cy:50N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50N-2 7204 bef.1.Cy:51 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 51 7205 bef.1.Cy:51N Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 51N 7206 bef.1.Cy:67-1 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67-1 7207 bef.1.Cy:67N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67N-1 7208 bef.1.Cy:67-2 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67-2 7209 bef.1.Cy:67N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67N-2 7210 bef.1.Cy:67 TOC Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67 TOC 7211 bef.1.Cy:67NTOC Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67N TOC 226 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 Addr. Parameter Setting Options Default Setting Comments 7212 bef.2.Cy:50-1 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50-1 7213 bef.2.Cy:50N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50N-1 7214 bef.2.Cy:50-2 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50-2 7215 bef.2.Cy:50N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50N-2 7216 bef.2.Cy:51 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 51 7217 bef.2.Cy:51N Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 51N 7218 bef.2.Cy:67-1 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67-1 7219 bef.2.Cy:67N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67N-1 7220 bef.2.Cy:67-2 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67-2 7221 bef.2.Cy:67N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67N-2 7222 bef.2.Cy:67 TOC Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67 TOC 7223 bef.2.Cy:67NTOC Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67N TOC 7224 bef.3.Cy:50-1 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50-1 7225 bef.3.Cy:50N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50N-1 7226 bef.3.Cy:50-2 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50-2 7227 bef.3.Cy:50N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50N-2 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 227 Functions 2.15 Automatic Reclosing System 79 Addr. Parameter Setting Options Default Setting Comments 7228 bef.3.Cy:51 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 51 7229 bef.3.Cy:51N Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 51N 7230 bef.3.Cy:67-1 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67-1 7231 bef.3.Cy:67N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67N-1 7232 bef.3.Cy:67-2 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67-2 7233 bef.3.Cy:67N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67N-2 7234 bef.3.Cy:67 TOC Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67 TOC 7235 bef.3.Cy:67NTOC Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67N TOC 7236 bef.4.Cy:50-1 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50-1 7237 bef.4.Cy:50N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50N-1 7238 bef.4.Cy:50-2 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50-2 7239 bef.4.Cy:50N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50N-2 7240 bef.4.Cy:51 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 51 7241 bef.4.Cy:51N Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 51N 7242 bef.4.Cy:67-1 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67-1 7243 bef.4.Cy:67N-1 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N-1 228 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 Addr. Parameter Setting Options Default Setting Comments 7244 bef.4.Cy:67-2 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67-2 7245 bef.4.Cy:67N-2 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N-2 7246 bef.4.Cy:67 TOC Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67 TOC 7247 bef.4.Cy:67NTOC Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N TOC 7248 bef.1.Cy:50-3 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50-3 7249 bef.1.Cy:50N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50N-3 7250 bef.2.Cy:50-3 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50-3 7251 bef.2.Cy:50N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50N-3 7252 bef.3.Cy:50-3 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50-3 7253 bef.3.Cy:50N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50N-3 7254 bef.4.Cy:50-3 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50-3 7255 bef.4.Cy:50N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50N-3 7256 bef.1.Cy:67-3 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67-3 7257 bef.1.Cy:67N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: IE>>> directional 7258 bef.2.Cy:67-3 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67-3 7259 bef.2.Cy:67N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: IE>>> directional SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 229 Functions 2.15 Automatic Reclosing System 79 Addr. Parameter Setting Options Default Setting Comments 7260 bef.3.Cy:67-3 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67-3 7261 bef.3.Cy:67N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: IE>>> directional 7262 bef.4.Cy:67-3 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67-3 7263 bef.4.Cy:67N-3 Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N-3 2.15.8 Information List No. Information Type of Information Comments 127 79 ON/OFF IntSP 79 ON/OFF (via system port) 2701 >79 ON SP >79 ON 2702 >79 OFF SP >79 OFF 2703 >BLOCK 79 SP >BLOCK 79 2711 >79 Start SP >79 External start of internal A/R 2715 >Start 79 Gnd SP >Start 79 Ground program 2716 >Start 79 Ph SP >Start 79 Phase program 2722 >ZSC ON SP >Switch zone sequence coordination ON 2723 >ZSC OFF SP >Switch zone sequence coordination OFF 2730 >CB Ready SP >Circuit breaker READY for reclosing 2731 >Sync.release SP >79: Sync. release from ext. sync.-check 2753 79 DT delay ex. OUT 79: Max. Dead Time Start Delay expired 2754 >79 DT St.Delay SP >79: Dead Time Start Delay 2781 79 OFF OUT 79 Auto recloser is switched OFF 2782 79 ON IntSP 79 Auto recloser is switched ON 2784 79 is NOT ready OUT 79 Auto recloser is NOT ready 2785 79 DynBlock OUT 79 - Auto-reclose is dynamically BLOCKED 2788 79 T-CBreadyExp OUT 79: CB ready monitoring window expired 2801 79 in progress OUT 79 - in progress 2808 79 BLK: CB open OUT 79: CB open with no trip 2809 79 T-Start Exp OUT 79: Start-signal monitoring time expired 2810 79 TdeadMax Exp OUT 79: Maximum dead time expired 2823 79 no starter OUT 79: no starter configured 2824 79 no cycle OUT 79: no cycle configured 2827 79 BLK by trip OUT 79: blocking due to trip 2828 79 BLK:3ph p.u. OUT 79: blocking due to 3-phase pickup 2829 79 Tact expired OUT 79: action time expired before trip 2830 79 Max. No. Cyc OUT 79: max. no. of cycles exceeded 2844 79 1stCyc. run. OUT 79 1st cycle running 230 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.15 Automatic Reclosing System 79 No. Information Type of Information Comments 2845 79 2ndCyc. run. OUT 79 2nd cycle running 2846 79 3rdCyc. run. OUT 79 3rd cycle running 2847 79 4thCyc. run. OUT 79 4th or higher cycle running 2851 79 Close OUT 79 - Close command 2862 79 Successful OUT 79 - cycle successful 2863 79 Lockout OUT 79 - Lockout 2865 79 Sync.Request OUT 79: Synchro-check request 2878 79 L-N Sequence OUT 79-A/R single phase reclosing sequence 2879 79 L-L Sequence OUT 79-A/R multi-phase reclosing sequence 2883 ZSC active OUT Zone Sequencing is active 2884 ZSC ON OUT Zone sequence coordination switched ON 2885 ZSC OFF OUT Zone sequence coordination switched OFF 2889 79 1.CycZoneRel OUT 79 1st cycle zone extension release 2890 79 2.CycZoneRel OUT 79 2nd cycle zone extension release 2891 79 3.CycZoneRel OUT 79 3rd cycle zone extension release 2892 79 4.CycZoneRel OUT 79 4th cycle zone extension release 2899 79 CloseRequest OUT 79: Close request to Control Function SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 231 Functions 2.16 Fault Locator 2.16 Fault Locator The measurement of the distance to a short-circuit fault is a supplement to the protection functions. Power transmission within the system can be increased when the fault is located and cleared faster. 2.16.1 Functional Description General The fault locator is a stand-alone and independent function which uses the line and power system parameters set in other functions. In the event of a fault, it is addressed by the protection functions provided in the 7SJ80 device. The protected object can e.g. be an inhomogeneous line. For calculation purposes, the line can be divided into different sections, for example, a short cable followed by an overhead line. In such protected objects, you can configure each section individually. Without this information, the fault locator uses the general line data (see Section 2.1.6.2 Setting Notes). The fault locator also calculates double ground faults with different base points, reverse faults and faults that are located behind the configured sections. For faults that are not located within the configured sections, the fault locator uses the general line data. The fault locator can be triggered by the trip command of the non-directional or directional time overcurrent protection, or by each fault detection. In the latter case, fault location calculations is even possible if another protection relay cleared the fault. Additionally, the fault location can be initiated via a binary input. However, it is a prerequisite that pickup of the time overcurrent protection is performed at the same time (directional or nondirectional). Fault Location Determination The measurement principle of the fault locator is based on the calculation of impedances. Sampled value pairs of short-circuit current and short-circuit voltage are stored in a buffer (at a sampling rate of 1/16 cycle) shortly after the trip command. At that time, even with very fast circuit breakers, no errors in the measured values have occurred during the shutdown procedure. Measured value filtering and the number of impedance calculations are adjusted automatically to the number of stable measured value pairs in the determined data window. If no sufficient data windows with reliable values could be determined for fault location, message Flt.Loc.invalid is issued. The fault locator evaluates the short-circuit loops and uses the loops with the lowest fault impedance (see margin heading "Loop Selection"). Loop Selection Using the pickup of the time overcurrent protection (directional or non-directional), the valid measurement loops for the calculation of fault impedance are selected. The following table shows the assignment of the evaluated loops to the possible pickup scenarios of the protection elements. Fault Type Pickup by A B C x x x x x x 232 Signaled Loop N x x Measured Loop x x A A-N A-N B B-N B-N C C-N C-N x N A-N, B-N, C-N signaled loop x A-N A-N A-N x B-N B-N B-N x C-N C-N C-N A-B A-B A-B A-C A-C A-C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.16 Fault Locator Pickup by A B C x x Fault Type Signaled Loop N x x x Measured Loop B-C B-C B-C x A-B-N A-B, A-N, B-N signaled loop x x A-C-N C-A, A-N, B-N signaled loop x x x B-C-N B-C, B-N, C-N signaled loop x x x A-B-C A-B, B-C, C-A signaled loop x x x A-B-C-N A-B, B-C, C-A, A-N, B-N, C-N signaled loop x Output of Fault Location The following information is output as result of the fault location: * the short-circuit loop from which the fault reactance was determined, * * * the 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. the 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, Line Sections The line type is determined by the line section settings. If, for instance, the line includes a cable and an overhead line, two different sections must be configured. The system can distinguish between up to three different line types. When configuring this line data, please note that the different tabs for setting the line sections will only be displayed if more than one line section has been configured under the functional scope (address 181). The parameters for a line section are entered in the Setting tab . . 2.16.2 Setting Notes General The fault location is only enabled if address 180 was set to Enabled during configuration of the function extent. Under address 181 L-sections FL the number of line section must be selected, which is required for the accurate description of the line. If the number is set to 2 Sections or 3 Sections, further setting sheets appear in the Power System Data 2 in DIGSI. Default setting is 1 Section. Line Data To calculate the fault distance in kilometers or miles, the device needs the per distance reactance of the line in /kilometer or /mile. Furthermore, the line length in km or miles, the angle of the line impedance, and resistance and reactance ratios are required. These parameters have already been set in the Power System Data 2 for a maximum of 3 line sections (see Section 2.1.6.2 Setting Notes under "Ground Impedance Ratios" and "Reactance per Unit Length"). Initiation of Measurement Normally the fault location calculation is started when a directional or non-directional time overcurrent protection initiates a trip signal (address 8001 START = TRIP). However, it may also be initiated when pickup drops out (address 8001 START = Pickup), e.g. when another protection element clears the fault. Irrespective of this fact, calculation of the fault location can be triggered externally via a binary input. (FNo. 1106 >Start Flt. Loc) provided the device has picked up. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 233 Functions 2.16 Fault Locator 2.16.3 Settings Addr. Parameter Setting Options Default Setting Comments 8001 START Pickup TRIP Pickup Start fault locator with 2.16.4 Information List No. Information Type of Information Comments 1106 >Start Flt. Loc SP >Start Fault Locator 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 AG OUT Fault Locator Loop AG 1124 FL Loop BG OUT Fault Locator Loop BG 1125 FL Loop CG OUT Fault Locator Loop CG 1126 FL Loop AB OUT Fault Locator Loop AB 1127 FL Loop BC OUT Fault Locator Loop BC 1128 FL Loop CA OUT Fault Locator Loop CA 1132 Flt.Loc.invalid OUT Fault location invalid 234 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.17 Breaker Failure Protection 50BF 2.17 Breaker Failure Protection 50BF The breaker failure protection function monitors proper tripping of the relevant circuit breaker.. 2.17.1 Functional Description General If after a programmable time delay, the circuit breaker has not opened, breaker failure protection issues a trip signal to isolate the failure breaker by tripping other surrounding backup circuit breaker (see example in the figure below). [funktionsprinzip-svs-20061219, 1, en_US] Figure 2-96 Function principle of the breaker failure protection Initiation The breaker failure protection function can be initiated by two different sources: * Trip signals of internal protective functions of the 7SJ80, * external trip signals via binary inputs (>50BF ext SRC). For each of the two sources, a unique pickup message is generated, a unique time delay is initiated, and a unique trip signal is generated. The setting values of current threshold and delay time apply to both sources. Criteria There are two criteria for breaker failure detection: * Check whether the current flow has effectively disappeared after a tripping command was issued, * Evaluate the circuit breaker's auxiliary contacts. The criteria used to determine if the circuit breaker has operated are selectable and also depend on the protection function that initiated the breaker failure function. On tripping without fault current, e.g. via voltage protection, the current below the threshold 50BF PICKUP is not a reliable indication of the proper functioning of the circuit breaker. In such cases, pickup exclusively depends on the auxiliary contact criterion. In protection functions based on the measurement of currents (including all short-circuit protection functions), the current flow is a preferential criterion, i.e. it is given priority, as opposed to the auxiliary contacts. If current flows above the set threshold or thresholds (enabled w/ 3I0>) are detected, the breaker failure protection trips even if the auxiliary criterion indicates "Breaker Open". SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 235 Functions 2.17 Breaker Failure Protection 50BF Monitoring of the Current Flow Address 170 50BF can be set in such a way that either the current criterion can already be met by a single phase current (setting Enabled) or that another current is taken into consideration in order to check the plausibility (setting enabled w/ 3I0>), see Figure 2-97. The currents are filtered through numerical filters to evaluate only the fundamental harmonic. They are monitored and compared to the set threshold values. Besides the three phase currents, two additional currents are provided to enable a plausibility check. Separate threshold values can be used for this plausibility check if this is configured accordingly. To detect ground faults more quickly, the threshold value for the ground current can also be used for checking the plausibility of the phase currents. This function is activated via binary input >50BFactiv.3I0> (see Figure 2-97). The ground current IN (3*0) is preferably used as plausibility current. Via the parameters 613 you decide whether the measured (Ignd (measured)) or the calculated (3I0 (calcul.)) values are to be used. In case of system faults not involving ground currents, no increased ground currents/residual currents are flowing, and therefore the calculated triple negative sequence current 3*I22 or a second phase current is used as plausibility current. [7sj80-plausibilitaet-i-sv-20061218, 1, en_US] Figure 2-97 236 Monitoring of the current flow SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.17 Breaker Failure Protection 50BF Monitoring of the Circuit Breaker Auxiliary Contacts Evaluation of the circuit breaker's auxiliary contacts depends on the type of contacts, and how they are connected to the binary inputs: * * * * the auxiliary contacts for circuit breaker "open" (4602 >52-b) and "closed" (4601 >52-a) are configured, only the auxiliary contact for circuit breaker "open" is configured (4602 >52-b), only the auxiliary contact for circuit breaker "closed" is configured (4601 >52-a), none of the two auxiliary contacts is configured. Feedback information of the auxiliary status of the circuit breaker is evaluated, depending on the allocation of binary inputs and auxiliary contacts. After a trip command has been issued it is the aim to detect -- if possible -- by means of the feedback of the circuit breaker's auxiliary contacts whether the breaker is open or in intermediate position. If valid, this information can be used for a proper initiation of the breaker failure protection function. The logic diagram illustrates the monitoring of the circuit breaker's auxiliary contacts. [7sj80-erzeug-svs-int-sign, 1, en_US] Figure 2-98 Logic diagram for breaker failure protection, monitoring of the circuit-breaker auxiliary contacts Logic The entire breaker failure protection function may be turned on or off, or it can be blocked dynamically via binary inputs. If breaker failure protection is initiated, an alarm message is generated. With the initiation, two setable delay times are started. One delay time can be used to repeat the trip command to the local circuit breaker. The other is used to trip the higher-level circuit breaker. If criteria for a pickup are still met once the time delays have elapsed, the trip signals are issued successively If the criteria that led to the pickup are no longer met, after the time delays have elapsed, then the pickup will drop out and no trip signal is issued by the breaker failure protection function. To protect against nuisance tripping due to excessive contact bounce, a stabilization of the binary inputs for external trip signals takes place. This external signal must be present during the entire period of the delay times, otherwise the timer is reset and no tripping signal is issued. The following figure shows the logic diagram for the breaker failure protection function. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 237 Functions 2.17 Breaker Failure Protection 50BF [7sj62-64-svs-20081110, 1, en_US] Figure 2-99 Logic diagram of the breaker failure protection 2.17.2 Setting Notes General Breaker failure protection is only effective and accessible if address 170 50BF is set to Enabled or enabled w/ 3I0>. Setting Enabled considers the three phase currents for total current monitoring. Setting enabled w/ 3I0> additionally evaluates the ground current or the negative sequence system when only one phase current occurs. If this function is not required, then Disabled is set. The function can be set to ON or OFF under address 7001 FCT 50BF. 238 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.17 Breaker Failure Protection 50BF Criteria Address 7004 Chk BRK CONTACT establishes whether or not the breaker auxiliary contacts connected via binary inputs are to be used as a criterion for pickup. If this address is set to ON, then current criterion and/or the auxiliary contact criterion apply. This setting must be selected if the breaker failure protection is started by functions, which do not always have a certain criterion for detection of an open circuit breaker, e.g. voltage protection. Single-Element Breaker Failure Protection In single-element breaker failure protection, the adjacent circuit breakers, i.e. the breakers of the busbar or the busbar section affected, and where applicable also the breaker at the remote end, are tripped after the time delay TRIP-Timer (address 7005) has elapsed. The time 50BF-2 Delay (address 7008) is in this case set to infinite because it is not needed. The time delay to be set should be based on the maximum circuit breaker operating time plus the dropout time of the current flow monitoring element plus a safety margin which takes into consideration the tolerance of the time delay. In case of an external start, the set time delay is reduced automatically by 10 ms in order to compensate the residual time of the external start. Figure 2-100 illustrates the time sequences in an example. [abl-bei-norm-fehlerkllaer-u-bei-lsvs-20061220, 1, en_US] Figure 2-100 Time sequence example for normal clearance of a fault, and for circuit breaker failure with single-element breaker failure protection Two-Element Breaker Failure Protection In two-element breaker failure protection, the trip command is output again to the local feeder circuit breaker, normally to a separate set of trip coils of the feeder breaker, after the time delay TRIP-Timer (address 7005) has elapsed. If the circuit breaker does not respond to the repeated trip, the adjacent circuit breakers, i.e. the breakers of the busbar or the busbar section affected, and where applicable also the breaker at the remote end, are tripped after the time delay 50BF-2 Delay (Adresse 7008) has elapsed and the fault still exists. The time delays to be set should be based on the maximum circuit breaker operating time plus the dropout time of the current flow monitoring element plus a safety margin which takes into consideration the tolerance of the time delay. In case of an external start, the set time delay is reduced automatically by 10 ms in order to compensate the residual time of the external start. Figure 2-101 illustrates the time sequences in an example. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 239 Functions 2.17 Breaker Failure Protection 50BF [abl-bei-norm-fehlerkllaer-u-bei-lsvs-2stufig-090116, 1, en_US] Figure 2-101 Time sequence example for normal clearance of a fault, and for circuit breaker failure with two-element breaker failure protection Pickup Values The pickup value of the current flow monitoring is set under address 7006 50BF PICKUP, and the pickup value of the ground current monitoring under address 7007 50BF PICKUP IE>. The threshold values must be set at a level below the minimum fault current for which the total current monitoring must operate. A setting of 10 % below the minimum fault current for which breaker failure protection must operate is recommended. The pickup value should not be set too low since otherwise there is a risk that transients in the current transformer secondary circuit may lead to extended dropout times if extremely high currents are switched off. Via binary input 1404 >50BFactiv.3I0> you can activate the threshold value 50BF PICKUP IE> also for checking the plausibility of the phase currents. 2.17.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter 7001 Setting Options Default Setting Comments FCT 50BF OFF ON OFF 50BF Breaker Failure Protection 7004 Chk BRK CONTACT OFF ON OFF Check Breaker contacts 7005 TRIP-Timer 0.06 .. 60.00 sec; 0.25 sec TRIP-Timer 7006 50BF PICKUP 1A 0.05 .. 20.00 A 0.10 A 5A 0.25 .. 100.00 A 0.50 A 50BF Pickup current threshold 1A 0.05 .. 20.00 A 0.10 A 5A 0.25 .. 100.00 A 0.50 A 0.06 .. 60.00 sec; 0.50 sec 7007 7008 240 50BF PICKUP IE> 50BF-2 Delay C 50BF Pickup earth current threshold Delay of 2nd stage for busbar trip SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.17 Breaker Failure Protection 50BF 2.17.4 Information List No. Information Type of Information Comments 1403 >BLOCK 50BF SP >BLOCK 50BF 1404 >50BFactiv.3I0> SP >50BF Activate 3I0> threshold 1431 >50BF ext SRC SP >50BF initiated externally 1451 50BF OFF OUT 50BF is switched OFF 1452 50BF BLOCK OUT 50BF is BLOCKED 1453 50BF ACTIVE OUT 50BF is ACTIVE 1456 50BF int Pickup OUT 50BF (internal) PICKUP 1457 50BF ext Pickup OUT 50BF (external) PICKUP 1471 50BF TRIP OUT 50BF TRIP 1480 50BF int TRIP OUT 50BF (internal) TRIP 1481 50BF ext TRIP OUT 50BF (external) TRIP 1494 50BF TRIP 2 OUT 50BF TRIP 2 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 241 Functions 2.18 Flexible Protection Functions 2.18 Flexible Protection Functions The flexible protection function is applicable for a variety of protection principles. The user can create up to 20 flexible protection functions and configure them according to their function. Each function can be used either as an autonomous protection function, as an additional protective element of an existing protection function or as a universal logic, e.g. for monitoring tasks. 2.18.1 Functional Description General The function is a combination of a standard protection logic and a characteristic (measured quantity or derived quantity) that is adjustable via parameters. The characteristics listed in table 2-20 and the derived protection functions are available. Please note that with voltage connection type Vab, Vbc or Vab, Vbc, VSyn or Vab, Vbc, Vx (address 213 VT Connect. 3ph) the power values are only available if you have symmetrical voltage conditions within the network and address 207 Vol. Symmetry is set to YES (Power System Data 1). Table 2-15 Possible Protection Functions Characteristic Characteristic / Measured Quantity Group Protective Function Current Frequency Voltage Power 242 ANSI-No. Mode of Operation 3-phase 1-phase RMS value of fundamental component Time overcurrent protection 50, 50G X X rms True RMS (r.m.s. value) Time overcurrent protection Thermal overload protection 50, 50G X X 30 Zero sequence system Time overcurrent protection, ground 50N X 1 Positive-sequence component 2 Negative-sequence component 2/1 Positive/negative sequence component ratio f Frequency Frequency protection 81U/O df/dt Frequency change Frequency change protection 81R V RMS value of fundamental component Voltage protection Displacement voltage 27, 59, 59G, 59N, 59NC X X Vrms True RMS (r.m.s. value) Voltage protection Displacement voltage 27, 59, 59G, 59N, 59NC X X 3V0 Zero sequence system Displacement voltage 59N X V1 Positive-sequence component Voltage protection 27, 59 X V2 Negative-sequence component Voltage asymmetry 47 X dV/dt Voltage change Voltage change protection P Real power Reverse power protection Power protection 32R, 32, 37 X X Q Reactive power Power protection 32 X X cos Power factor Power factor 55 X X X Negative sequence protec- 46 tion X X without phase reference X SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.18 Flexible Protection Functions Characteristic Characteristic / Measured Quantity Group Protective Function Binary input Direct coupling - Binary input ANSI-No. Mode of Operation 3-phase 1-phase without phase reference Section 2.19 Reverse-Power Protection Application with Flexible Protection Function gives an application example of the function "reverse power protection". The maximum 20 configurable protection functions operate independently of each other. The following description concerns one function; it can be applied accordingly to all other flexible functions. The logic diagram Figure 2-102 illustrates the description. Functional Logic The function can be switched OFF and ON or, it can be set to Alarm Only. In this status, a pickup condition will neither initiate fault recording nor start the trip time delay. Tripping is thus not possible. Changing the Power System Data 1 after flexible functions have been configured may cause these functions to be set incorrectly. Message (FNo.235.2128 $00 inval.set) reports this condition. The function is inactive in this case and function's setting has to be modified. Blocking Functions The function can be blocked via binary input (FNo. 235.2110 >BLOCK $00) or via local operating terminal ("Control"->"Tagging"->"Set"). Blocking will reset the function's entire measurement logic as well as all running times and indications. Blocking via the local operating terminal may be useful if the function is in a status of permanent pickup which does not allow the function to be reset. In context with voltage-based characteristics, the function can be blocked if one of the measuring voltages fails. Recognition of this status is either accomplished by the relay's internal Fuse-Failure-Monitor" (FNo. 170 VT FuseFail; see section 2.11.1 Measurement Supervision) or via auxiliary contacts of the voltage transformer CB (FNo. 6509 >FAIL:FEEDER VT and FNo. 6510 >FAIL: BUS VT). This blocking mechanism can be enabled or disabled in the according parameters. The associated parameter BLK.by Vol.Loss is only available if the characteristic is based on a voltage measurement. When using the flexible function for power protection or power monitoring, it will be blocked if currents fall below 0.03 * Nom. Parameter BLK f out of r allows you to specify whether the protection function is blocked if the measured power frequency is outside the operating range of the function (25 Hz to 70 Hz). Operating Mode, Measured Quantity, Measurement Method The flexible function can be tailored to assume a specific protective function for a concrete application in parameters OPERRAT. MODE, MEAS. QUANTITY, MEAS. METHOD and PICKUP WITH. Parameter OPERRAT. MODE can be set to specify whether the function works 3-phase, 1-phase oder no reference, i.e. without a fixed phase reference. The three-phase method evaluates all three phases in parallel. This implies that threshold evaluation, pickup indications and trip time delay are accomplished selectively for each phase and parallel to each other. This may be for example the typical operating principle of a three-phase time overcurrent protection. When operating single-phase, the function employs either a phase's measured quantity, which must be stated explicitly, (e.g. evaluating only the current in phase Ib), or the measured ground current In or the measured displacement voltage Vn. If the characteristic relates to the frequency or if external trip commands are used, the operating principle is without (fixed) phase reference. Additional parameters can be set to specify the used MEAS. QUANTITY and the MEAS. METHOD. The MEAS. METHOD determines for current and voltage measured values whether the function uses the RMS value of the fundamental component or the normal RMS value (true RMS) that evaluates also harmonics. All other characteristics use always the rms value of the fundamental component. Parameter PICKUP WITH moreover specifies whether the function picks up on exceeding the threshold (>-element) or on falling below the threshold (<-element). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 243 Functions 2.18 Flexible Protection Functions Characteristic Curve The function's characteristic curve is always "definite time"; this means that the time delay is not affected by the measured quantity. Function Logic The following figure shows the logic diagram of a three-phase function. If the function operates on one phase or without phase reference, phase selectivity and phase-specific indications are not relevant. [logik-flexstz-100504-st, 1, en_US] Figure 2-102 244 Logic diagram of the flexible protection functions SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.18 Flexible Protection Functions The parameters can be set to monitor either exceeding or dropping below of the threshold. The configurable pickup time delay will be started once the threshold (>-element) has been exceeded. When the time delay has elapsed and the threshold is still violated, the pickup of the phase (e.g. no. 235.2122 $00 pickup A)and of the function (no. 235.2121 $00 picked up) is reported. If the pickup delay is set to zero, the pickup will occur simultaneously with the detection of the threshold violation. If the function is enabled, the pickup will start the trip time delay and the fault log. This is not the case if set to "Alarm only". If the threshold violation persists after the trip time delay has elapsed, the trip will be initiated upon its expiration (no. 235.2126 $00 TRIP). The timeout is reported via (no. 235.2125 $00 Time Out). Expiry of the trip time delay can be blocked via binary input (no. 235.2113 >$00 BLK.TDly). The time delay will not be started as long as the binary input is active; a trip can thus be initiated. The time delay is started after the binary input has dropped out and the pickup is still present. It is also possible to bypass the expiration of the time delay by activating binary input (no. 235.2111 >$00 instant.). The trip will be launched immediately when the pickup is present and the binary input has been activated. The trip command can be blocked via binary inputs (no. 235.2115 >$00 BL.TripA) and (no. 235.2114 >$00 BLK.TRIP). The phase-selective blocking of the trip command is required for interaction with the inrush restraint (see "Interaction with other functions"). The function's dropout ratio can be set. If the threshold (>-element) is undershot after the pickup, the dropout time delay will be started. The pickup is maintained during that time, a started trip delay time continues to count down. If the trip time delay has elapsed while the dropout time delay is still during, the trip command will only be given if the current threshold is exceeded. The element will only drop out when the dropout time delay has elapsed. If the time is set to zero, the dropout will be initiated immediately once the threshold is undershot. External Trip Commands The logic diagram does not explicitly depict the external trip commands since their functionality is analogous. If the binary input is activated for external trip commands (no. 235.2112 >$00 Dir.TRIP), it will be logically treated as threshold overshooting, i.e. once it has been activated, the pickup time delay is started. If the pickup time delay is set to zero, the pickup condition will be reported immediately starting the trip time delay. Otherwise, the logic is the same as depicted in Figure 2-102. Interaction with Other Functions The flexible protection functions interact with a number of other functions such as the * Breaker failure protection: The breaker failure protection is started automatically if the function initiates a trip. The trip will, however, only take place if the current criterion is met at this time, i.e. the set minimum current threshold 7006 50BF PICKUP (Power System Data 1) has been exceeded. * Automatic reclosing (AR): The AR cannot be started directly. In order to interact with the AR, the trip command of the flexible function needs be linked in CFC to binary input no. 2716 >Start 79 Ph or no. 2715 >Start 79 Gnd. Using an operating time requires the pickup of the flexible function to be linked to binary input no. 2711 >79 Start. * * Fuse-Failure-Monitor (see description at "Blocking Functions"). Inrush restraint: Direct interaction with the inrush restraint is not possible. In order to block a flexible function by the inrush restraint, the blocking must be carried out in CFC. The flexible function provides three binary inputs for blocking trip commands selectively for each phase (no. 235.2115 to 235.2117). They have to be linked with the phase-selective indications for detecting the inrush (no. 1840 to 1842). Activating a crossblock function requires the phase-selective inrush indications to be logically combined with the binary input for blocking the function trip command (no. 235.2114 >$00 BLK.TRIP). The flexible function also needs to be delayed by at least 20 ms to make sure that the inrush restraint picks up before the flexible function. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 245 Functions 2.18 Flexible Protection Functions * Entire relay logic: The pickup signal of the flexible function is added to the general device pickup, the trip signal is added to the general device trip (see also Section 2.22 Function Logic). All functions associated with general device pickup and tripping are thus also applied to the flexible function. After the picked up element has dropped out, the trip signals of the flexible protection functions are held up at least for the specified minimum trip command time 210 TMin TRIP CMD. 2.18.2 Setting Notes The setting of the functional scope determines the number of flexible protection functions to be used (see Section 2.1.1 Functional Scope). If a flexible function in the functional scope is disabled (by removing the checkmark), this will result in losing all settings and configurations of this function or its settings will be reset to their default settings. General In the DIGSI setting dialog "General", parameter In the DIGSI setting dialog General", parameter FLEXIBLE FUNC. can be set to OFF, ON or Alarm Only. If the function is enabled in operational mode Alarm Only, no faults are recorded, no Effective"-indication is generated, no trip command issued and neither will the circuitbreaker protection be affected. Therefore, this operational mode is preferred when a flexible function is not required to operate as a protection function. Furthermore, the OPERRAT. MODE can be configured. Three-phase - functions evaluate the three-phase measuring system, i.e. all three phases are processed simultaneously. A typical example is the three-phase operating time overcurrent protection. Single-phase - functions evaluate only the individual measuring value. This can be an individual phase value (e.g. VB) or Vx or a ground variable (VN, N or N2 ). Setting no reference determines the evaluation of measured variables irrespective of a single or threephase connection of current and voltage. Table 2-20 provides an overview regarding which variables can be used in which mode of operation. Parameter BLK f out of r allows you to specify whether the protection function is blocked if the measured power frequency is outside the operating range of the function (25 Hz to 70 Hz). SIEMENS recommends using the default setting (YES). A release beyond the normal operating range is only required for special applications. Measured Variable In the setting dialog "Measured Variable" the measured variables to be evaluated by the flexible protection functions can be selected, which may be a calculated or a directly measured variable. The setting options that can be selected here are dependent on the mode of measured-value processing as predefined in parameter OPERRAT. MODE (see the following table). Table 2-16 Parameter OPERRAT. MODE Parameter MEAS. QUANTITY Setting Setting Options Current Voltage P forward P reverse Q forward Q reverse Power factor Single-phase, Three-phase 3-phase 246 Parameter "Operating Mode" and "Measured Quantity" dV/dt rising dV/dt falling SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.18 Flexible Protection Functions Without Reference Frequency df/dt rising df/dt falling Binary Input Please note that with voltage connection type Vab, Vbc or Vab, Vbc, VSyn or Vab, Vbc, Vx (address 213 VT Connect. 3ph) the power values are only available if you have symmetrical voltage conditions within the network and address 207 Vol. Symmetry is set to YES (Power System Data 1). Measurement Procedures The measurement procedures as set out in the following table can be configured for the measured variables current, voltage and power. The dependencies of the available measurement procedures of configurable modes of operation and the measured variable are also indicated. Table 2-17 Parameter in the Setting Dialog "Measurement Procedure", Mode of Operation 3-phase Parameter OPERRAT. MODE = 3-phase Parameter MEAS. QUANTITY = Current or Voltage Parameter MEAS. METHOD Fundamental Only the fundamental harmonic is evaluated, higher harmonics are suppressed. This is the standard measurement procedure of the protection functions. Important: The voltage threshold value is always parameterized as phase-to-phase voltage. If parameter VOLTAGE SYSTEM is selected as phase-to-ground, the voltage threshold will be devided by 3. True RMS The "true" RMS value is determined, i.e. higher harmonics are evaluated. This procedure is applied, for example, if an overload protection element must be realized on the basis of a current measurement, as the higher harmonics contribute to thermal heating. Important: The voltage threshold value is always parameterized as phase-to-phase voltage. If parameter VOLTAGE SYSTEM is selected as phase-to-ground, the voltage threshold will be devided by 3. Positive seq., In order to realize certain applications, the positive sequence system or negative sequence system can be configured as measurement procedure. Examples are: - I2 (tripping monitoring system) - U2 (voltage asymmetry) Via the selection zero sequence system, additional zero sequence current or zero sequence voltage functions can be realized that operate independent of the ground variables IN and VN, which are measured directly via transformers. Negative seq., Zero sequence Important: The voltage threshold is always parameterized according to the definition of the balanced components independently of parameter VOLTAGE SYSTEM. Parameter MEAS. QUANTITY = Current Parameter MEAS. METHOD Ratio I2/I1 The ratio of the negative-sequence current to the positive-sequence current is evaluated. Please note that the function only operates if2 or 1 has exceeded the threshold value 0.1 * N. Parameter MEAS. QUANTITY = Voltage Parameter VOLTAGE SYSTEM SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 247 Functions 2.18 Flexible Protection Functions Parameter OPERRAT. MODE = 3-phase Phase-Phase Phase-Ground If you have configured address 213 VT Connect. 3ph to Van, Vbn, Vcn or Vab, Vbc, VGnd, you can select whether a threephase voltage function will evaluate the phase-to-ground voltage or the phase-to-phase voltages. When selecting phase-to-phase, these variables are derived from the phase-to-ground voltages. The selection is, for example, important for single-pole faults. If the faulty voltage drops to zero, the affected phase-to-ground voltage is thus zero, and the respective phase-to-phase voltages drop to the variable of a phase-to-ground voltage. With phase-to-phase voltage connection the parameter is hidden. NOTE i With regard to the phase-selective pickup messages, a special behavior is observed in the three-phase voltage protection with phase-to-phase variables, because the phase-selective pickup message "Flx01 Pickup Lx" is allocated to the respective measured-value channel "Lx". Single-phase faults: If, for example, voltage VA drops to such degree that voltages VAB and VA exceed their threshold values, the device indicates pickups "Flx01 Pickup A" and "Flx01 Pickup C", because the undershooting was detected in the first and third measured-value channel. Two-phase faults: If, for example, voltage VAB drops to such degree that its threshold value is reached, the device then indicates pickup "Flx01 Pickup A", because the undershooting was detected in the first measured-value channel. Table 2-18 Parameter in the Setting Dialog "Measurement Procedure", Mode of Operation 1-phase Parameter OPERRAT. MODE = 1-phase Parameter MEAS. QUANTITY = Current or Voltage Parameter MEAS. METHOD Fundamental Only the fundamental harmonic is evaluated, higher harmonics are suppressed. This is the standard measurement procedure of the protection functions. True RMS The "True" RMS value is determined, i.e. higher harmonics are evaluated. This procedure is applied, for example, if an overload protection element must be realized on the basis of a current measurement, as the higher harmonics contribute to thermal heating. Parameter MEAS. QUANTITY = Current Parameter CURRENT Ia Ib Ic In In sensitive In2 It is determined which current-measuring channel must be evaluated by the function. Depending on the device version, either IN (normal-sensitive ground current input), INS (sensitive ground current input) or IN2 (second ground current connected to the device) can be selected. If parameter 251 is set to A,G2,C,G; G2->B, the setting N refers to the current at the second current (N2). The setting NS refers to the sensitive ground current at the fourth current input. If parameter 251 is set to A,G2,C,G; G->B, the setting N2 refers to the current at the second current (N2). The setting NS or NS refers to the sensitive or highly sensitive ground current at the fourth current input. Parameter MEAS. QUANTITY = Voltage Parameter VOLTAGE 248 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.18 Flexible Protection Functions Parameter OPERRAT. MODE = 1-phase It is determined which voltage-measuring channel must be evaluated by the function. When selecting phase-to-phase voltage, the threshold value must be set as a phase-tophase value, when selecting a phase-to-ground variable as phase-toground voltage. The extent of the setting texts depends on the connection of the voltage transformer (see address 213VT Connect. 3ph). Va-n Vb-n Vc-n Va-b Vb-c Vc-a Vn Vx Parameter MEAS. QUANTITY = P forward or P reverse or Q forward or Q reverse Parameter POWER It is determined which power-measuring channel (current and voltage) must be evaluated by the function. With phase-tophase voltage connections the parameter is hidden (see address 213 VT Connect. 3ph). Ia Va-n Ib Vb-n Ic Vc-n i When selecting Vab, Vbc, VGnd, the phase-to-ground voltages will be calculated if "phase-to-ground" is configured. When selecting "phase-to-phase", the connected phaseto-phase voltages are used and VCA is calculated from VAB and VBC. NOTE Warning! If the 3-phase voltage connection is established at a motor or generator feeder and the Ux input is operated at the busbar or at another voltage measuring point other than the feeder, you must select "True RMS" as the measurement procedure. Otherwise, there is a risk of overfunction or underfunction in a situation where the feeder voltage and the Ux voltage exhibit significantly different frequencies. i NOTE If you have selected Vph-g, VSyn in VT Connect. 3ph, the connected phase-to-Ground voltage can be processed. If you select VOLTAGE as measured quantity, this connected voltage is used automatically. The forward direction of power (P forward, Q reverse) is the direction of the line. Parameter (1108 P,Q sign) for sign inversion of the power display in the operating measured values is ignored by the flexible functions. Via parameter PICKUP WITH it is determined whether the function must be triggered on exceeding or undershooting of the set threshold value. Settings The pickup thresholds, time delays and dropout ratios of the flexible protection function are set in the "Settings" dialog box in DIGSI. The pickup threshold of the function is configured via parameter P.U. THRESHOLD. The OFF-command time delay is set via parameter T TRIP DELAY. Both setting values must be selected according to the required application. The pickup can be delayed via parameter T PICKUP DELAY. This parameter is usually set to zero (default setting) in protection applications, because a protection function should pick up as quickly as possible. A setting deviating from zero may be appropriate if a trip log is not desired to be started upon each short-term exceeding of the pickup threshold, for example, with power protection or when a function is not used as a protection, but as a monitoring function. When setting the power threshold values, it is important to take into consideration that a minimum current of 0.03 N is required for power calculation. The power calculation is blocked for lower currents. The dropout of pickup can be delayed via parameter T DROPOUT DELAY. This setting is also set to zero by default (standard setting) A setting deviating from zero may be required if the device is utilized together with electro-magnetic devices with considerably longer dropout ratios than the digital protection device (see SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 249 Functions 2.18 Flexible Protection Functions Section 2.2 for more information). When utilizing the dropout time delay, it is recommended to set it to a shorter time than the OFF-command time delay in order to avoid both times to "race". The dropout ratio of the function can be selected in parameter DROPOUT RATIO. The standard dropout ratio of protection functions is 0.95 (default setting). If the function is used as power protection, a dropout ratio of at least 0.9 should be set. The same applies to the utilization of the symmetrical components of current and voltage. If the dropout ratio is decreased, it would be sensible to test the pickup of the function regarding possible "chatter". The dropout difference of the frequency elements is set under parameter DO differential. Usually, the default setting of 0.02 Hz can be retained. A higher dropout difference should be set in weak systems with larger, short-term frequency fluctuations to avoid chattering of the message. A fixed dropout difference of 0.1 Hz/s is used for the frequency change (df/dt) measurand. The same applies to the voltage change (dU/dt) measurand. The permanent dropout difference here is 3 V/s. Parameter BLK.by Vol.Loss determines whether a function whose measured variable is based on a voltage measurement (measured quantities voltage, P forward, P reverse, Q forward, Q reverse and power factor), should be blocked in case of a measured voltage failure (set to YES) or not (set to NO). Renaming Messages, Checking Configurations After parameterization of a flexible function, the following steps should be noted: * Open matrix in DIGSI * * Rename the neutral message texts in accordance with the application. Check configurations on contacts and in operation and fault buffer, or set them according to the requirements. Further Information The following instruction should be noted: * As the power factor does not differentiate between capacitive and inductive, the sign of the reactive power may be used with CFC-help as an additional criterion. 2.18.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 0 FLEXIBLE FUNC. OFF ON Alarm Only OFF Flexible Function 0 OPERRAT. MODE 3-phase 1-phase no reference 3-phase Mode of Operation 0 BLK f out of r YES NO YES Block while Freq. is out of range 250 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.18 Flexible Protection Functions Addr. Parameter 0 Setting Options Default Setting Comments MEAS. QUANTITY Please select Current Voltage P forward P reverse Q forward Q reverse Power factor dV/dt rising dV/dt falling Frequency df/dt rising df/dt falling Binray Input Please select Selection of Measured Quantity 0 MEAS. METHOD Fundamental True RMS Positive seq. Negative seq. Zero sequence Ratio I2/I1 Fundamental Selection of Measurement Method 0 PICKUP WITH Exceeding Dropping below Exceeding Pickup with 0 CURRENT Ia Ib Ic In In sensitive In2 Ia Current 0 VOLTAGE Please select Va-n Vb-n Vc-n Va-b Vb-c Vc-a Vn Vx Please select Voltage 0 POWER Ia Va-n Ib Vb-n Ic Vc-n Ia Va-n Power 0 VOLTAGE SYSTEM Phase-Phase Phase-Ground Phase-Phase Voltage System 0 P.U. THRESHOLD 0 P.U. THRESHOLD 0 0 P.U. THRESHOLD C 0.05 .. 40.00 A 2.00 A Pickup Threshold 1A 0.05 .. 40.00 A 2.00 A Pickup Threshold 5A 0.25 .. 200.00 A 10.00 A 1A 0.001 .. 1.500 A 0.100 A 5A 0.005 .. 7.500 A 0.500 A 2.0 .. 260.0 V 110.0 V P.U. THRESHOLD SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Pickup Threshold Pickup Threshold 251 Functions 2.18 Flexible Protection Functions Addr. Parameter 0 0 Setting Options Default Setting Comments P.U. THRESHOLD 2.0 .. 200.0 V 110.0 V Pickup Threshold P.U. THRESHOLD 2.0 .. 260.0 V 110.0 V Pickup Threshold 0 P.U. THRESHOLD 40.00 .. 60.00 Hz 51.00 Hz Pickup Threshold 0 P.U. THRESHOLD 50.00 .. 70.00 Hz 61.00 Hz Pickup Threshold 0 P.U. THRESHOLD 0.10 .. 20.00 Hz/s 5.00 Hz/s Pickup Threshold 0 P.U. THRESHOLD 1A 2.0 .. 10000.0 W 200.0 W Pickup Threshold 5A 10.0 .. 50000.0 W 1000.0 W 1A 2.0 .. 10000.0 VAR 200.0 VAR 5A 10.0 .. 50000.0 VAR 1000.0 VAR 0 P.U. THRESHOLD C Pickup Threshold 0 P.U. THRESHOLD -0.99 .. 0.99 0.50 Pickup Threshold 0 P.U. THRESHOLD 15 .. 100 % 20 % Pickup Threshold 0 P.U. THRESHOLD 4 .. 100 V/s 60 V/s Pickup Threshold 0 T TRIP DELAY 0.00 .. 3600.00 sec 1.00 sec Trip Time Delay 0A T PICKUP DELAY 0.00 .. 60.00 sec 0.00 sec Pickup Time Delay 0 T PICKUP DELAY 0.00 .. 28800.00 sec 0.00 sec Pickup Time Delay 0A T DROPOUT DELAY 0.00 .. 60.00 sec 0.00 sec Dropout Time Delay 0A BLK.by Vol.Loss NO YES YES Block in case of Meas.Voltage Loss 0A DROPOUT RATIO 0.70 .. 0.99 0.95 Dropout Ratio 0A DROPOUT RATIO 1.01 .. 3.00 1.05 Dropout Ratio 0 DO differential 0.02 .. 1.00 Hz 0.03 Hz Dropout differential 2.18.4 Information List Type of Information Comments 235.2110 >BLOCK $00 SP >BLOCK Function $00 235.2111 >$00 instant. SP >Function $00 instantaneous TRIP 235.2112 >$00 Dir.TRIP SP >Function $00 Direct TRIP 235.2113 >$00 BLK.TDly SP >Function $00 BLOCK TRIP Time Delay 235.2114 >$00 BLK.TRIP SP >Function $00 BLOCK TRIP 235.2115 >$00 BL.TripA SP >Function $00 BLOCK TRIP Phase A 235.2116 >$00 BL.TripB SP >Function $00 BLOCK TRIP Phase B 235.2117 >$00 BL.TripC SP >Function $00 BLOCK TRIP Phase C 235.2118 $00 BLOCKED OUT Function $00 is BLOCKED 235.2119 $00 OFF OUT Function $00 is switched OFF 235.2120 $00 ACTIVE OUT Function $00 is ACTIVE 235.2121 $00 picked up OUT Function $00 picked up 235.2122 $00 pickup A OUT Function $00 Pickup Phase A 235.2123 $00 pickup B OUT Function $00 Pickup Phase B 235.2124 $00 pickup C OUT Function $00 Pickup Phase C 235.2125 $00 Time Out OUT Function $00 TRIP Delay Time Out 235.2126 $00 TRIP OUT Function $00 TRIP 235.2128 $00 inval.set OUT Function $00 has invalid settings 236.2127 BLK. Flex.Fct. IntSP BLOCK Flexible Function No. 252 Information SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function 2.19 Reverse-Power Protection Application with Flexible Protection Function 2.19.1 Functional Description General General By means of the flexible protection functions a single-element or multi-element reverse power protection can be realized. Each reverse power element can be operated in single-phase or three-phase. Depending on the chosen option, the elements can evaluate active power forward, active power reverse, reactive power forward or reactive power reverse as measured value. The pickup by the protection elements can occur on exceeding or undershooting of the threshold. Possible applications for reverse power protection are set out in Table 2-19. Table 2-19 Overview of reverse power protection applications Type of Evaluation P Q Direction Overshooting Undershooting forward Monitoring of the forward power limits of operational equipment Detection of idling motors reverse Protection of a local industrial network against reversed feeding into the energy supply network Detection of reversed feeding by motors forward Monitoring of the reactive power limits of operational equipment (transformers, lines) Connection of a capacitor bank for reactive power compensation reverse Monitoring of the reactive power limits of operational equipment (transformers, lines) Connection of a capacitor bank The following example depicts a typical application where the flexible function acts as reverse power protection. Disconnection Facility The following fugure gives an example of an industrial control system with internal supply by the illustrated generator. All illustrated lines and the busbar are indicated in three-phase (excluding the ground connections and the connection to the voltage measurement at the generator). Both feeders 1 and 2 supply the consumers of the customer. Usually the industrial customer receives his current from the energy supplier. The generator runs in synchronism, without feeding power. If the power supply company can no longer guarantee the required supply, the control system is separated from the system of the power supply company and the generator is taking over the internal supply. In this example the control system is disconnected from the system of the power supply company as soon as the frequency leaves the nominal range (e.g. 1 - 2% deviation from the nominal frequency), the voltage exceeds or undershoots a set value, or the generator's active power is fed to the system of the power supply company. Depending on the user's philosophy, some of these criteria may be combined. This would be realized via the CFC. The example illustrates how a reverse power protection is implemented by means of the flexible protection functions. Frequency protection and voltage protection are described in Sections 2.8 Frequency Protection 81 O/U and 2.6 Voltage Protection 27, 59. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 253 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function [bsb-schaltanl-gen-eigenvers-20061205, 1, en_US] Figure 2-103 Example of a substation with autonomous generator supply Substation Layout The control system is on the high-voltage side linked via a 110 kV line to the power system of the power supply company. The circuit breaker CB1 is part of the power system of the power supply company. Disconnection from the control system of the power supply company's power system is effected by the load-isolator. The transformer with a transformation ratio of 10:1 transforms the voltage level to 11 kV. The transformer, the generator and the two feeders are linked via a busbar at the low-voltage side. Circuit breakers CB2 to CB5 separate consumer and operational equipment from the busbar. 254 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function Table 2-20 System data for the application example Power System Data Generator nominal power SNom,Gen = 38.1 MVA Transformer nominal power SNom,Trafo = 38.1 MVA Nominal voltage of high-voltage side UNom = 110 kV Nominal voltage of busbar side UNom = 11 kV Nominal primary CT current on busbar side Nom,prim = 2000 A Nominal secondary CT current on busbar side Nom,sek = 1 A Nominal primary VT voltage on busbar side UNom,prim = 11 kV Nominal secondary VT voltage on busbar side UNom,sek = 100 V Protective Functionality With protection device 7SJ80, the control system is disconnected from the generator upon the generator's reversed feeding into the power supply company's power system (protection function P reverse>). This functionality is realized by means of a flexible protection function. Additionally, the disconnection is effected by fluctuations in frequency or voltage in the power supply company's power system (protection function f<, f>, 27-1 PICKUP, 59-1 PICKUP, 67-1 PICKUP, , 67N-1 PICKUP). The protection receives the measured values via a three-phase current and voltage transformer set. In case of disconnection, the circuit breaker CB2 is triggered. The transformer is protected by a differential protection and inverse or definite time overcurrent protection functions for the phase-to-phase currents. In the event of a fault, the circuit-breaker CB1 in the power supply company's system is activated via a remote link. In addition, the circuit breaker CB2 is activated. Overcurrent protection functions protect the feeders 1 and 2 against short circuits and overload caused by the connected consumers. The phase-to-phase currents and the zero currents of the feeders can be protected by inverse and definite time overcurrent protection elements. In the event of a fault, the circuit breakers CB4 and CB5 are activated. In addition, the busbar could be equipped with the 7UT635 differential protective relay for multiple ends. The current transformers required to this end are already included in the example above. Wiring Diagram, Power Direction The following figure shows the wiring of the device for reverse power protection. The power flow in positive or forward direction occurs from the high-voltage busbar (not shown) via the transformer to the lowvoltage busbar. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 255 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function [7sj80-anschl-rueckleist-schutz-20061205, 1, en_US] Figure 2-104 Wiring diagram for a 7SJ80 as reverse power protection 2.19.2 Implementation of the Reverse Power Protection General The names of messages can be edited in DIGSI and adjusted accordingly for this example. The names of the parameters are fixed. Determination of the Reverse Power The reverse power protection evaluates the active power from the symmetrical components of the fundamental harmonics of the voltages and currents. The evaluation of the positive sequence systems causes reverse power determination to be independent of the asymmetries in currents and voltages and reflects the real load of the driving end. The calculated active power value corresponds to the total active power. The connection in the example illustrates positive measurement of power in the direction extending from the busbar to the transformer of the device. Functional Logic The following logic diagram depicts the functional logic of the reverse power protection. 256 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function [flexfkn-p-rueckwaerts-040104-st, 1, en_US] Figure 2-105 Logic diagram of the reverse power determination with flexible protection function The reverse power protection picks up once the configured pickup threshold has been exceeded. If the pickup condition persists during the equally settable pickup delay, the pickup message P.rev.PU is generated and starts the trip delay time. If the pickup condition does not drop out while the trip delay time is counting down, the trip indication P. rev. TRIP and the timeout indication P. rev. timeout (not shown) are generated. The picked up element drops out when the value falls below the dropout threshold. The blocking input >P rev. block blocks the entire function, i.e. pickup, trip and running times are reset. After the blocking has been released, the reverse power must exceed the pickup threshold and both times must run out before the protection function trips. Pickup Value, Dropout Ratio The pickup value of the reverse power protection is set to 10% of the nominal generator output. In this example, the setting value is configured as secondary power in watts. The following relationship exists between the primary and the secondary power: [flexfkn-ansprechwert-250204-he, 1, en_US] On the basis of the indicated data, the pickup values are calculated considering P prim = 3.81 MW (10% of 38.1 MW) on the primary level to [flexfkn-ansprechwert-numer-250204-he, 1, en_US] on the secondary level. The dropout ratio is set to 0.9. This yields a secondary dropout threshold of Psec, dropout = 15.6 W. If the pickup threshold is reduced to a value near the lower setting limit of 10 W, the dropout ratio should equally be reduced to approximately 0.7. Delay for Pickup, Dropout and Trip The reverse power protection does not require short tripping times as protection from undesired power feedback. In the present example, it is useful to delay pickup and dropout by about 0.5 s and the trip by approx. 1 s. Delaying the pickup will minimize the number of fault logs which are opened when the reverse power oscillates around the threshold. When using the reverse power protection to disconnect the substation quickly from the power supply company's system if faults occur, it is useful to select a larger pickup value (e.g. 50% of nominal power) and shorter time delays. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 257 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function 2.19.3 Configuring the Reverse Power Protection in DIGSI First create and open a 7SJ64x (e.g. 7SJ642) device in DIGSI Manager. Configure a flexible protection function (flexible function 01) for the present example in the Device Configuration. [funktionsumfang-flexfkn01-030204-he, 1, en_US] Figure 2-106 Configuration of a flexible protection function Select "Additional functions" in the Parameters" menu to view the flexible function The parameter selection options for the flexible protection functions primarily depend on the settings made in the Power System Data 1 for the connection of the voltage and current transformers (Addresses 213 and 251). [flexfkn-weitere-funktionen-030204-he, 1, en_US] Figure 2-107 The flexible function appears in the function selection. First activate the function at "Settings --> General" and select the operating mode "3-phase" 258 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function [flexfkn-einstellungen-allgemein-3phasig-030204-he, 1, en_US] Figure 2-108 Selection of the three-phase operating mode In menu items "Measured Value" and "Measurement Procedures" "Active Power reverse"" or "Exceeding" must be set. If in menu item Settings" the box Additional Parameters display" is enabled, threshold value, pickup delay time and trip delay time can be configured. As the power direction cannot be determined in case of measured voltage failure, protection blocking would be sensible in this case. [flexfkn-einstellungen-5-watt-030204-he, 1, en_US] Figure 2-109 Setting options of the flexible function Allocating the Reverse-Power Protection in DIGSI Configuration Matrix The DIGSI configuration matrix initially shows the following indications (after selecting "Indications and commands only" and "No filter". SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 259 Functions 2.19 Reverse-Power Protection Application with Flexible Protection Function [flexfkn-rangierung-vor-dem-editieren-030204-he, 1, en_US] Figure 2-110 Indications prior to editing Clicking the texts allows for editing short text and long text as required by the application. [flexfkn-rangierung-nach-dem-editieren-030204-he, 1, en_US] Figure 2-111 Indications after editing The indications are allocated in the same way as the indications of other protective functions. 260 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck 2.20 Synchrocheck When connecting two sections of a power system, the synchrocheck function verifies that the switching does not endanger the stability of the power system Applications * Typical applications are, for example, the synchronization of a feeder and a busbar or the synchronization of two busbars via tie-breaker. 2.20.1 General Synchronous power systems exhibit small differences regarding frequency and voltage values. Before connection it is to be checked whether the conditions are synchronous or not. If the conditions are synchronous, the system is energized; if they are asynchronous, it is not. The circuit breaker operating time is not taken into consideration. The synchrocheck function is activated via address 161 SYNCHROCHECK. For comparing the two voltages of the sections of the power system to be synchronized, the synchrocheck function uses the reference voltage V1 and an additional voltage to be connected V2. If a transformer is connected between the two voltage transformers as shown in the following example, its vector group can be adapted in the 7SJ80 relay so that there is no external adjustment required. [synchro-fkt-einspeis-061115, 1, en_US] Figure 2-112 Infeed SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 261 Functions 2.20 Synchrocheck [synchro-fkt-querkuppl-061115, 1, en_US] Figure 2-113 Cross coupling The synchrocheck function of the 7SJ80 usually coordinates with the integrated automatic reclosing system and the control function. Nevertheless, it is also possible to employ an external automatic reclosing system. In such a case, the signal exchange between the devices is to be accomplished via binary inputs and outputs. The configuration determines whether the synchrocheck is to be carried out only in the case of automatic reclosing or only in the case of circuit breaker control or in both cases. It is also possible to configure different release criteria for automatic reclosing or control closing. Synchronous connection is always accomplished via the integrated control. The release command for closing under satisfied synchronism conditions can be deactivated via parameter 6113 25 Synchron. For special applications, the deactivated closing release can, however, be activated via a binary input (>25 synchr.) (see "De-energized Switching"). Connection, Multi-phase For comparing the two voltages, the synchrocheck function uses the reference voltage V1 and an additional voltage to be connected V2. For the multi-phase connection, set the P.System Data 1 at 213 Vab, Vbc, VSyn. With this setting, the device is connected as open-delta connection and the phase-to-phase voltages VAB and VBC are used as reference voltage V1. The voltage to be synchronized V2 is assigned to the single-phase connection and may be any phase-to-phase voltage. The connected voltage is set at address 6123. Furthermore, it should be noted that in the case of an open-delta connection, no zero voltage can be determined. In this case, the functions "Directional Ground Fault Detection" and "Fuse Failure Monitor (FFM)" must be hidden or disabled. The function Directional Overcurrent Protection Ground" then works with the negative sequence system values. Notes on the effects of the current transformer connection can be found in Section 2.1.3.2 Setting Notes, Table 2-1. Connection, Single-phase If there is only one phase-to-ground voltage available for the reference voltage V1, the device can be informed of this fact via the P.System Data 1, address 213 Vph-g, VSyn. Also in this case the synchrocheck function can be fully applied. For the voltage to be synchronized V2, the same phase-to-ground voltage as for V1 has to be connected. Please note that some of the protection functions are restricted or do not work at all with this kind of connection. Notes on the effects of the current transformer connection can be found in Section 2.1.3.2 Setting Notes, Table 2-1. 262 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck 2.20.2 Functional Sequence Validity Check of the Configuration Already during startup of the device, a validation check of the configuration is performed. If there is a fault, the message 25 Set-Error is output. after a measurement request there is a condition which is not plausible, the message 25 Set-Error is output. The measurement is then not started. Concerning the configuration, it is also checked if the substation parameter 213 is set to Vab, Vbc, VSyn or Vph-g, VSyn. Furthermore, specific thresholds and settings of the function group are checked. If there is a condition which is not plausible, the error message 25 Set-Error is output additionally. Please ensure in this case that address 6106 (threshold V1, V2 energized) is smaller than address 6103 (lower voltage limit Vmin). The synchrocheck function cannot be controlled via a binary input. SYNC Error The synchronization is not started if a voltage transformer failure (m.c.b. tripping) is communicated to the device via the binary input 6509 >FAIL:FEEDER VT or 6510 >FAIL: BUS VT. The message 25 Sync. Error is output. In this case, the synchronization can be controlled directly via a binary input. In case of a protection pickup, the complete synchronization process is reset instantaneously. Release The synchrocheck function only operates if it receives a measurement request. This request may be issued by the internal control function, the automatic reclosing function or externally via a binary input, e.g. from an external automatic reclosing system. Before a release for closing is granted, the following conditions are checked: * Is the reference voltage V1 above the setting value Vmin but below the maximum voltage Vmax? * Is the voltage V2 to be synchronized above the setting value Vmin, but below the maximum voltage Vmax? * * * * * * * Is the voltage difference V2 - V1 within the permissible limit dV SYNCHK V2>V1? Is the voltage difference V1 - V2 within the permissible limit dV SYNCHK V2<V1? Are the two frequencies f1 and f2 within the permissible operating range fNom 3 Hz? Is the frequency difference f2 - f1 within the permissible limit df SYNCHK f2>f1? Is the frequency difference f1 - f2 within the permissible limit df SYNCHK f2<f1? Is the angle difference 2 - 1 within the permissible limit d SYNCHK 2>1? Is the angle difference 1 - 2 within the permissible limit d SYNCHK 2<1? If there is a condition which is not plausible, the message 25 Sync. Error is output and the measurement is not started. the conditions are plausible, the measurement is started (message25-1 meas.) and the configured release conditions are checked. Each condition which is met is indicated explicitly (messages 25 Vdiff ok, 25 fdiff ok, 25 diff ok). Conditions which are not met are also indicated explicitly, e.g. when the voltage difference (messages 25 V2>V1, 25 V2<V1), frequency difference (messages 25 f2>f1", 25 f2<f1") or angle difference (messages 25 2>1, 25 2<1) is outside the limit values. The precondition for these messages is that both voltages are within the operating range of the synchrocheck function (see "Operating Range"). If the conditions are met, the synchrocheck function issues a release signal for closing the relay (25 CloseRelease). This release signal is only available for the configured duration of the CLOSE command and is processed by the device's function control as CLOSE command to the circuit breaker (see also margin heading "Interaction with Control"). However, the message 25 Synchron is applied as long as the synchronous conditions are met. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 263 Functions 2.20 Synchrocheck The measurement of the the synchronism conditions can be confined to the a maximum monitoring time TSYN. DURATION. If the conditions are not met within T-SYN. DURATION, the release is cancelled (message 25 MonTimeExc). A new synchronization can only be performed if a new measurement request is received. Operating Range The operating range of the synchrocheck function is defined by the configured voltage limits Vmin and Vmax as well as the fixed frequency band fNom 3 Hz If the measurement is started and one of or both voltages are outside the operating range or one of the voltages leaves the operating range, this is indicated by corresponding messages (25 f1>>, 25 f1<<, 25 V1>>, 25 V1<<). Measured Values The measured values of the synchrocheck function are displayed in separate windows for primary, secondary and percentaged measured values. The measured values are displayed and updated only while the synchrocheck function is requested. The following is displayed: * Value of the reference voltage V1 * * * Value of the voltage to be synchronized V2 Frequency values f1 and f2 Differences of voltage, frequency and angle. 2.20.3 De-energized Switching Connecting two components of a power system is also possible if at least one of the components is de-energized and if the measured voltage is greater than the threshold 6106 V>. With a multi-phase connection on the side V1, all connected voltages must have a higher value than the threshold V> so that the side V1 is considered as being energized. With a single-phase connection, of course, only the one voltage has to exceed the threshold value. Besides the release under synchronous conditions, the following additional release conditions can be selected for the check: SYNC V1>V2< = SYNC V1<V2> = SYNC V1<V2< = Release on the condition that component V1 is energized and component V2 is deenergized. Release on the condition that component V1 is de-energized and component V2 is energized. Release on the condition that component V1 and component V2 are de-energized. Each of these conditions can be enabled or disabled individually via parameters or binary inputs; combinations are thus also possible (e.g. release if SYNC V1>V2< or SYNC V1<V2> are fulfilled). For that reason synchronization with the use of the additional parameter 6113 25 Synchron (configured to NO) can also be used for the connection of a ground electrode. In such a case, connection is only permissible when there is no voltage on the load side. The threshold below which a power system component is considered as being de-energized is defined by parameter V<. If the measured voltage exceeds the threshold V>, a power system component is considered as being energized. With a multi-phase connection on the side V1, all connected voltages must have a higher value than the threshold V> so that the side V1 is considered as being energized. With a single-phase connection, of course, only the one voltage has to exceed the threshold value. Before granting a release for connecting the energized component V1 and the de-energized component V2, the following conditions are checked: 264 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck * * * Is the reference voltage V1 above the setting value Vmin and V> but below the maximum voltage Vmax? Is the voltage to be synchronized V2 below the setting value V<? Is the frequency f1 within the permissible operating range fNom 3 Hz? After successful completion of the checks, the release is granted. For connecting the de-energized component 1 to the energized component 2 or the de-energized component 1 to the de-energized component 2, the conditions to be fulfilled correspond to those stated above. The associated messages indicating the release via the corresponding condition are as follows: 25 V1> V2<, 25 V1< V2> and 25 V1< V2<. Via the binary inputs >25 V1>V2<, >25 V1<V2> and >25 V1<V2<, the release conditions can also be issued externally, provided the synchronization is controlled externally. The parameter TSUP VOLTAGE (address 6111) can be set to configure a monitoring time which requires the additional release conditions stated above to be present for de-energized connection before connection is allowed. 2.20.4 Direct Command / Blocking Parameter 6110 Direct CO can be set to grant a release without performing any checks. In this case, connection is allowed immediately when initiating the synchrocheck function. It is obviously not reasonable to combine Direct CO with other release conditions. If the synchrocheck function fails, a direct command may be issued or not, depending on the type of failure (also see "Plausibility Check" and "SYNC Error"). Via the binary input >25direct CO, this release can also be granted externally. Blocking the entire synchrocheck function is possible via the binary input >BLK 25-1. The message signaling this condition is output via 25-1 BLOCK. With the blocking, the measurement is terminated and the entire function is reset. A new measurement can only be performed with a new measurement request. Via the binary input >BLK 25 CLOSE it is possible to block only the release signal for closing (25 CloseRelease). When the blocking is active, measurement continues. The blocking is indicated by the message 25 CLOSE BLK. When the blocking is reset and the release conditions are still fulfilled, the release signal for closing is issued. 2.20.5 Interaction with Control, Automatic Reclosing and External Control With Control Basically, the synchrocheck function interacts with the device control. The switchgear component to be synchronized is selected via a parameter. If a CLOSE command is issued, the control takes into account that the switchgear component requires synchronization. The control sends a measurement request (25 Measu. req.) to the synchrocheck function which is then started. Having completed the check, the synchrocheck function issues the release message (25 CloseRelease) to which the control responds by terminating the switching operation either positively or negatively. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 265 Functions 2.20 Synchrocheck [zusam-wirk-steuer-synchro-fkt-061115, 1, en_US] Figure 2-114 Interaction of control and synchrocheck function With Automatic Reclosing The automatic reclosing (AR) function can also interact with the synchrocheck function. They are linked via the device control. The selection is made via configuration in the automatic reclosing and synchrocheck function. The AR parameters (7138 Internal SYNC) determine whether working with SYNC function group 1 or - in the case of external synchronization - without SYNC function group. The switch to be used is defined in function group 1. The switchgear component indicated in the AR parameters (7137 Cmd.via control) and the SYNC function group must be identical. If no SYNC function group is entered in the AR parameters, the close command of the AR function is carried out asynchronously via the switchgear component indicated in the AR parameters. Equally, the CLOSE command 79 Close (message 2851) allows only asynchronous switching. If, for example, circuit breaker Q0 is configured as object to be switched synchronously, a CLOSE command of the AR function will address this breaker and assign it a CLOSE command which will be processed by the control. As this breaker requires synchronization, the control launches the synchrocheck function and awaits release. If the configured conditions of the SYNC function group are fulfilled, the release is granted and the control issues the CLOSE command. [anbind-awe-an-synchro-fkt-061115, 1, en_US] Figure 2-115 266 Connection of the automatic reclosing function to the synchrocheck function SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck With External Control As another option, the synchrocheck function can be activated via external measurement requests via binary inputs. If the start is effected via the pulse start signal >25 Start, the corresponding stop signal >25 Stop must always be generated, too. Having completed the check, the synchrocheck function issues the release message (see the following figure). Measurement is terminated as soon as the measurement request is reset via the binary input. In this case, there is no need to configure a control device to be synchronized. [zusam-wirk-synchro-fkt-mit-ext-anst-061115, 1, en_US] Figure 2-116 Interaction of synchrocheck function and external control 2.20.6 Setting Notes General The synchronization function can only operate if 25 Function 1 with SYNCHROCHECK was enabled at address 161 during configuration of the functional scope (see Section 2.1.1.2 Setting Notes). If this function is not required, then Disabled is set. While setting the Power System Data 1 (see Section Voltage Connection (Power System), Page 40) the device was already provided with data relevant for the measured values and the operating principle of the synchronization function. This concerns the following parameters: 202 Vnom PRIMARY primary nominal voltage of the voltage transformers V1 (phase-to-phase) in kV; 203 Vnom SECONDARY secondary nominal voltage of the voltage transformers V1 phase-to-phase) in V; 213 VT Connect. 3ph specifies how the voltage transformers are connected. When using the synchronization function the setting Vab, Vbc, VSyn is used if two phase-to-phase voltages are open delta-connected to the device. You can use any phase-to-phase voltage as the reference voltage VSYN Use the setting Vph-g, VSyn if only phase-to-ground voltages are available. One of these voltages is connected to the first voltage transformer; the reference voltage VSYN is connected to the third voltage transformer. V1 at the first voltage transformer and V2 at the third voltage transformer must belong to the same voltage type (VAN or VBN or VCN). Connection examples are given under side heading "Voltage Connections" and in the Appendix C Connection Examples). If you have set Vab, Vbc, VSyn or Vph-g, VSyn, the zero sequence voltage can not be determined. The functions "Directional Ground Fault Detection", "Directional Time Overcurrent Protection Ground" and "Fuse Failure Monitor (FFM)" are disabled in this case. Table 2-1 in the Section provides information about the consequences of the different voltage connection types. The operating range of the synchronization function (fNom 3 Hz) refers to the nominal frequency of the power system, address 214 Rated Frequency. The corresponding messages of the SYNC function group are pre-allocated for IEC 60870-5-103 (VDEW). Selecting the SYNC function group in DIGSI opens a dialog box with tabs in which the individual parameters for synchronization can be set. General Settings The general thresholds for the synchronizing function are set at addresses 6101 to 6112. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 267 Functions 2.20 Synchrocheck Address 6101 Synchronizing allows you to switch the entire SYNC function group ON or OFF. If switched off, the synchrocheck does not verify the synchronization conditions and release is not granted. Parameter 6102 SyncCB is used to select the switchgear component to which the synchronization settings are applied. Select the option none to use the function as external synchronizing feature. It will then be triggered via binary input messages. Addresses 6103 Vmin and 6104 Vmax set the upper and lower limits for the operating voltage range for V1 or V2 and thus determine the operating range for the synchronization function. Values outside this range will be signaled. Address 6105 V< indicates the voltage threshold below which the feeder or the busbar can safely be considered switched off (for checking a de-energized feeder or busbar). Address 6106 V> indicates the voltage threshold above which the feeder or busbar can safely be considered energized (for checking an energized feeder or busbar). It must be set below the anticipated operational undervoltage. The setting for the mentioned voltage values is made in secondary volts. When using DIGSI for configuration, these values can also be entered as primary values. Depending on the connection of the voltages these are phase-to-earth voltages or phase-to-phase voltages. Addresses 6107 to 6110 are set to specify the release conditions for the voltage check: Where 6107 SYNC V1<V2> = component V1 must be de-energized, component V2 must be energized (connection when reference is de-energized, dead line); 6108 SYNC V1>V2< = component V1 must be energized, component V2 must be de-energized (connection when feeder is de-energized, dead bus); 6109 SYNC V1<V2< = component V1 and component V2 must both be de-energized (connection when reference and feeder are de-energized, dead bus / dead line); 6110 Direct CO = connection released without checks. The possible release conditions are independent of each other and can be combined. It is not recommended to combine Direct CO with other release conditions. Parameter TSUP VOLTAGE (address 6111) can be set to configure a monitoring time which requires above stated release conditions to be present for at least de-energized switching before connection is allowed. The preset value of 0.1 s accounts for transient responses and can be applied without modification. Release via synchrocheck can be limited to a configurable synchronous monitoring time SYN. DURATION (address 6112). The configured conditions must be fulfilled within this time period. Otherwise release is not granted and the synchronizing function is terminated. If this time is set to , the conditions will be checked until they are fulfilled. For special applications (e.g. connecting a ground switch) parameter 6113 25 Synchron allows enabling/ disabling the connection release when the conditions for synchronism are satisfied. Power System Data The system related data for the synchronization function are set at addresses 6121 to 6125. The parameter Balancing V1/V2 (address 6121) can be set to account for different VT ratios of the two parts of the power system (see example in Figure 2-117). If a transformer is located between the system parts to be synchronized, its vector group can be accounted for by angle adjustment so that no external adjusting measures are required. Parameter ANGLE ADJUSTM. (address 6122) is used to this end. The phase angle from V1 to V2 is evaluated positively. Example: Busbar Feeder Transformer 400 kV primary; 100 V secondary 220 kV primary; 110 V secondary 400 kV/220 kV; vector group Dy(n)5 The transformer vector group is defined from the high side to the low side. In the example, the reference voltage transformers (V1) are the ones of the transformer high side, i.e. the setting angle is 5 x 30 (according to vector group), that is 150: 268 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck Address 6122 ANGLE ADJUSTM. = 150. The reference voltage transformers supply 100 V secondary for primary operation at nominal value while the feeder transformer supplies 110 V secondary. Therefore, this difference must be balanced: Address 6121 Balancing V1/V2 = 100 V/110 V = 0.91. [ss-spg-ueber-trafo-gemess-061115, 1, en_US] Figure 2-117 Busbar voltage measured across the transformer Voltage Connections The 7SJ80 provides two voltage inputs for connecting the voltage V1 and one voltage input for connecting the voltage V2 (see the following examples). If two phase-to-phase voltages are open delta-connected to side V1 as reference voltage, a phase-to-phase voltage must be connected and configured for the additional voltage V2 to be synchronized. To correctly compare the phase-to-phase reference voltage V1 with the additional voltage V2, the device needs to know the connection type of voltage V2. That is the task of parameter CONNECTIONof V2 (parameter 6123). For the device to perform the internal conversion to primary values, the primary rated transformer voltage of the measured quantity V2 must be entered via parameter 6125 VT Vn2, primary, primary if a transformer is located between the system parts to be synchronized. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 269 Functions 2.20 Synchrocheck [sync-mehrphasig-anschl-061116, 1, en_US] Figure 2-118 Phase-to-phase voltage connection (open-delta connection) If only phase-to-ground voltages are available, the reference voltage V1 is connected to the first voltage transformer and the additional voltage V2 to the third voltage transformer. [sync-1phasig-anschl-le-061116, 1, en_US] Figure 2-119 270 Phase-to-ground voltage connection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck Voltage Difference The parameters 6150 dV SYNCHK V2>V1 and 6151 dV SYNCHK V2<V1 can be set to adjust the permissible voltage differences asymmetrically. The availability of two parameters enables an asymmetrical release to be set. 2.20.7 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". Addr. Parameter Setting Options Default Setting Comments 6101 Synchronizing ON OFF OFF Synchronizing Function 6102 SyncCB (Setting options depend on none configuration) Synchronizable circuit breaker 6103 Vmin 20 .. 125 V 90 V Minimum voltage limit: Vmin 6104 Vmax 20 .. 140 V 110 V Maximum voltage limit: Vmax 6105 V< 1 .. 60 V 5V Threshold V1, V2 without voltage 6106 V> 20 .. 140 V 80 V Threshold V1, V2 with voltage 6107 SYNC V1<V2> YES NO NO ON-Command at V1< and V2> 6108 SYNC V1>V2< YES NO NO ON-Command at V1> and V2< 6109 SYNC V1<V2< YES NO NO ON-Command at V1< and V2< 6110A Direct CO YES NO NO Direct ON-Command 6111A TSUP VOLTAGE 0.00 .. 60.00 sec 0.10 sec Supervision time of V1>;V2> or V1<;V2< 6112 T-SYN. DURATION 0.01 .. 1200.00 sec; 30.00 sec Maximum duration of Synchronization 6113A 25 Synchron YES NO YES Switching at synchronous condition 6121 Balancing V1/V2 0.50 .. 2.00 1.00 Balancing factor V1/V2 6122A ANGLE ADJUSTM. 0 .. 360 0 Angle adjustment (transformer) 6123 CONNECTIONof V2 A-B B-C C-A A-B Connection of V2 6125 VT Vn2, primary 0.10 .. 800.00 kV 20.00 kV VT nominal voltage V2, primary 6150 dV SYNCHK V2>V1 0.5 .. 50.0 V 5.0 V Maximum voltage difference V2>V1 6151 dV SYNCHK V2<V1 0.5 .. 50.0 V 5.0 V Maximum voltage difference V2<V1 6152 df SYNCHK f2>f1 0.01 .. 2.00 Hz 0.10 Hz Maximum frequency difference f2>f1 6153 df SYNCHK f2<f1 0.01 .. 2.00 Hz 0.10 Hz Maximum frequency difference f2<f1 6154 d SYNCHK 2>1 2 .. 80 10 Maximum angle difference alpha2>alpha1 6155 d SYNCHK 2<1 2 .. 80 10 Maximum angle difference alpha2<alpha1 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 271 Functions 2.20 Synchrocheck 2.20.8 Information List No. Type of Information Comments 170.0001 >25-1 act SP >25-group 1 activate 170.0043 >25 Sync requ. SP >25 Synchronization request 170.0049 25 CloseRelease OUT 25 Sync. Release of CLOSE Command 170.0050 25 Sync. Error OUT 25 Synchronization Error 170.0051 25-1 BLOCK OUT 25-group 1 is BLOCKED 170.2007 25 Measu. req. SP 25 Sync. Measuring request of Control 170.2008 >BLK 25-1 SP >BLOCK 25-group 1 170.2009 >25direct CO SP >25 Direct Command output 170.2011 >25 Start SP >25 Start of synchronization 170.2012 >25 Stop SP >25 Stop of synchronization 170.2013 >25 V1>V2< SP >25 Switch to V1> and V2< 170.2014 >25 V1<V2> SP >25 Switch to V1< and V2> 170.2015 >25 V1<V2< SP >25 Switch to V1< and V2< 170.2016 >25 synchr. SP >25 Switch to Sync 170.2022 25-1 meas. OUT 25-group 1: measurement in progress 170.2025 25 MonTimeExc OUT 25 Monitoring time exceeded 170.2026 25 Synchron OUT 25 Synchronization conditions okay 170.2027 25 V1> V2< OUT 25 Condition V1>V2< fulfilled 170.2028 25 V1< V2> OUT 25 Condition V1<V2> fulfilled 170.2029 25 V1< V2< OUT 25 Condition V1<V2< fulfilled 170.2030 25 Vdiff ok OUT 25 Voltage difference (Vdiff) okay 170.2031 25 fdiff ok OUT 25 Frequency difference (fdiff) okay 170.2032 25 diff ok OUT 25 Angle difference (alphadiff) okay 170.2033 25 f1>> OUT 25 Frequency f1 > fmax permissible 170.2034 25 f1<< OUT 25 Frequency f1 < fmin permissible 170.2035 25 f2>> OUT 25 Frequency f2 > fmax permissible 170.2036 25 f2<< OUT 25 Frequency f2 < fmin permissible 170.2037 25 V1>> OUT 25 Voltage V1 > Vmax permissible 170.2038 25 V1<< OUT 25 Voltage V1 < Vmin permissible 170.2039 25 V2>> OUT 25 Voltage V2 > Vmax permissible 170.2040 25 V2<< OUT 25 Voltage V2 < Vmin permissible 170.2050 V1 = MV V1 = 170.2051 f1 = MV f1 = 170.2052 V2 = MV V2 = 170.2053 f2 = MV f2 = 170.2054 dV = MV dV = 170.2055 df = MV df = 170.2056 d = MV dalpha = 170.2090 25 V2>V1 OUT 25 Vdiff too large (V2>V1) 170.2091 25 V2<V1 OUT 25 Vdiff too large (V2<V1) 170.2092 25 f2>f1 OUT 25 fdiff too large (f2>f1) 170.2093 25 f2<f1 OUT 25 fdiff too large (f2<f1) 170.2094 25 2>1 OUT 25 alphadiff too large (a2>a1) 272 Information SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.20 Synchrocheck No. Information Type of Information Comments 170.2095 25 2<1 OUT 25 alphadiff too large (a2<a1) 170.2096 25 FG-Error OUT 25 Multiple selection of func-groups 170.2097 25 Set-Error OUT 25 Setting error 170.2101 25-1 OFF OUT Sync-group 1 is switched OFF 170.2102 >BLK 25 CLOSE SP >BLOCK 25 CLOSE command 170.2103 25 CLOSE BLK OUT 25 CLOSE command is BLOCKED SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 273 Functions 2.21 Phase Rotation 2.21 Phase Rotation A phase rotation function via binary input and parameter is implemented in 7SJ80 devices. Applications * Phase rotation ensures that all protective and monitoring functions operate correctly even with anticlockwise rotation, without the need for two phases to be reversed. 2.21.1 Functional Description General Various functions of the 7SJ80 only operate correctly if the phase rotation of the voltages and currents is known. Among these functions are negative sequence protection, undervoltage protection (based only on positive sequence voltages), directional overcurrent protection (direction with cross-polarized voltages), and measured value monitors. If an "acb" phase rotation is normal, the appropriate setting is made during configuration of the Power System Data. If the phase rotation can change during operation (e.g. the direction of a motor must be routinely changed), then a changeover signal at the routed binary input for this purpose is sufficient to inform the protective relay of the phase rotation reversal. Logic Phase rotation is permanently established at address 209 PHASE SEQ. (Power System Data). Via the exclusive- OR gate the binary input >Reverse Rot. inverts the sense of the phase rotation applied with setting. [meldelogikdrehfeldumschaltung-090902-kn, 1, en_US] Figure 2-120 Message logic of the phase rotation reversal Influence on Protective and Monitoring Functions The swapping of phases directly impacts the calculation of positive and negative sequence quantities, as well as phase-to-phase voltages via the subtraction of one phase-to-ground voltage from another and vice versa. Therefore, this function is vital so that phase detection messages, fault values, and operating measurement values are not correct. As stated before, this function influences the negative sequence protection function, directional overcurrent protection function, voltage protection function, flexible protection functions and some of the monitoring functions that issue messages if the defined and calculated phase rotations do not match. 2.21.2 Setting Notes Setting the Function Parameter The normal phase sequence is set at 209 (see Section 2.1.3 Power System Data 1). If, on the system side, phase rotation is reversed temporarily, then this is communicated to the protection device using the binary input >Reverse Rot. (5145). 274 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.22 Function Logic 2.22 Function Logic The function logic coordinates the execution of protection and auxiliary functions, it processes the resulting decisions and information received from the system. This includes in particular: Fault Detection / Pickup Logic Processing Tripping Logic 2.22.1 Pickup Logic of the Entire Device General Device Pickup The pickup signals for all protection functions in the device are connected via an OR logic and lead to the general device pickup. 4 It is initiated by the first function to pick up and drop out when the last function drops out. As a consequence, the following message is reported: 501 Relay PICKUP. The general pickup is a prerequisite for a number of internal and external consequential functions. The following are among the internal functions controlled by general device pickup: * Start of a trip log: From general device pickup to general device dropout, all fault messages are entered in the trip log. * Initialization of Oscillographic Records: The storage and maintenance of oscillographic values can also be made dependent on the general device pickup. Exception: Apart from the settings ON or OFF, some protection functions can also be set to Alarm Only. With setting Alarm Only no trip command is given, no trip log is created, fault recording is not initiated and no spontaneous fault annunciations are shown on the display. External functions may be controlled via an output contact. Examples are: * Automatic reclosing devices, * Starting of additional devices, or similar. 2.22.2 Tripping Logic of the Entire Device General Tripping The trip signals for all protective functions are connected by OR and generate the message 511 Relay TRIP. This message can be configured to an LED or binary output, just as the individual tripping messages can. Terminating the Trip Signal Once the trip command is output by the protection function, it is recorded as message Relay TRIP (see Figure 2-121). At the same time, the minimum trip command duration TMin TRIP CMD is started. This ensures that the command is transmitted to the circuit breaker for a sufficient amount of time, even if the function which issued the trip signal drops out quickly. The trip commands can be terminated first when the last protection function has dropped out (no function is in pickup mode) AND the minimum trip signal duration has expired. Finally, it is possible to latch the trip signal until it is manually reset (lockout function). This allows the circuitbreaker to be locked against reclosing until the cause of the fault has been clarified and the lockout has been manually reset. The reset takes place either by pressing the LED reset key or by activating an appropriately allocated binary input (>Reset LED). A precondition, of course, is that the circuit-breaker close coil - as usual - remains blocked as long as the trip signal is present, and that the trip coil current is interrupted by the auxiliary contact of the circuit breaker. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 275 Functions 2.22 Function Logic [7sj6x-abst-ausloesekommando-150502-kn, 1, en_US] Figure 2-121 Terminating the Trip Signal 2.22.3 Setting Notes Trip Signal Duration The minimum trip command duration TMin TRIP CMD was described already in Section 2.1.3 Power System Data 1. This setting applies to all protective functions that initiate tripping. 276 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions 2.23 Auxiliary Functions The general functions of the device are described in chapter "Auxililary Functions". 2.23.1 Message Processing After the occurrence of a system fault, data regarding the response of the protective relay and the measured values are saved for future analysis. For this reason the device is designed to perform message processing. Applications * * * LED Display and Binary Outputs (Output Relays) Information via Display Field or Personal Computer Information to a Control Center Prerequisites The SIPROTEC 4 System Description provides a detailed description of the configuration procedure (see /1/ SIPROTEC 4 System Description). 2.23.1.1 LED Displays and Binary Outputs (Output Relays) Important events and conditions are displayed, using LEDs at the front panel of the relay. The device furthermore has output relays for remote indication. All LEDs and binary outputs indicating specific messages can be freely configured. The relay is delivered with a default setting. The Appendix of this manual deals in detail with the delivery status and the allocation options. 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: * On site by pressing the LED key on the relay, * * * Remotely using a binary input configured for that purpose, Using one of the serial interfaces, Automatically at the beginning of a new pickup. State indication messages should not be latched. Also, they cannot be reset until the criterion to be reported has reset. This applies to messages from monitoring functions, or similar. A green LED displays operational readiness of the relay ("RUN"), and cannot be reset. It goes out if the selfcheck feature of the microprocessor recognizes an abnormal occurrence, or if the auxiliary voltage is lost. When auxiliary voltage is present, but the relay has an internal malfunction, then the red LED ("ERROR") lights up and the processor blocks the relay. 2.23.1.2 Information on the Integrated Display (LCD) or Personal Computer Events and conditions can be read out on the display at the front cover of the relay. Using the front PC interface or the port B at the botton, a personal computer can be connected, to which the information can be sent. The relay is equipped with several event buffers, for operational messages, circuit breaker statistics, etc., which are protected against loss of the auxiliary voltage by a buffer battery. These messages can be displayed on the LCD at any time by selection via the keypad or transferred to a personal computer via the serial service or PC interface. Readout of messages during operation is described in detail in the SIPROTEC 4 System Description. Classification of Messages The messages are categorized as follows: SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 277 Functions 2.23 Auxiliary Functions * Operational messages (event log); messages generated while the device is operating: Information regarding the status of device functions, measured data, power system data, control command logs etc. * * * Fault indications; these are indications of the last 25 network faults that were processed by the device. Ground fault messages (when the device has sensitive ground fault detection). Messages of "statistics"; they include a counter for the trip commands initiated by the device and possibly reclose commands as well as values of interrupted currents and accumulated fault currents. A complete list of all message and output functions that can be generated by the device with the maximum functional scope can be found in the appendix. All functions are associated with an information number (FNo). There is also an indication of where each message can be sent to. If functions are not present in a not fully equipped version of the device, or are configured to Disabled, then the associated indications cannot appear. Operational Messages (Buffer: Event Log) The operational messages contain information that the device generates during operation and about operational conditions. Up to 200 operational messages are recorded in chronological order in the device. New messages are appended at the end of the list. If the memory is used up, then the oldest message is scrolled out of the list by a new message. Fault Messages (Buffer: Trip Log) After a fault on the system, for example, important information about the progression of the fault can be retrieved, such as the pickup of a protective element or the initiation of a trip signal. The start of the fault is time stamped with the absolute time of the internal system clock. The progress of the disturbance is output with a relative time referred to the instant of fault detection, so that the duration of the fault until tripping and up to reset of the trip command can be ascertained. The resolution of the time information is 1 ms. Spontaneous Displays on the Device Front After occurrence of a fault, the most important fault data is output automatically on the device display, without any further operating actions. It is displayed after a general device pickup in the sequence shown in the following figure. [anzeige-spontanmeld-im-display-20070326, 1, en_US] Figure 2-122 Display of spontaneous messages in the HMI Retrievable Messages The messages for the last eight network faults can be retrieved and read out. The definition of a network fault is such that the time period from fault detection up to final clearing of the disturbance is considered to be one network fault. If auto-reclosing occurs, then the network fault ends after the last reclosing shot, which means after a successful reclosing or lockout. Therefore the entire clearing process, including all reclosing shots, occupies only one trip log buffer. Within a network fault, several fault messages can occur (from the first pickup of a protective function to the last dropout of a protective function). Without auto-reclosing each fault event represents a network fault. In total 600 indications can be recorded. Oldest data are erased for newest data when the buffer is full. Ground Fault Messages In devices with sensitive ground fault detection, separate ground fault logs are provided for ground fault recording. These logs are completed if the ground fault detection is not set to tripping but to Alarm Only (address 3101 = Alarm Only) or the setting ON with GF log has been selected. With setting ON with GF log, there is also a trip, apart from the opening of the ground fault log. 278 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions For cos- / sin- measurements, a criterion for the opening of the ground fault log is the pickup of the VN>element. For "U0/I0- measurements" the ground fault log is opened as soon as a VN>-element has responded and the angle condition is fulfilled. (Detailed information is provided in the logic diagrams for ground fault detection, Section 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s)). As soon as the pickup drops out, the fault recording is terminated. The ground fault log is opened as soon as the message 1271 Sens.Gnd Pickup (appearing) is issued and terminated upon disappearing of such message. Up to 45 ground fault messages can be recorded for the last 3 ground faults. If more ground fault messages are generated, the oldest are deleted consecutively. General Interrogation The general interrogation which can be retrieved via DIGSI enables the current status of the SIPROTEC 4 device to be read out. All messages requiring general interrogation are displayed with their present value. Spontaneous Messages The spontaneous messages displayed using DIGSI reflect the present status of incoming information. Each new incoming message appears immediately, i.e. the user does not have to wait for an update or initiate one. 2.23.1.3 Information to a Control Center Stored information can additionally be transferred to a central control and storage device if the relay is connected to such a device via port B. Transmission is possible via various transmission protocols. 2.23.2 Statistics The number of trips initiated by the 7SJ80, the number of close commands initiated by the AR and the operating hours under load are counted. An additional counter allows the number of hours to be determined in which the circuit breaker is positioned in the "open" condition. Further statistical data can be gained to optimize the intervals for circuit breaker maintenance. The counter and memory levels are secured against loss of auxiliary voltage. During the first start of the protection device the statistical values are pre-defined to zero. 2.23.2.1 Functional Description Number of Trips In order to count the number of trips of 7SJ80, the 7SJ80 relay has to be informed of the position of the circuit breaker auxiliary contacts via binary inputs. Hereby, it is necessary that the internal pulse counter #of TRIPs= is allocated in the matrix to a binary input that is controlled by the circuit breaker OPEN position. The pulse count value "Number of TRIPs CB" can be found in the "Statistics" group if the option "Measured and Metered Values Only" was enabled in the configuration matrix. Number of Automatic Reclosing Commands The number of reclosing commands initiated by the automatic reclosing function is summed up in separate counters for the 1st and 2nd cycle. Operating Hours The operating hours under load are also stored (= the current value in at least one phase is greater than the limit value BkrClosed I MIN set under address 212). Hours Meter "CB open" A meter can be realized as a CFC application if it adds up the number of hours in state "Circuit Breaker open" similarly to the operating hours meter. The universal hours meter is linked to a respective binary input and counts if the binary input is active. Alternatively, the undershooting of the parameter value 212 BkrClosed SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 279 Functions 2.23 Auxiliary Functions I MIN may be used as a criterion for starting the meter. The meter can be set or reset. A CFC application example for such meter is available on the Internet (SIPROTEC Download Area). 2.23.2.2 Circuit Breaker Maintenance General The procedures aiding in CB maintenance allow maintenance intervals of the CB poles to be carried out when their actual degree of wear makes it necessary. Saving on maintenance and servicing costs is one of the main benefits this functionality offers. The universal CB maintenance accumulates the tripping currents of the trips initiated by the protective functions and comprises the four following autonomous subfunctions: * * * * Summation tripping current (-procedure) Summation of tripping powers (x-procedure) Two-point procedure for calculating the remaining lifetime (2P-procedure) Sum of all Squared Fault Current Integral (I2t-procedure); Measured value acquisition and preparation operates phase-selectively for all four subfunctions. The three results are each evaluated using a threshold which is specific for each procedure (see Figure 2-123.). [schema-lsw-171103-kn, 1, en_US] Figure 2-123 Diagram of CB maintenance procedures The procedure is always present and active as a basic functionality. However, the other procedures (x, 2P and 2t) can be selected via a common configuration parameter. As the load on the switch depends on the current amplitude and duration of the actual switching action, including arc deletion, determination of the start and end criteria is of great importance. The procedures x, 2P and 2t make use of the same criteria for that purpose. The logic of the start and end criterion is illustrated in Figure 2-124. 280 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions The start criterion is fulfilled by an internal protective tripping initiated by the group indication "device TRIP". Trips initiated via the internal control function are taken into consideration for the circuit breaker maintenance if the respective command is indicated via the parameter 265 Cmd.via control. An externally initiated trip command can be taken into consideration if the message >52 Wear start is sent simultaneously via a binary input. The edge of the sent message >52-a can also be used as a further criterion as this signals that the mechanism of the circuit breaker is put in motion in order to separate the contacts. As soon as the start criterion has been fulfilled, the parameterized opening time of the circuit breaker is started. The time of commencement of separation of the circuit breaker contacts is thus determined. The end of the trip procedure, including arc deletion is determined via another given parameter (CB tripping time) supplied by the manufacturer of the circuit breaker. In order to prevent an incorrect calculation procedure in case of circuit breaker failure, the current criterion 212 BkrClosed I MIN verifies whether the current actually returned to zero after two additional cycles. When the phase-selective logic release is fulfilled by the current criterion, the calculation and evaluation methods of the respective procedures are initiated. After these have been completed, the end criterion of the circuit breaker maintenance is fulfilled and ready for a new initiation. Please note that CB maintenance will be blocked if parameter settings are made incorrectly. This condition is indicated by the message 52 WearSet.fail, 52WL.blk n PErr or 52WL.blk I PErr (see Section 2.1.6.2 Setting Notes, "Power System Data 2"). The latter two indications can only take effect if the 2P-procedure was configured. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 281 Functions 2.23 Auxiliary Functions [logik-lsw-start-endekriterium-170903-kn, 1, en_US] Figure 2-124 Logic of the start and end criterion -Procedure Being a basic function, the -procedure is unaffected by the configuration and does not require any procedurespecific settings. All tripping currents occurring 11/2 periods after a protective trip, are summed up for each phase. These tripping currents are r.m.s. values of the fundamental harmonic. The interrupted current in each pole is determined for each trip signal. The interrupted fault current is indicated in the fault messages and is added up with previously stored fault current values in the statistic-counters. Measured values are indicated in primary terms. 282 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions The method does not feature integrated threshold evaluation. But using CFC it is possible to implement a threshold, which logically combines and evaluates the three summation currents via an OR operation. Once the summation current exceeds the threshold, a corresponding message will be triggered. x-Procedure While the -procedure is always enabled and active, use of the Ix-procedure depends on the CB maintenance configuration. This procedure operates analogously to the -procedure. The differences relate to the involution of the tripping currents and their reference to the exponentiated rated operating current of the CB. Due to the reference to r x, the result is an approximation to the number of make-break operations specified by the CB manufacturer. The displayed values can be interpreted as the number of trips at rated operational current of the CB. They are displayed in the statistics values without unit and with two decimal places. The tripping currents used for calculation are a result of the rms values of the fundamental harmonic, which is recalculated each cycle. If the start criterion is satisfied (as described in Section General"), the r.m.s. values, which are relevant after expiration of the opening time, are checked for each phase as to whether they comply with the current criterion. If one of the values does not satisfy the criterion, its predecessor will be used instead for calculation. If no r.m.s. value satisfies the criterion up to the predecessor of the starting point, which is marked by the start criterion, a trip has taken place which only affects the mechanical lifetime of the breaker and is consequently not detected by this procedure. If the current criterion grants the logic release after the opening time has elapsed, the recent primary tripping currents (b) are involuted and related to the exponentiated rated operating current of the CB. These values are then added to the existing statistic values of the x-procedure. Subsequently, threshold comparison is started using threshold I^x> as well as the output of the new related summation tripping current powers. If one of the new statistic values lies above the threshold, the message Threshold I^x> is generated. 2P-Procedure The application of the two-point procedure for the calculation of the remaining lifespan depends on the CMD configuration. The data supplied by the CB manufacturer is transformed in such manner that, by means of measuring the fault currents, a concrete statement can be made with regard to the still possible operating cycles. The CB manufacturer's double-log operating cycle diagrams form the basis of the measured fault currents at the time of contact separation. Determination of the fault currents is effected in accordance with the method as described in the above section of the x-procedure. The three results of the calculated remaining lifetime are represented as statistic value. The results represent the number of still possible trips, if the tripping takes place when the current reaches the rated operational current. They are displayed without unit and without decimals. As with the other procedures, a threshold logically combines the three "remaining lifetime results" via an OR operation and evaluates them. It forms the "lower threshold", since the remaining lifetime is decremented with each trip by the corresponding number of operating cycles. If one of the three phase values drops below the threshold, a corresponding message will be triggered. A double-logarithmic diagram provided by the CB manufacturer illustrates the relationship of operating cycles and tripping current (see example in Figure 2-125). This diagram allows the number of yet possible trips to be determined (for tripping with equal tripping current). According to the example, approximately 1000 trips can yet be carried out at a tripping current of 10 kA. The characteristic is determined by two vertices and their connecting line. Point P1 is determined by the number of permitted operating cycles at rated operating current r, point P2 by the maximum number of operating cycles at rated fault tripping current sc. The associated four values can be configured. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 283 Functions 2.23 Auxiliary Functions [lsw-2p-schaltspiel270404-he, 1, en_US] Figure 2-125 Diagram of operating cycles for the 2P procedure As Figure 2-125 illustrates a double-log diagram, the straight line between P1 and P2 can be expressed by the following exponential function: n = b*bm where n is the number of operating cycles, b the operating cycles at b = 1A, b the tripping current, and m the directional coefficient. The general line equation for the double-logarithmic representation can be derived from the exponential function and leads to the coefficients b and m. i 284 NOTE Since a directional coefficient of m < -4 is technically irrelevant, but could theoretically be the result of incorrect settings, it is limited to -4. If a coefficient is smaller than -4, the exponential function in the operating cycles diagram is deactivated. The maximum number of operating cycles with sc (263 OP.CYCLES Isc) is used instead as the calculation result for the current number of operating cycles, see Figure 2-126. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions [2p-richtungskoeffizient-300104-he, 1, en_US] Figure 2-126 Value limitation of directional coefficient With the characteristics description, you can calculate the actual remaining lifetime after each tripping. [fo_7sj_remaining-lifetime _01, 1, en_US] The index i characterizes the actual tripping. With the ratio of the maximum number of switching cycles (nmax is n at r) to the actual calculated number of switching cycles, you get the ratio of these concerning the maximum number of possible switching cycles in case of a tripping with rated operating current (r). In the following example, the circuit breaker has tripped 100 times with rated operating current, 2 times with rated short-circuit current, and 3 times with 10 kA. The number of permissible trippings with rated operating current is calculated as following: [fo_7sj_remaining-lifetime _03, 1, en_US] RLT Remaining lifetime In the example, 9465 more trippings with rated operating current are possible. If the current criterion described in the Section "General" grants the phase-selective logic release, the present number of operating cycles is calculated based on the tripping currents determined when the CB operating time on tripping has elapsed. They are set off against the remaining lifetime allowing the present statistic SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 285 Functions 2.23 Auxiliary Functions values to be displayed and the evaluation to be started using the specified threshold. If one of the new values lies above the threshold, the message Thresh.R.Endu.< is generated. Three additional phase-selective statistic values are provided to determine the portion of purely mechanical trips among the results of the remaining lifetime (e.g. for phase A: mechan.TRIP A=). They act as counters which count only the trips whose tripping currents are below the value of the current criterion. 2t-Procedure During the 2t-procedure the squared fault current integral occurring per trip is added up phase-selectively. The integral is derived from the squared instantaneous values of the currents occurring during arc time of the circuit breaker. This results in: T CB arc = (parameter 266 T 52 BREAKTIME) - (parameter 267 T 52 OPENING). The three sums of the calculated integrals are represented as statistic values referred to the squared device nominal current (nom2). As with the other procedures, a threshold logically combines the three sums via an OR operation and evaluates them. The calculated squared tripping currrent integrals are added to the existing statistic values. Subsequently, threshold comparison is started using threshold I^2t>, and the new statistic values are output. If one of the values lies above the threshold, the message Thresh. I^2t> is generated. Commissioning Usually, no measures are required for commissioning. However, should the protection device be exchanged (e.g. old circuit breaker and a new protection device), the initial values of the respective limit or statistical values must be determined via the switching statistics of the respective circuit breaker. 2.23.2.3 Setting Notes Reading/Setting/Resetting Counters The SIPROTEC 4 System Description provides a description of 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 MESSAGES --> STATISTICS by overwriting the counter values displayed. Circuit Breaker Maintenance Under address 172 52 B.WEAR MONIT one of the alternatives x procedure, 2P procedure, 2t procedure or Disabled can be set. All parameters relevant to this function are available at parameter block P.System Data 1 (see Section 2.1.3 Power System Data 1 ). The following setting values are important input values the subfunctions require in order to operate correctly: The CB Tripping Time is a characteristic value provided by the manufacturer. It covers the entire tripping process from the trip command (applying auxiliary power to the trip element of the circuit breaker) up to arc extinction in all poles. The time is set at address 266 T 52 BREAKTIME. The CB Operating Time T 52 OPENING is equally a characteristic value of the circuit breaker. It covers the time span between the trip command (applying auxiliary power to the trip element of the circuit breaker) and separation of CB contacts in all poles. It is entered at address 267 T 52 OPENING. The following diagram illustrates the relationship between these CB times. 286 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions [ls-zeiten-120304-he, 1, en_US] Figure 2-127 Illustration of the CB times Current flow monitoring 212 BkrClosed I MIN, which some protective functions rely upon to detect a closed CB, is used as the current zero criterion. It should be set with respect to the actually used device functions (see also margin heading "Current Flow Monitoring (CB)" in Section 2.1.3.2 Setting Notes. Procedure Being the basic function of summation current formation, the -procedure is always active and does not require any additional settings. This is irrespective of the configuration in address 172 52 B.WEAR MONIT. This method does not offer integrated threshold evaluation. The latter could, however, be implemented using CFC. x-Procedure Parameter 172 52 B.WEAR MONIT can be set to activate the x procedure. In order to facilitate evaluating the sum of all tripping current powers, the values are referred to the involuted CB rated operational current. This value is indicated in the CB data at address 260 Ir-52 in the P.System Data 1 and can be set as primary value. This reference allows the threshold of the x procedure to correspond to the maximum number of make-break operations. For a circuit breaker, whose contacts have not yet been worn, the maximum number of make-break operations can be entered directly as threshold. The exponent for the involution of the rated operational current and of the tripping currents is set at address 264 Ix EXPONENT. To meet different customer requirements, this exponent 264 Ix EXPONENT can be increased from 1.0 (default setting = 2.0) to 3.0. For the procedure to operate correctly, the time response of the circuit breaker must be specified in parameters 266 T 52 BREAKTIME and 267 T 52 OPENING. The summated values can be interpreted as the number of tripping operations at rated operational current of the CB. They are displayed in the statistical values without unit and with two decimal places. 2P-Procedure Parameter 172 52 B.WEAR MONIT can be set to activate the 2P procedure. An operating cycles diagram (see sample diagram in the functional description of the 2P procedure), provided by the manufacturer, shows the SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 287 Functions 2.23 Auxiliary Functions relationship of make-break operations and tripping current. The two vertices of this characteristic in a double logarithmic scale are decisive for the setting of addresses 260 to 263: Point P1 is determined by the number of permitted make-break operations (parameter 261 OP.CYCLES AT Ir) for rated operational current r (parameter 260 Ir-52) Point P2 is determined by the maximum number of make-break operations (parameter 263 OP.CYCLES Isc) for rated fault tripping current sc (parameter 262 Isc-52). For the procedure to operate correctly, the time response of the circuit breaker must be specified in parameters 266T 52 BREAKTIME and 267T 52 OPENING. 2t-Procedure The 2t-procedure is activated via configuration parameter 172 52 B.WEAR MONIT. The square fault current integrals are referred to the squared device nominal current. For purposes of determining the arc time, the device must be informed of the CB tripping time T 52 BREAKTIME as well as the CB opening time T 52 OPENING of the circuit breaker. For recognition of the last zero crossing (arc deletion) of the currents after tripping, the "Current-zero" Criterion is required. 2.23.2.4 Information List No. Information Type of Information Comments - #of TRIPs= PMV Number of TRIPs= 409 >BLOCK Op Count SP >BLOCK Op Counter 1020 Op.Hours= VI Counter of operating hours 1021 Ia = VI Accumulation of interrupted current Ph A 1022 Ib = VI Accumulation of interrupted current Ph B 1023 Ic = VI Accumulation of interrupted current Ph C 2896 79 #Close1./3p= VI No. of 1st AR-cycle CLOSE commands,3pole 2898 79 #Close2./3p= VI No. of higher AR-cycle CLOSE commands,3p 16001 I^x A= VI Sum Current Exponentiation Ph A to Ir^x 16002 I^x B= VI Sum Current Exponentiation Ph B to Ir^x 16003 I^x C= VI Sum Current Exponentiation Ph C to Ir^x 16006 Resid.Endu. A= VI Residual Endurance Phase A 16007 Resid.Endu. B= VI Residual Endurance Phase B 16008 Resid.Endu. C= VI Residual Endurance Phase C 16011 mechan.TRIP A= VI Number of mechanical Trips Phase A 16012 mechan.TRIP B= VI Number of mechanical Trips Phase B 16013 mechan.TRIP C= VI Number of mechanical Trips Phase C 16014 I^2t A= VI Sum Squared Current Integral Phase A 16015 I^2t B= VI Sum Squared Current Integral Phase B 16016 I^2t C= VI Sum Squared Current Integral Phase C 2.23.3 Measurement A series of measured values and the values derived from them are constantly available for call up on site, or for data transfer. Applications * * 288 Information on the actual status of the system Conversion of secondary values to primary values and percentages SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions Prerequisites Except for secondary values, the device is able to indicate the primary values and percentages of the measured values. A precondition correct display of the primary and percentage values is the complete and correct entry of the nominal values for the instrument transformers and the protected equipment as well as current and voltage transformer ratios in the ground paths when configuring the device. The following table shows the formulas which are the basis for the conversion of secondary values to primary values and percentages. When using the connection types Vab, Vbc or Vab, Vbc, Vx of the voltage transformers (address 213 VT Connect. 3ph), the measured values for power P, Q, S, power factor, energy and the derived values, such as mean values etc. are not available. Measured values which cannot be calculated due to the selected voltage connection are shown as dots. 2.23.3.1 Display of Measured Values Table 2-21 Measured Values A, B, C, Conversion formulae between secondary values and primary/percentage values sekundary primary % sec. 1, 2 E = 3 *0 e sec. (calculated) N = measured N sec. value of N-input Ns Ns sec. (Ns, 3I0real, 3I0reakctiv) N2 = measured value from the E2 input N2 sec. VA, VB, VC, VPh-N sec. V0, V1, V2, Vsyn VA-B, VB-C, VC-A VPh-Ph sec. VN VN sec. Vx Vx sec. P, Q, S (P and Q phase-segregated) No secondary measured values Power Factor (phase-segregated) cos cos Frequency Protection f in Hz f in Hz SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 cos * 100 in % 289 Functions 2.23 Auxiliary Functions Table 2-22 Legend for the conversion formulae Parameter CT PRIMARY Address Parameter Ignd-CT PRIM Address 204 CT SECONDARY 205 Ignd-CT SEC 218 Vnom PRIMARY 202 Vph / Vdelta 206 Vnom SECONDARY 203 FullScaleVolt. 1101 FullScaleCurr. 1102 VXnom PRIMARY 232 Ignd2-CT PRIM. 238 VXnom SECONDARY 233 Ignd2-CT SEC. 239 217 Depending on the type of device ordered and the device connections, some of the operational measured values listed below may not be available. The phase-to-ground voltages are either measured directly, if the voltage inputs are connected phase-to- ground, or they are calculated from the phase-to-phase voltages VA-B and VB-C and the displacement voltage VN. The displacement voltage VN is either measured directly or calculated from the phase-to-ground voltages: [verlagerungsspannunguen-020315-wlk, 1, en_US] Please note that value V0 is indicated in the operational measured values. The ground current N is either measured directly or calculated from the conductor currents. [erdstrom-020315-wlk, 1, en_US] Upon delivery, the power and operating values are set in such manner 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 to 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 1108 P,Q sign the signs for these components can be inverted. The calculation of the operational measured values is also performed during a fault. The values are updated in intervals of > 0.3 s and < 1 s. 2.23.3.2 Transfer of Measured Values Measured values can be transferred via the interfaces to a central control and storage unit. The measuring range in which these values are transmitted depend on the protocol and, if necessary, additional settings. 290 Protocol Transmittable measuring range, format IEC 60870-5-103 0 to 240 % of the measured value. IEC 61850 The primary operational measured values are transmitted. The measured values as well as their unit format are set out in detail in manual PIXIT 7SJ. The measured values are transmitted in "Float" format. The transmitted measuring range is not limited and corresponds to the operational measurement. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions Protocol Transmittable measuring range, format PROFIBUS, Modbus, DNP 3.0 DNP3 TCP PROFINET The unit format of the measured values on the device side is at first automatically generated by means of the selected nominal values of current and voltage within the system data. The current unit format can be determined in DIGSI or at the device via Menu Operational Values. The user can select via DIGSI which operational measured values (primary, secondary or percentage) must be transmitted. The measured values are always transmitted as 16-bit values including sign (range 32768). The user can define the scaling of the operational measured value to be transmitted. This will result in the respective transmittable measuring range. For further details, please refer to the descriptions and protocol profiles. 2.23.3.3 Information List No. Information Type of Information Comments 601 Ia = MV Ia 602 Ib = MV Ib 603 Ic = MV Ic 604 In = MV In 605 I1 = MV I1 (positive sequence) 606 I2 = MV I2 (negative sequence) 621 Va = MV Va 622 Vb = MV Vb 623 Vc = MV Vc 624 Va-b= MV Va-b 625 Vb-c= MV Vb-c 626 Vc-a= MV Vc-a 627 VN = MV VN 629 V1 = MV V1 (positive sequence) 630 V2 = MV V2 (negative sequence) 632 Vsync = MV Vsync (synchronism) 641 P= MV P (active power) 642 Q= MV Q (reactive power) 644 Freq= MV Frequency 645 S= MV S (apparent power) 680 Phi A = MV Angle Va-Ia 681 Phi B = MV Angle Vb-Ib 682 Phi C = MV Angle Vc-Ic 701 INs Real MV Resistive ground current in isol systems 702 INs Reac MV Reactive ground current in isol systems 807 /trip = MV Thermal Overload 830 INs = MV INs Senstive Ground Fault Current 831 3Io = MV 3Io (zero sequence) 832 Vo = MV Vo (zero sequence) 901 PF = MV Power Factor 16031 (3Vo,INs) = MV Angle between 3Vo and INsens. 18473 Va-b RMS= MV Va-b RMS(10 minute RMS value) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 291 Functions 2.23 Auxiliary Functions No. Information Type of Information Comments 18474 Vb-c RMS= MV Vb-c RMS(10 minute RMS value) 18475 Vc-a RMS= MV Vc-a RMS(10 minute RMS value) 30701 Pa = MV Pa (active power, phase A) 30702 Pb = MV Pb (active power, phase B) 30703 Pc = MV Pc (active power, phase C) 30704 Qa = MV Qa (reactive power, phase A) 30705 Qb = MV Qb (reactive power, phase B) 30706 Qc = MV Qc (reactive power, phase C) 30707 PFa = MV Power Factor, phase A 30708 PFb = MV Power Factor, phase B 30709 PFc = MV Power Factor, phase C 30800 VX = MV Voltage VX 30801 Vph-n = MV Voltage phase-neutral 2.23.4 Average Measurements The long-term averages are calculated and output by the 7SJ80. 2.23.4.1 Functional Description Long-Term Averages The long-term averages of the three phase currents x, the positive sequence components 1 for 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 averages mentioned above, the length of the time window for averaging and the frequency with which it is updated can be set. 2.23.4.2 Setting Notes Average Calculation The selection of the time period for measured value averaging is set with parameter 8301 DMD Interval in the corresponding setting group from A to D under MEASUREMENT. 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: Time average is generated for all measured values with a window of 15 minutes. The output is updated every 15/3 = 5 minutes. With address 8302 DMD Sync.Time, the starting time for the averaging window set under address 8301 is determined. This setting specifies if the window should start on the hour (On The Hour) or 15 minutes later (15 After Hour) or 30 minutes / 45 minutes after the hour (30 After Hour oder 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. 292 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions 2.23.4.3 Settings Addr. Parameter Setting Options Default Setting Comments 8301 DMD Interval 15 Min., 1 Sub 15 Min., 3 Subs 15 Min.,15 Subs 30 Min., 1 Sub 60 Min., 1 Sub 60 Min.,10 Subs 5 Min., 5 Subs 60 Min., 1 Sub Demand Calculation Intervals 8302 DMD Sync.Time On The Hour 15 After Hour 30 After Hour 45 After Hour On The Hour Demand Synchronization Time 2.23.4.4 Information List No. Information Type of Information Comments 833 I1 dmd= MV I1 (positive sequence) Demand 834 P dmd = MV Active Power Demand 835 Q dmd = MV Reactive Power Demand 836 S dmd = MV Apparent Power Demand 963 Ia dmd= MV I A demand 964 Ib dmd= MV I B demand 965 Ic dmd= MV I C demand 2.23.5 Min/Max Measurement Setup Minimum and maximum values are calculated by the 7SJ80. Time and date of the last update of the values can also be read out. 2.23.5.1 Functional Description Minimum and Maximum Values The minimum and maximum values for the three phase currents x, the three phase-to-ground voltages Vx-N, the three phase-to-phase voltages Vxy, the positive sequence components 1 and V1, the displacement voltage V0, the real power P, reactive power Q, and apparent power S, the frequency; and the power factor cos are calculated as primary values (including the date and time they were last updated). The minimum and maximum values of the long-term averages listed in the previous section are also calculated. The minimum and maximum values can be reset at any time via binary inputs or by using the integrated control panel or the DIGSI software. Additionally, the reset can be carried out cyclically, starting at a preset point of time. 2.23.5.2 Setting Notes Minimum and Maximum Values The tracking of minimum and maximum values can be reset automatically at a programmable point in time. To select this feature, address 8311 MinMax cycRESET should be set to YES. 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 8312 MiMa RESET TIME. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 293 Functions 2.23 Auxiliary Functions The reset cycle in days is entered at address 8313 MiMa RESETCYCLE, and the beginning date of the cyclical process, from the time of the setting procedure (in days), is entered at address 8314 MinMaxRES.START. 2.23.5.3 Settings Addr. Parameter Setting Options Default Setting Comments 8311 MinMax cycRESET NO YES YES Automatic Cyclic Reset Function 8312 MiMa RESET TIME 0 .. 1439 min 0 min MinMax Reset Timer 8313 MiMa RESETCYCLE 1 .. 365 Days 7 Days MinMax Reset Cycle Period 8314 MinMaxRES.START 1 .. 365 Days 1 Days MinMax Start Reset Cycle in 2.23.5.4 Information List No. Information Type of Information Comments - ResMinMax IntSP_Ev Reset Minimum and Maximum counter 395 >I MinMax Reset SP >I MIN/MAX Buffer Reset 396 >I1 MiMaReset SP >I1 MIN/MAX Buffer Reset 397 >V MiMaReset SP >V MIN/MAX Buffer Reset 398 >VphphMiMaRes SP >Vphph MIN/MAX Buffer Reset 399 >V1 MiMa Reset SP >V1 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 412 > MiMa Reset SP >Theta MIN/MAX Buffer Reset 837 IAdmdMin MVT I A Demand Minimum 838 IAdmdMax MVT I A Demand Maximum 839 IBdmdMin MVT I B Demand Minimum 840 IBdmdMax MVT I B Demand Maximum 841 ICdmdMin MVT I C Demand Minimum 842 ICdmdMax MVT I C 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 Minimum 848 QdMax= MVT Reactive Power Maximum 849 SdMin= MVT Apparent Power Minimum 850 SdMax= MVT Apparent Power Maximum 851 Ia Min= MVT Ia Min 852 Ia Max= MVT Ia Max 853 Ib Min= MVT Ib Min 294 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions No. Information Type of Information Comments 854 Ib Max= MVT Ib Max 855 Ic Min= MVT Ic Min 856 Ic Max= MVT Ic Max 857 I1 Min= MVT I1 (positive sequence) Minimum 858 I1 Max= MVT I1 (positive sequence) Maximum 859 Va-nMin= MVT Va-n Min 860 Va-nMax= MVT Va-n Max 861 Vb-nMin= MVT Vb-n Min 862 Vb-nMax= MVT Vb-n Max 863 Vc-nMin= MVT Vc-n Min 864 Vc-nMax= MVT Vc-n Max 865 Va-bMin= MVT Va-b Min 867 Va-bMax= MVT Va-b Max 868 Vb-cMin= MVT Vb-c Min 869 Vb-cMax= MVT Vb-c Max 870 Vc-aMin= MVT Vc-a Min 871 Vc-aMax= MVT Vc-a Max 872 Vn Min = MVT V neutral Min 873 Vn Max = MVT V neutral Max 874 V1 Min = MVT V1 (positive sequence) Voltage Minimum 875 V1 Max = MVT V1 (positive sequence) Voltage Maximum 876 Pmin= MVT Active Power Minimum 877 Pmax= MVT Active Power Maximum 878 Qmin= MVT Reactive Power Minimum 879 Qmax= MVT Reactive Power Maximum 880 Smin= MVT Apparent Power Minimum 881 Smax= MVT Apparent Power Maximum 882 fmin= MVT Frequency Minimum 883 fmax= MVT Frequency Maximum 884 PF Max= MVT Power Factor Maximum 885 PF Min= MVT Power Factor Minimum 1058 /TrpMax= MVT Overload Meter Max 1059 /TrpMin= MVT Overload Meter Min 2.23.6 Set Points for Measured Values SIPROTEC devices facilitate the setting of limit values for some measured and metered values. If any of these limit values is reached, exceeded or fallen below during operation, the device issues an alarm which is indicated in the form of an operational message. This can be allocated to LEDs and/or binary outputs, transferred via the interfaces and linked in DIGSI CFC. The limit values can be configured via DIGSI CFC and allocated via the DIGSI device matrix. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 295 Functions 2.23 Auxiliary Functions Applications * 2.23.6.1 This monitoring program works with multiple measurement repetitions and a lower priority than the protection functions. Therefore, it may not pick up if measured values are changed spontaneously in the event of a fault, before a pickup or tripping of the protection function occurs. This monitoring program is therefore absolutely unsuitable for blocking protection functions. Setting Notes Setpoints for Measured Values Setting is performed in the DIGSI configuration Matrix under Settings, Masking I/O (Configuration Matrix). Apply the filter "Measured and Metered Values Only" and select the configuration group "Set Points (MV)". Here you can insert new limit values via the Information Catalog which are subsequently linked to the measured value to be monitored using CFC. This view also allows you to change the default settings of the limit values under Properties. The settings for limit values must be in percent and usually refer to nominal values of the device. For more details, see the SIPROTEC 4 System Description and the DIGSI CFC Manual. 2.23.7 Set Points for Statistic 2.23.7.1 Functional Description For the statistical counters, setpoints may be entered and a message is generated as soon as they are reached. The message can be allocated to both output relays and LEDs. 2.23.7.2 Setting Notes Setpoints for the Statistical Counter The setting of threshold values for the statistical counters takes place in DIGSI under Messages Statistics in the sub-menu Threshold Values for Statistics. Double-click to display the corresponding contents in another window. By overwriting the previous value the settings can be changed (please refer to the SIPROTEC 4 System Description). 2.23.7.3 Information List No. Information Type of Information Comments - OpHour> LV Operating hours greater than 272 SP. Op Hours> OUT Set Point Operating Hours 16004 I^x> LV Threshold Sum Current Exponentiation 16005 Threshold I^x> OUT Threshold Sum Curr. Exponent. exceeded 16009 Resid.Endu. < LV Lower Threshold of CB Residual Endurance 16010 Thresh.R.Endu.< OUT Dropped below Threshold CB Res.Endurance 16017 I^2t> LV Threshold Sum Squared Current Integral 16018 Thresh. I^2t> OUT Threshold Sum Squa. Curr. Int. exceeded 2.23.8 Energy Metering Metered values for active and reactive energy are determined by the device. They can be output via the display of the device, read out with DIGSI via the operator interface or transmitted to a control center via port B. 296 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.23 Auxiliary Functions 2.23.8.1 Functional Description Metered Values for Active and Reactive Energy Metered values of the real power Wp and reactive power (Wq) are acquired in kilowatt, megawatt or gigawatt hours primary or in kVARh, MVARh or GVARh primary, separately according to the input (+) and output (-), or capacitive and inductive. The measured-value resolution can be configured. The signs of the measured values appear as configured in address 1108 P,Q sign (see Section "Display of Measured Values"). 2.23.8.2 Setting Notes Setting of parameter for meter resolution Parameter 8315 MeterResolution allows increasing the resolution of the energy metered values by the Factor 10 or Factor 100 compared to the Standard setting. 2.23.8.3 Settings Addr. Parameter Setting Options Default Setting Comments 8315 MeterResolution Standard Factor 10 Factor 100 Standard Meter resolution 2.23.8.4 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) 916 Wp= - Increment of active energy 917 Wq= - Increment of reactive energy 924 WpForward MVMV Wp Forward 925 WqForward MVMV Wq Forward 928 WpReverse MVMV Wp Reverse 929 WqReverse MVMV Wq Reverse 2.23.9 Commissioning Aids In test mode or during commissioning, the device information transmitted to a central or storage device can be influenced. There are tools available for testing the system interface (port B) and the binary inputs and outputs of the device. Applications * * Test Mode Commissioning Prerequisites In order to be able to use the commissioning aids described in the following, the device must be connected to a control center via port B. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 297 Functions 2.23 Auxiliary Functions 2.23.9.1 Functional Description Influencing Information to the Control Center During Test Mode Some of the available protocols allow for identifying all messages and measured values transmitted to the control center with "Test Mode" as the message cause while the device is tested on site. This identification prevents the message from being incorrectly interpreted as resulting from an actual fault. Moreover, a transmission block can be set during the test so that no messages are transferred to the control center. This can be implemented via binary inputs, using the interface on the device front and a PC. The SIPROTEC 4 System Description states in detail how to activate and deactivate test mode and blocked data transmission. Testing the Connection to a Control Center Via the DIGSI device control it can be tested whether messages are transmitted correctly. A dialog box shows the display texts of all messages which were allocated to the system interface (port B) in the DIGSI matrix. In another column of the dialog box, a value for the messages to be tested can be defined (e.g. message ON / message OFF). After having entered password no. 6 (for hardware test menus), the corresponding message is issued and can be read out in the event log of the SIPROTEC 4 device and in the substation control center. The procedure is described in detail in Chapter "Mounting and Commissioning". Checking the Binary Inputs and Outputs The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually and precisely controlled in DIGSI. This feature can be used, for example, to verify control wiring from the device to substation equipment (operational checks), during start-up. A dialog box shows all binary inputs and outputs as well as LEDs of the device with their present status. The operating equipment, commands, or messages that are configured (masked) to the hardware components are also displayed. After having entered password no. 6 (for hardware test menus), it is possible to switch to the opposite status in another column of the dialog box. Thus, you can energize every single output relay to check the wiring between protected device and the system without having to create the alarm allocated to it. The procedure is described in detail in Chapter "Mounting and Commissioning". Creating Oscillographic Recordings for Tests During commissioning, energization sequences should be carried out to check the stability of the protection also during closing operations. Oscillographic event recordings contain the maximum information on the behavior of the protection. Along with the capability of storing fault recordings via pickup of the protection function, the 7SJ80 also has the capability of capturing the same data when commands are given to the device via the service program DIGSI, the serial interface, or a binary input. For the latter, event >Trig.Wave.Cap. must be allocated to a binary input. Triggering for the oscillographic recording then occurs, for instance, via the binary input when the protection object is energized. An oscillographic recording that is triggered externally (that is, without a protective element pickup) are processed by the device as a normal oscillographic record. For each oscillographic record a fault record is created which is given its individual number to ensure that assignment can be made properly. However, these oscillographic recordings are not displayed in the fault log buffer in the display as they are no network fault events. The procedure is described in detail in Chapter "Mounting and Commissioning". 298 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.24 Breaker Control 2.24 Breaker Control A control command function is integrated in the SIPROTEC 4 7SJ80 to coordinate the operation of circuit breakers and other equipment in the power system. Control commands can originate from four command sources: * Local control at the device's operator panel * * * Operation using DIGSI Remote control via network control center or substation controller (e.g. SICAM) Automatic functions (e.g., via binary input) Switchgear with single and multiple busbars are supported. The number of switchgear devices to be controlled is limited only by the number of binary inputs and outputs. Interlocking checks ensure high security against maloperation and a multitude of switchgear types and operating modes are available. 2.24.1 Control Device Switchgear can also be controlled via the device's operator panel, DIGSI or a connection to the substation control equipment. Applications * Switchgear with single and double busbars Prerequisites The number of switchgear devices to be controlled is limited by the - existing binary inputs - existing binary outputs. 2.24.1.1 Functional Description Operation Using the Device's Operator Panel For controlling the device, there are two independent colored keys located below the graphic display. If you are somewhere in the menu system outside the control submenu, you can return to the control mode via one of these keys. Then, select the switchgear to be operated with the help of the navigation keys. The switching direction is determined by operating the I or O pushbutton. The selected switching direction is displayed flashing in the bottom line of the following security prompt. Password and security prompts prevent unintended switching operations. With ENTER the entries are confirmed. Cancellation is possible at any time before the control command is issued or during switch selection via the ESC key. Command end, feedback or any violation of the interlocking conditions are indicated. For further information on the device operation, please refer to Section 2.25 Notes on Device Operation. Operation using DIGSI Switchgear can be controlled via the operator control interface with a PC using the DIGSI software. The procedure to do so is described in the SIPROTEC 4 System Description (Control of Switchgear). Operation Using the System Interface Switchgear can be controlled via the serial system interface and a connection to the substation control equipment. For that it is necessary that the required periphery is physically existing in the device as well as in the SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 299 Functions 2.24 Breaker Control substation. Furthermore, certain settings for the serial interface need to be made in the device (see SIPROTEC 4 System Description). 2.24.1.2 Information List No. Information Type of Information Comments - 52Breaker CF_D12 52 Breaker - 52Breaker DP 52 Breaker - Disc.Swit. CF_D2 Disconnect Switch - Disc.Swit. DP Disconnect Switch - GndSwit. CF_D2 Ground Switch - GndSwit. DP Ground Switch 31000 Q0 OpCnt= VI Q0 operationcounter= 31001 Q1 OpCnt= VI Q1 operationcounter= 31008 Q8 OpCnt= VI Q8 operationcounter= 2.24.2 Types of Commands In conjunction with the power system control several command types can be distinguished for the device: 2.24.2.1 Functional Description Commands to the Process These are all commands that are directly output to the switchgear to change their process state: * Switching commands for controlling the circuit breakers (not synchronized), disconnectors and ground electrodes * * Step commands, e.g. raising and lowering transformer LTCs Set-point commands with configurable time settings, e.g. to control Petersen coils Internal / Pseudo Commands They do not directly operate binary outputs. They serve to initiate internal functions, simulate changes of state, or to acknowledge changes of state. * Manual overriding commands to manually update 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 flagged as such in the information status and can be displayed accordingly. * Tagging commands (for "setting") of the information value of internal objects, for example switching authority (remote/local), settings group switching, data transmission block and deleting/presetting metered values. * * Acknowledgment and resetting commands for setting and resetting internal buffers or data states. Information status command to set/reset the additional information "information status" of a process object, such as: - Input blocking - Output blocking 2.24.3 Command Sequence Safety mechanisms in the command sequence ensure that a command can only be released after a thorough check of preset criteria has been successfully concluded. Standard Interlocking checks are provided for each 300 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.24 Breaker Control individual control command. Additionally, user-defined interlocking conditions can be programmed separately for each command. The actual execution of the command is also monitored afterwards. The overall command task procedure is described in brief in the following list: 2.24.3.1 Functional Description Check Sequence 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 Recognition. User configurable interlocking checks - Switching Authority - Device Position Check (set vs. actual comparison) - Interlocking, Zone Controlled (logic using CFC) - System Interlocking (centrally, using SCADA system or substation controller) - Double Operation (interlocking against parallel switching operation) - Protection Blocking (blocking of switching operations by protective functions). Fixed Command Checks - Internal Process Time (software watch dog which checks the time for processing the control action between initiation of the control and final close of the relay contact) - Setting Modification in Process (if setting modification is in process, commands are denied or delayed) - Operating equipment enabled as output (if an operating equipment component was configured, but not configured to a binary input, the command is denied) - Output Block (if an output block has been programmed for the circuit breaker, and is active at the moment the command is processed, then the command is denied) - Board Hardware Error - Command in Progress (only one command can be processed at a time for one operating equipment, object-related Double Operation Block) - 1-of-n-check (for schemes with multiple assignments, such as relays contact sharing a common terminal a check is made if a command is already active for this set of output relays). Monitoring the Command Execution The following is monitored: * Interruption of a command because of a Cancel Command * Runtime Monitor (feedback message monitoring time) 2.24.4 Interlocking System interlocking is executed by the user-defined logic (CFC). 2.24.4.1 Functional Description Interlocking checks in a SICAM / SIPROTEC 4 system are normally divided in the following groups: SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 301 Functions 2.24 Breaker Control * * * System interlocking relies on the system data base in the substation or central control system. Bay interlocking relies on the object data base (feedbacks) of the bay unit. Cross-bay interlocking via GOOSE messages directly between bay units and protection relays (with IEC61850: The inter-relay communication with GOOSE is performed via the EN100 module) The extent of the interlocking checks is determined by the configuration of the relay. To obtain more information about GOOSE, please refer to the SIPROTEC 4 System Description. Switching objects that require system interlocking in a central control system are assigned to a specific parameter inside the bay unit (via configuration matrix). For all commands, operation with interlocking (normal mode) or without interlocking (Interlocking OFF) can be selected: * For local commands, by activation of "Normal/Test"-key switch, * * 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). Deactivated interlock switching means the configured interlocking conditions are not checked in the relay. Interlocked switching means that all configured interlocking conditions are checked within the command processing. If a condition is not fulfilled, the command will be rejected by a message with a minus added to it (e.g. "CO-"), immediately followed by a message. The following table shows the possible types of commands in a switching device and their corresponding annunciations. For the device the messages designated with *) are displayed in the event logs, for DIGSI they appear in spontaneous messages. Type of Command Command Cause Message 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" appearing in the message is a confirmation of the command execution. The command execution was as expected, in other words positive. The minus sign means a negative confirmation, the command was rejected. Possible command feedbacks and their causes are dealt with in the SIPROTEC 4 System Description. The following figure shows operational indications relating to command execution and operation response information for successful switching of the circuit breaker. 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 manual entry or abort are not checked, i.e. carried out independent of the interlocking. [leistungsschalterbetriebsmeldung-020315-wlk, 1, en_US] Figure 2-128 Example of an operational annunciation for switching circuit breaker 52 (Q0) Standard Interlocking (default) The standard interlockings contain the following fixed programmed tests for each switching device, which can be individually enabled or disabled using parameters: 302 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.24 Breaker Control * Device Status Check (set = actual): The switching command is rejected, and an error indication is displayed if the circuit breaker is already in the set position. (If this check is enabled, then it works whether interlocking, e.g. zone controlled, is activated or deactivated.) This condition is checked in both interlocked and non-interlocked status modes. * System Interlocking: To check the power system interlocking, a local command is transmitted to the central unit with Switching Authority = LOCAL. A switching device that is subject to system interlocking cannot be switched by DIGSI. * Zone Controlled / Bay Interlocking: Logic links in the device which were created via CFC are interrogated and considered during interlocked switching. * Blocking by Protection: Switch-ON commands are rejected with interlocked switches, as soon as one of the protection functions of the unit has opened a fault case. The OPEN-command, by contrast, can always be executed. Please be aware, activation of thermal overload protection elements or sensitive ground fault detection can create and maintain a fault condition status, and can therefore block CLOSE commands. * Double Operation Block: Parallel switching operations are interlocked against one another; while one command is processed, a second cannot be carried out. * Switching Authority LOCAL: A control command from the user interface of the device (command with command source LOCAL) is only allowed if the Key Switch (by configuration) is set to LOCAL. * Switching Authority DIGSI: Switching commands that are issued locally or remotely via DIGSI (command with command source DIGSI) are only allowed if remote control is admissible for the device (by configuration). If a DIGSI-PC communicates with the device, it deposits here its virtual device number (VD). Only commands with this VD (when Switching Authority = REMOTE) will be accepted by the device. Remote switching commands will be rejected. * Switching authority REMOTE: A remote switch command (command with source REMOTE) is only allowed if remote control is enabled at the device (by configuration). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 303 Functions 2.24 Breaker Control [schutz-standardverriegelungen-090902-kn, 1, en_US] Figure 2-129 Standard interlockings The following figure shows the configuration of the interlocking conditions using DIGSI. 304 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.24 Breaker Control [objekteigenschaft-verriegelungsbeding-020313-kn, 1, en_US] Figure 2-130 DIGSI dialog box for setting the interlocking conditions On devices with operator panel, the display shows the configured interlocking reasons. They are marked with letters explained in the following table. Table 2-23 Command types and corresponding messages Interlocking Commands Abbrev. Display L L System interlocking S A Zone controlled Z Z SET = ACTUAL (switch direction check) P P Protection blocking B B Switching Authority Control Logic using 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 "52 Close" and "52 Open" with the data values: ON/ OFF). Switching Authority The interlocking condition "Switching Authority" serves for determining the switching authority. It enables the user to select the authorized command source. For devices with operator panel, the following switching authority ranges are defined in the following priority sequence: * LOCAL * * DIGSI REMOTE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 305 Functions 2.24 Breaker Control The "Switching authority" object serves for interlocking or enabling LOCAL control but not REMOTE or DIGSI commands. With a 7SJ80, the switching authority can be changed between "REMOTE" and "LOCAL" on the operator panel after having entered the password or by means of CFC also via binary inputs and a function key. The "Switching authority DIGSI" is used for interlocking and allows commands to be initiated using DIGSI. Commands are allowed for both a remote and a local DIGSI connection. When a (local or remote) DIGSI PC logs on to the device, it enters its Virtual Device Number (VD). The device only accepts commands having that VD (with switching authority = OFF or REMOTE). When the DIGSI PC logs off, the VD is cancelled. Commands are checked for their source SC and the device settings, and compared to the information set in the objects "Switching authority" and "Switching authority DIGSI". Configuration Switching authority available Switching authority available DIGSI Specific device (e.g. switching device) Specific device (e.g. switching device) Table 2-24 y/n (create appropriate object) y/n (create appropriate object) Switching authority LOCAL (check for Local status): y/n Switching authority REMOTE (check for LOCAL, REMOTE, or DIGSI commands: y/n Interlocking logic Current Switching Authority Status Switching Command Issued with SC3)=LOCAL Command Issued from SC=LOCAL or REMOTE Command issued from SC=DIGSI LOCAL not registered Allowed Interlocked 2) - "switching authority LOCAL" Interlocked "DIGSI not registered" LOCAL Checked Allowed Interlocked 2) - "switching authority LOCAL" Interlocked 2) - "switching authority LOCAL" verriegelt, da VORORT- Steuerung" REMOTE Not checked Interlocked 1) - "switching Allowed authority REMOTE" Interlocked "DIGSI not registered" REMOTE Checked Interlocked 1) - "switching Interlocked 2) - "switching authority DIGSI" authority DIGSI" Allowed 1) also "Allowed" for: "switching authority LOCAL (check for Local status): is not marked 2) also "Allowed" for: "Switching authority REMOTE (check for LOCAL, REMOTE, or DIGSI status): is not marked" 3) SC = Source of command SC = Auto SICAM: Commands that are initiated internally (command processing in the CFC) are not subject to switching authority and are therefore always "allowed". Switching Mode The switching mode determines whether selected interlocking conditions will be activated or deactivated at the time of the switching operation. The following switching modes (local) are defined: * Local commands (SC = LOCAL) - interlocked (normal), or - non-interlocked switching. With a 7SJ80, the switching mode can be changed between "locked" and "unlocked" on the operator panel after having entered the password or by means of CFC also via binary inputs and a function key. The following switching modes (remote) are defined: 306 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.24 Breaker Control * Remote or DIGSI commands (SC = LOCAL, REMOTE, or DIGSI) - interlocked, or - non-interlocked switching. Here, deactivation of interlocking is accomplished via a separate command. - For commands from CFC (SC = AUTO SICAM), please observe the notes in the CFC manual (component: BOOL to command). Zone Controlled / Field Interlocking Zone controlled / field interlocking (e.g. via CFC) includes the verification that predetermined switchgear position conditions are satisfied to prevent switching errors (e.g. disconnector vs. ground switch, ground switch only if no voltage applied) as well as verification of the state of other mechanical interlocking in the switchgear bay (e.g. High Voltage compartment doors). Interlocking conditions can be programmed separately, for each switching device, for device control CLOSE and/or OPEN. The enable information with the data "switching device is interlocked (OFF/NV/FLT) or enabled (ON)" can be set up, * directly, using a single point or double point indication, key-switch, or internal indication (marking), or * by means of a control logic via CFC. When a switching command is initiated, the actual status is scanned cyclically. The assignment is done via "Release object CLOSE/OPEN". System Interlocking Substation Controller (System interlocking) involves switchgear conditions of other bays evaluated by a central control system. Double Activation Blockage Parallel switching operations are interlocked. As soon as the command has arrived all command objects subject to the interlocking are checked to know whether a command is being processed. While the command is being executed, interlocking is enabled for other commands. Blocking by Protection The pickup of protective elements blocks switching operations. Protective elements are configured, separately for each switching component, to block specific switching commands sent in CLOSE and TRIP direction. When enabled, "Block CLOSE commands" blocks CLOSE commands, whereas "Block TRIP commands" blocks TRIP signals. Switching operations in progress will immediately be aborted by the pickup of a protective element. Device Status Check (set = actual) For switching commands, a check takes place whether the selected switching device is already in the set/ desired position (set/actual comparison). This means, if a circuit breaker is already in the CLOSED position and an attempt is made to issue a closing command, the command will be refused, with the operating message "set condition equals actual condition". If the circuit breaker / switchgear device is in the intermediate position, then this check is not performed. Bypassing Interlockings Bypassing configured interlockings at the time of the switching action happens device-internal via interlocking recognition in the command job or globally via so-called switching modes. * SC=LOCAL - The user can switch between the modes "interlocked" or "non-interlocked" (bypassed) in the operator panel after entering the password or using CFC via binary input and function key. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 307 Functions 2.24 Breaker Control * * REMOTE and DIGSI - Commands issued by SICAM or DIGSI are unlocked via a global switching mode REMOTE. A separate request must be sent for the unlocking. The unlocking applies only for one switching operation and for commands caused by the same source. - Job order: command to object "Switching mode REMOTE", ON - Job order: switching command to "switching device" Command via CFC (automatic command, SC=Auto SICAM): - Behavior configured in the CFC block ("BOOL to command"). 2.24.5 Command Logging During the processing of the commands, independent of the further message routing and processing, command and process feedback information are sent to the message processing center. These messages contain information on the cause. With the corresponding allocation (configuration) these messages are entered in the event list, thus serving as a report. Prerequisites A listing of possible operating messages and their meaning as well as the command types needed for tripping and closing of the switchgear or for raising and lowering of transformer taps are described in the SIPROTEC 4 System Description. 2.24.5.1 Functional Description Acknowledgment of Commands to the Device Front All messages with the source of command LOCAL are transformed into a corresponding response and shown in the display of the device. Acknowledgment of commands to Local / Remote / DIGSI The acknowledgment of messages with source of command Local/ Remote/DIGSI are sent back to the initiating point independent of the routing (configuration on the serial digital interface). The acknowledgment 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. Monitoring of Feedback Information The processing of commands monitors the command execution and timing of feedback information for all commands. At the same time the command is sent, the monitoring time is started (monitoring of the command execution). This time controls whether the device achieves the required final result within the monitoring time. The monitoring time is stopped as soon as the feedback information arrives. If no feedback information arrives, a response Timeout command monitoring time appears and the process is terminated. Commands and information feedback are also recorded in the event list. 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 and a message is output. The "plus" sign appearing in a feedback information confirms that the command was successful. 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 and Switching Relays The command types needed for tripping and closing of the switchgear or for raising and lowering of transformer taps are described in the configuration section of the SIPROTEC 4 System Description /1/ SIPROTEC 4 System Description. 308 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions 2.25 Notes on Device Operation 2.25 Notes on Device Operation The operation of the 7SJ80 slightly differs from the other SIPROTEC 4 devices. These differences are described in the following. General information regarding the operation and configuration of SIPROTEC 4 devices is set out in the SIPROTEC 4 System Description. 2.25.1 Different operation Pushbuttons of the Control Panels Pushbutton Funktion/Bedeutung Confirming entries and navigating forward in the menus Navigating to the main menu (where necessary, press repeatedly), navigating backwards in the menus, discarding entries Testing the LEDs Resetting the LED memory and binary outputs Function key Fn for displaying the assignment of the function keys. If several function keys have been assigned, a second page is displayed for the assignment when leafing through, if required. Combined pushbutton with numeric keys for a faster navigation (e.g. Fn + 1 operational messages) Navigation to the main menu with Fn in combination with the numeric key 0. For setting the contrast, keep the pushbutton pressed for about 5 seconds. Set the contrast in the menu with the scrolling keys (downward: less contrast, upward: more contrast). Entry of Negative Signs Only a few parameters can reach a negative value, i.e. a negative sign can only be entered for these. If a negative sign is permissible, the prompt -/+ --> v/^ appears in the bottom line when changing the parameter. The sign can be determined via the scrolling keys: downward = negative sign, upward = positive sign. Display The SIPROTEC 4 System Description applies to devices with a 4-line ASCII display. Apart from that there are devices with a graphical display and a size of 30 lines. The 7SJ80 uses the outputs of the graphical display, but with 6 lines. Therefore, the representation might differ from the representations in the System Description. The basic differences of the device with regard to the representation are the following: The current selection is indicated by inverse representation (not by the prefix >) [grundbild-hauptmenue-20070404, 1, en_US] Figure 2-131 Inverse representation of the current selection In part, the sixth line is used for representing e.g. the active parameter group. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 309 Functions 2.25 Notes on Device Operation [grundbild-parameter-20070404, 1, en_US] Figure 2-132 310 Representation of the active parameter group (line 6) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 3 Mounting and Commissioning This chapter is intended for experienced commissioning staff. He must be familiar with the commissioning of protection and control systems, the management of power systems and the safety rules and regulations. Hardware adjustments to the power system data might be necessary. The primary tests require the protected object (line, transformer, etc.) to carry load. 3.1 Mounting and Connections 312 3.2 Checking Connections 328 3.3 Commissioning 332 3.4 Final Preparation of the Device 352 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 311 Mounting and Commissioning 3.1 Mounting and Connections 3.1 Mounting and Connections General ! WARNING Warning of improper transport, storage, installation or assembly of the device. Failure to observe these precautions can result in death, personal injury, or serious material damage. 3.1.1 Trouble-free and safe use of this device depends on proper transport, storage, installation, and assembly of the device according to the warnings in this device manual. Of particular importance are the general installation and safety regulations for work in a high-voltage environment (for example, ANSI, 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 have been checked as recommended in the SIPROTEC 4 System Description. It has been verified that these data comply with the power system data. General Diagrams Block diagrams for the terminal assignment of the 7SJ80 are shown in Appendix B Terminal Assignments. Connection examples for the current and voltage transformer circuits are provided in Appendix C Connection Examples. Voltage Connection Examples Connection examples for voltage transformers are provided in Appendix C Connection Examples. It must be checked that the configuration of the Power System Data 1 (Section Voltage Connection (Power System), Page 40) corresponds with the connections. The normal connection is set at address 213 VT Connect. 3ph = Van, Vbn, Vcn. When connecting an open delta winding of the voltage transformer set, address 213 VT Connect. 3ph must be set to Vab, Vbc, VGnd. For the synchrocheck function, address 213 must be set to Vab, Vbc, VSyn or Vph-g, VSyn. Another example shows the connection mode 213 = Vab, Vbc, Vx. The voltage connected to the third transformer Vx is only used by the flexible protection functions. Moreover, there are examples for the connection modes Vab, Vbc and Vph-g, VSyn. Binary Inputs and Outputs The configuration options of the binary in- and outputs, i.e. the procedure for the individual adaptation to the plant conditions, are described in the SIPROTEC 4 System Description. The connections to the plant are dependent on this configuration. The presettings of the device are listed in Appendix E Default Settings and Protocol-dependent Functions. Please also check that the labeling strips on the front panel correspond to the configured message functions. Setting Group Change If binary inputs are used to switch setting groups, please observe the following: 312 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections * Two binary inputs must be dedicated to the purpose of changing setting groups when four groups are to be switched. One binary input must be set for >Set Group Bit0, the other input for >Set Group Bit1. If either of these input functions is not assigned, then it is considered as not controlled. * For the control of 2 setting groups one binary input is sufficient, namely >Set Group Bit0, since the non-assigned binary input >Set Group Bit1 is then regarded as not connected. * The control signals must be permanently active so that the selected setting group is and remains active. The following table shows the allocation of the binary inputs to the setting groups A to D and a simplified connection diagram for the two binary inputs is 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). Where: no = yes = Table 3-1 not energized or not connected energized Changing setting groups using binary inputs Binary Input Active Group >Param.Wahl1 >Param. Wahl2 no no Group A yes no Group B no yes Group C yes yes Group D [einstellgruppenumschaltung-ueber-binaere-160502-wlk, 1, en_US] Figure 3-1 Connection diagram (example) for setting group switching using binary inputs Trip Circuit Supervision 74TC It must be noted 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 one binary input is used, a bypass resistor R must be used (see following figure). The resistor R is inserted into the circuit of the 52b circuit breaker auxiliary contact to facilitate the detection of a malfunction also when the 52a circuit breaker auxiliary contact is open and the trip contact has dropped out. The value of this resistor must be such that in the circuit breaker open condition (therefore 52a is open and 52b is closed), the circuit breaker trip coil (52TC) is no longer energized and binary input (BI1) is still energized if the command relay contact is open. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 313 Mounting and Commissioning 3.1 Mounting and Connections [prinzip-ausloesekreisueberwachung-1-binein-150502-kn, 1, en_US] Figure 3-2 Trip circuit supervision with one binary input This results in an upper limit for the resistance dimension, Rmax and a lower limit Rmin, from which the optimal value of the arithmetic mean R should be selected: [formel-mittelwert-r-260602-kn, 1, en_US] In order that the minimum voltage for controlling the binary input is ensured, Rmax is derived as: [formel-rmax-260602-kn, 1, en_US] So the circuit breaker trip coil does not remain energized in the above case, Rmin is derived as: [formel-rmin-260602-kn, 1, en_US] BI (HIGH) Constant current with activated BI ( = 0.4 mA) VBI min Minimum control voltage for BI (= 19 V at delivery setting for nominal voltages of 24 V/ 48 V; 88 V at delivery setting for nominal voltages of 60 V/ 110 V/ 125 V/ 220 V/ 250 V) VCTR Control voltage for trip circuit RCBTC Ohmic resistance of the circuit breaker coil VCBTC(LOW) Maximum voltage on the circuit breaker coil that does not lead to tripping If the calculation has the result max < Rmin, the calculation has to be repeated with the next smaller threshold VBI min. This threshold is determined via the parameters 220 Threshold BI 1 to 226 Threshold BI 7. The settings Thresh. BI 176V, Thresh. BI 88V, Thresh. BI 19V are possible. 314 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections For the power consumption of the resistance: [formel-leistungvon-r-260602-kn, 1, en_US] Example BI (HIGH) 0.4 mA (SIPROTEC 4 7SJ80) VBI min 19 V at delivery setting for nominal voltages of 24 V/ 48 V; 88 V at delivery setting for nominal voltages of 60 V/ 110 V/ 125 V/ 220 V/ 250 V VCTR 110 V (from the system / trip circuit) RCBTC 500 (from the system / trip circuit) VCBTC (LOW) 2 V (from the system / trip circuit) [fo_r-max-bsp, 1, en_US] [beispiel-rmin-20061211, 1, en_US] [fo_r-mittelwertbsp, 1, en_US] [fo_leistung-r, 1, en_US] 3.1.2 Hardware Modifications 3.1.2.1 Disassembly Work on the Printed Circuit Boards i NOTE i NOTE Before carrying out the following steps, make sure that the device is not operative. Apart from the communication modules and the fuse, there are no further components that can be configured or operated by the user inside the device. Any service activities exceeding the installation or exchange of communication modules must only be carried out by Siemens personnel For preparing the workplace, a pad suitable for electrostatic sensitive devices (ESD) is required. Additionally, the following tools are required: * a screwdriver with a 5 mm to 6 mm (0.20 - 0.24 in) wide blade, * * a Philips screwdriver size 1, a 5 mm (0.20 in) socket or nut driver SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 315 Mounting and Commissioning 3.1 Mounting and Connections In order to disassemble the device, first remove it from the substation installation. To do so, perform the steps stated in Sections Panel Flush Mounting, Panel Surface Mounting or Cubicle Mounting in reverse order. i NOTE i NOTE ! The following must absolutely be observed: Disconnect the communication connections at the device bottom (ports A and B). If this is not observed, the communication lines and/or the device might be destroyed. To use the device, all terminal blocks must be plugged in. CAUTION Mind electrostatic discharges Failure to observe these precautions can result in personal injury or material damage. i Any electrostatic discharges while working at the electronics block are to be avoided. We recommend ESD protective equipment (grounding strap, conductive grounded shoes, ESD-suitable clothing, etc.). Alternatively, an electrostatic charge is to be discharged by touching grounded metal parts. NOTE In order to minimize the expenditure for reconnecting the device, remove the completely wired terminal blocks from the device. Use a screwdriver (DIN 4 x 0.8) to carefully bend the left and right spring clips outwards. Then carefully pull out the terminal block. When reinstalling the device, carefully insert the terminal block into the spring clips. Both spring clips must engage clearly audible. (Sections Panel Flush Mounting, Panel Surface Mounting or Cubicle Mounting). In order to install or exchange communication modules or to replace the fuse, proceed as follows: Remove the two covers at the top and bottom. Thus, 1 housing screw each at the top and bottom becomes accessible. First, only unscrew the bottom housing screw so far that its tip no longer looks out of the thread of the mounting bracket (the housing screws are captive, they remain in the front cover even when unscrewed). Unscrew all screws that fasten any existing communication modules in the module cover on the bottom side of the device. Also unscrew the 4 countersunk screws that fasten the module cover on the bottom side of the device. Carefully pull the entire module cover out of the device. Only now completely unscrew the two housing screws at the top and bottom in the cover and carefully remove the complete electronics block from the housing (Figure 3-3). i 316 NOTE If you have not removed the terminal blocks from the rear panel, much more force is required for removing and reinstalling the electronics block, which might lead to the damaging of the device. Therefore, we absolutely recommend to remove the terminal blocks before removing the electronics block. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections [einschub-7sj80-20071107, 1, --_--] Figure 3-3 Electronics block without housing Replacing the Fuse The fuse holder is located at the edge of the basic I/O board close to the power supply connection. [7sx80-fuse-basic-io-080408, 1, en_US] Figure 3-4 Placing the fuse SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 317 Mounting and Commissioning 3.1 Mounting and Connections Remove the defective fuse. Insert the new fuse with the following technical data into the fuse holder: 5 mm x 20 mm (0.20 * 0.79 in) safety fuse T characteristic 2.0 A nominal current 250 V nominal voltage Switching capability 1500 VA/ DC 300 V Only UL-approved fuses may be used. This data applies to all device types (24 V/48 V and 60 V - 250 V). Make sure that the defective fuse has not left any obvious damage on the device. If the fuse trips again after reconnection of the device, refrain from any further repairs and send the device to Siemens for repair. The device can now be reassembled again (see Section Reassembly). 3.1.2.2 Connections of the Current Terminals Fixing Elements The fixing elements for the transformer connection are part of the current terminal (housing side). They have a stress-crack- and corrosion-resistant alloy. The head shape of the terminal screw allows for using a flat screwdriver (5.0 x 1.0 mm) or a crosstip screwdriver (PZ2). We recommend PZ2. Cable Lugs and Wire Cross-sections There are two connection options: the connection of single wires and the connection with a ring lug. Only copper wires may be used. We recommend ring lugs with the following dimensions: [ringkabelschuh-20070710, 1, en_US] Figure 3-5 Ring lug For complying with the required insulation clearances, insulated ring lugs have to be used. Otherwise, the crimp zone has to be insulated with corresponding means (e.g. by pulling a shrink-on sleeve over). We recommend ring lugs of the PIDG range from Tyco Electronics. Two ring lugs can be mounted per connection. 318 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections [stromwandler-anklemmen-20080530, 1, en_US] Figure 3-6 Current transformer connection As single wires, solid conductors as well as stranded conductors with conductor sleeves can be used. Up to two single wires with identical cross-sections can be used per connection. Alternatively jumpers (Order No. C53207-A406-D193-1) can be used with terminal points in a stacked arrangement. When using jumpers, only ring lugs are allowed. When connecting single wires, the following cross-sections are allowed: Cable cross-section: AWG 14-10 (2.0 mm2 to 5.2 mm2) Connector sleeve with plastic collar L = 10 mm (0.39 in) or L = 12 mm (0.47 in) Stripping length: (when used without conductor sleeve) 15 mm (0.59 in) Use exclusively solid copper conductors. Mechanical Requirements The fixing elements and the connected components are designed for the following mechanical requirements: 3.1.2.3 Permissible tightening torque at the terminal screw 2.7 Nm (23.9 lb.in) With solid conducters the allowed maximum tighting torque is 2 Nm Permissible traction per connected conductor 80 N based on IEC 60947-1 (VDE 660, Part 100) Connections of the Voltage Terminals Fixing Elements The fixing elements for the voltage transformer connection are part of the voltage terminal (housing side). They have a stress-crack- and corrosion-resistant alloy. The head shape of the terminal screw allows for using a flat screwdriver (4.0 mm x 0.8 mm / 0.16 in x 0.031 in) or a crosstip screwdriver (PZ1). PZ1 is recommended. Cable Lugs and Wire Cross-sections The connection mode available is the connection as single cable. As single cables, solid conductors as well as stranded conductors with or without conductor sleeves can be used. We recommend using twin cable end sleeves when connecting two single cables. We recommend the twin cable end sleeves of the series PN 966 144 from Tyco Electronics. When connecting single cables, the following cross-sections are allowed: Cable cross-sections: AWG 20-14 (0.5 mm2 to 2.0 mm2) Connector sleeve with plastic collar L = 12 mm (0.47 in) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 319 Mounting and Commissioning 3.1 Mounting and Connections Stripping length: (when used without conductor sleeve) 12 mm (0.47 in) Only copper cables may be used. With terminal points lying one below the other you may connect single conductors and jumpers (Order No. C53207-A406-D194-1) together. Please make sure that neighboring jumpers are built in/connected alternately. Mechanical Requirements The fixing elements and the connected components are designed for the following mechanical requirements: 3.1.2.4 Permissible tightening torque at the terminal screw 1.0 Nm (8.85 lb.in) Permissible traction per connected conductor 50 N based on IEC 60947-1 (VDE 660, Part 100) Interface Modules General The 7SJ80 relay is supplied with preconfigured interfaces according to the ordering version. You do not have to make any adaptations to the hardware (e.g. plugging in jumpers) yourself, except for the installation or replacement of communication modules. The use of the interface modules RS232, RS485 and optical can be defined via the parameter 617 ServiProt (CM). This parameter is only visible if the 11th digit of the ordering number was selected to be 1 for RS232, 2 for RS485 or 3 for optical. Installation or Replacement of the Ethernet Interface Module The following requirement must be fulfilled: There is no SIPROTEC 4 communication module mounted yet. Otherwise, this has to be removed before actually installing the Ethernet interface module (see below). The Ethernet interface module is inserted in the respective slot, most suitably from the open bottom, i.e. above the back of the battery case. A supporting frame is placed over the modular plug. The narrow spacer lies at edge of the printed circuit board. The module is attached to the 50-pole plug connector of the CPU module slightly inclined to the basic I/O board. The supporting plate is slightly pulled outwards in this area. The module can now be inserted vertically up to the stop. Then, the supporting plate is pressed against in the area of the locking latch until the upper edge of the printed circuit board of the Ethernet interface module snaps into the locking latch. [com-modul-mit-stuetz-20100716, 1, --_--] Figure 3-7 320 Ethernet interface with support frame SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections [en100-lc_schraeg-20071107, 1, --_--] Figure 3-8 Installation of the Ethernet interface Now, a SIPROTEC 4 communication module can be installed (see Section Installation or Replacement of a SIPROTEC 4 Communication Module). Otherwise, the device can be reassembled again (see Section Reassembly). Installation or Replacement of a SIPROTEC 4 Communication Module The following description assumes the normal case that a SIPROTEC 4 communication module which has not yet been existing is retrofitted. If a SIPROTEC 4 communication module has to be removed or replaced, the steps are to be performed in reverse order. i NOTE The installation can only be performed alone or after the installation of the Ethernet module. The SIPROTEC 4 communication module is inserted via the large window in the plastic supporting plate. The direction of insertion is not arbitrary. The module is held at its mounting bracket. The opposite end of the module is inserted with the same orientation in the window opening, under the supporting plate and any existing extension I/O. The module bracket is turned towards the Ethernet module locking latch at the supporting plate. Thus, even the longest connection elements of the communication module can be moved in this space between the lower supporting plate reinforcement and the locking latch in the direction of the transformer module. The mounting bracket of the module is now drawn up to the stop in the direction of the lower supporting plate reinforcement. Thus, the 60-pin plug connector on the module and the basic I/O board are aligned on top of each other. The alignment has to be checked via the opening at the bottom of the rack. Attach the module's mounting rail from the back side of the basic I/O using 2 M 2.5 screws. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 321 Mounting and Commissioning 3.1 Mounting and Connections [com-modul-20071107, 1, --_--] Figure 3-9 Installation of a SIPROTEC 4 communication module The device can now be reassembled again (see Section Reassembly). 3.1.2.5 Reassembly The reassembly of the device is performed in the following steps: Carefully insert the complete electronics block into the housing. Please observe the following: The connections of the communication modules point at the bottom of the housing. If there is no communication module, orient yourself to the connections for the current terminal. These connections are located on the side of the printed circuit board pointing at the device bottom. Insert the electronics block into the housing, until the supporting part rests against the front edge of the housing. Press the left housing wall slightly out and insert the electronics block carefully further into the housing. When the front edge of the housing and the inside of the front plate touch, center the front plate by carful lateral movements. This makes sure that the front plate encloses/surrounds the housing. The electronics block can only be inserted centered up to the end stop. 322 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections [einschub-mit-stuetz-20100716, 1, --_--] Figure 3-10 Reassembly of Device Fix the front cover to the housing with the two medium screws at the top and bottom of the front cover. The two covers can be inserted again either now or after the reinstallation of the device. Now install the device in accordance with the Sections Panel Flush Mounting, Panel Surface Mounting or Cubicle Mounting. i NOTE Insert the current and voltage terminal blocks again and lock them in place! 3.1.3 Installation 3.1.3.1 General The 7SJ80 relay has a housing size 1/6. The housing has 2 covers and 4 fixing holes each at the top and bottom (see Figure 3-11 and Figure 3-12). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 323 Mounting and Commissioning 3.1 Mounting and Connections [front-7sj80-mit-abdeckungen-20071107, 1, --_--] Figure 3-11 Housing with covers [front-7sj80-ohne-abdeckungen-20071107, 1, --_--] Figure 3-12 3.1.3.2 Housing with fixing holes (without covers) Panel Flush Mounting The housing (housing size 1/6) has 2 covers and 4 fixing holes. 324 * Remove the 2 covers at the top and bottom of the front cover. Thus, 4 elongated holes are revealed in the mounting bracket and can be accessed. * Insert the device into the panel cut-out and fasten it with four screws. For dimensional drawings, refer to Section 4.25 Dimensions. * Mount the 2 covers again. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections * Connect a solid low-ohmic protective and operational ground to the grounding terminal of the device. The cross-section of the cable used must correspond to the maximum connected cross-section but must be at least 2.5 mm2 (Grounding area > M4, grounding area to be lacquer-free). * Connections are to be established via the screw terminals on the rear panel of the device in accordance with the circuit diagram. The details on the connection technique for the communication modules at the bottom of the device (port A and port B) in accordance with the SIPROTEC 4 System Description and the details on the connection technique for the current and voltage terminals on the rear of the device in the Sections "Connections of the Current Terminals" and "Connections of the Voltage Terminals" must be strictly observed. [schalttafeleinbau-7sj80-1-6tel-gehaeuse-20070107, 1, en_US] Figure 3-13 3.1.3.3 Panel flush mounting of a 7SJ80 Cubicle Mounting To install the device in a rack or cubicle, two mounting brackets are required. The ordering codes are stated in Appendix, Section A Ordering Information and Accessories. The housing (housing size 1/6) has 2 covers and 4 fixing holes. * * Loosely screw the two angle rails into the rack or cubicle with 4 screws each. * * * * Secure the device to the angle rails with 4 screws. * Remove the 2 covers at the top and bottom of the front cover. Thus, 4 elongated holes are revealed in the mounting bracket and can be accessed. Mount the 2 covers again. Tighten the 8 screws of the the angle rails in the rack or cubicle. Connect a solid low-ohmic protective and operational ground to the grounding terminal of the device. The cross-section of the cable used must correspond to the maximum connected cross-section but must be at least 2.5 mm2 (Grounding area > M4, grounding area to be lacquer-free). Connections are to be established via the screw terminals at the rear panel of the device in accordance with the circuit diagram. The details on the connection technique for the communication modules on the bottom of the device (port A and port B) in accordance with the SIPROTEC 4 System Description and the details on the connection technique for the current and voltage terminals at the rear of the device in the Sections "Connections of the Current Terminals" and "Connections of the Voltage Terminals" must be strictly observed. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 325 Mounting and Commissioning 3.1 Mounting and Connections [montage-7sj8x-einsechstel-gehaeuse-20070117, 1, en_US] Figure 3-14 3.1.3.4 Example installation of a 7SJ80 in a rack or cubicle Panel Surface Mounting When ordering the device as surface-mounting case (9th digit of the ordering number= B), the mounting frame shown below is part of the scope of delivery. For installation, proceed as follows: * Drill the holes for the mounting frame into the control panel. 326 * Fasten the mounting frame with 4 screws to the control panel (the continuously open side of the mounting frame is intended for the cable harnesses and can point at the top or bottom according to customer specification). * * Loosen the terminal blocks for the wiring, wire the terminal blocks and then click them in again. * Connections are to be established via the screw terminals on the rear panel of the device in accordance with the circuit diagram. The details on the connection technique for the communication modules at the bottom of the device (port A and port B) in accordance with the SIPROTEC 4 System Description and the details on the connection technique for the current and voltage terminals on the rear of the device in the Sections "Connections of the Current Terminals" and "Connections of the Voltage Terminals" must be strictly observed. * * Insert the device into the mounting frame (make sure that no cables are jammed). Connect a solid low-ohmic protective and operational ground to the grounding terminal of the device. The cross-section of the cable used must correspond to the maximum connected cross-section but must be at least 2.5 mm2 (Grounding area > M4, grounding area to be lacquer-free). Secure the device to the mounting frame with 4 screws. For dimensional drawings, refer to the Technical Data, Section 4.25 Dimensions. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.1 Mounting and Connections [montagehalterung-20070116, 1, en_US] Figure 3-15 Mounting rails for panel surface mounting SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 327 Mounting and Commissioning 3.2 Checking Connections 3.2 Checking Connections 3.2.1 Checking the Data Connections of the Interfaces Pin Assignment The following tables show the pin assignment of the various interfaces. The position of the connections can be seen in the following figures. [usb-schnittst-auf-geraetefrontseite-20070111, 1, en_US] Figure 3-16 USB interface [ethernet-anschlussbuchsen-101103-kn, 1, en_US] Figure 3-17 Ethernet connections at the device bottom [dsub-buchsen-20070111, 1, en_US] Figure 3-18 Serial interface at the device bottom USB Interface The USB interface can be used to establish a connection between the protection device and your PC. For the communication, the Microsoft Windows USB driver is used which is installed together with DIGSI (as of version V4.82). The interface is installed as a virtual serial COM port. We recommend the use of standard USB cables with a maximum length of 5 m/16 ft. 328 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.2 Checking Connections Table 3-2 Assignment of the USB socket Pin-No. 1 2 3 4 Housing USB VBUS (unused) D- D+ GND Shield Connections at port A If the interface is used for communication with the device, the data connection is to be checked. Table 3-3 Assignment of the port A socket Pin-No. Ethernet interface 1 Tx+ 2 Tx- 3 Rx+ 4 -- 5 -- 6 Rx- 7 -- 8 -- Connections at port B When a serial interface of the device is connected to a control center, the data connection must be checked. A visual check of the assignment of the transmit and receive channels is important. With RS232 and fiber optic interfaces, each connection is dedicated to one transmission direction. For that reason the data output of one device must be connected to the data input of the other device and vice versa. Table 3-4 Pin-No. RS232 Belegung der Buchsen Port B RS485 Profibus DP, RS485 Modbus RS485 DNP3.0 RS485 1 Shield (electrically connected with shield shroud) 2 RxD - - Ethernet EN 100 IEC 60870-5-103 redundant Tx+ B/B' (RxD/TxD-P) - Tx- A/A' (RxD/TxD-N) 3 TxD A/A' (RxD/TxD-N) B/B' (RxD/TxD-P) A Rx+ - 4 - - CNTR-A (TTL) RTS (TTL level) -- - 5 GND C/C' (GND) C/C' (GND) GND1 -- - 6 - - +5 V ((max. load <100 mA) VCC1 Rx- - 7 RTS - 1) - - -- - 8 CTS B/B' (RxD/TxD-P) A/A' (RxD/TxD-N) B -- - 9 - - - - not available not available 1) Pin 7 also carries the RTS signal with RS232 level when operated as RS485 interface. Pin 7 must therefore not be connected! With data cables, the connections are designated according to DIN 66020 and ISO 2110: * TxD = Data output * * * * RxD = Data input RTS = Request to send CTS = Clear to send GND = Signal/Chassis Ground SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 329 Mounting and Commissioning 3.2 Checking Connections The cable shield is to be grounded at both ends. For extremely EMC-prone environments, the GND may be connected via a separate individually shielded wire pair to improve immunity to interference. Fiber-optic Cables ! WARNING Laser Radiation! Class 1 Do not look directly into the fiber-optic elements! Signals transmitted via optical fibers are unaffected by interference. The fibers guarantee electrical isolation between the connections. Transmit and receive connections are represented by symbols. The standard setting of the character idle state for the optical fiber 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 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 should perform the inspection steps. CAUTION Take care when operating the device without a battery on a battery charger. Non-observance of the following measures 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 Device Data). If undervoltage protection is configured and enabled in the device and if, at the same time, the current criterion is disabled, the device picks up right after auxiliary voltage has been connected, since no measuring voltage is available. To make the device configurable, pickup is to be stopped, i.e. the measuring voltage is connected or voltage protection is blocked. This can be performed by operation. 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 to avoid condensation. Connections are checked with the device at its final location. The plant must first be switched off and grounded. Proceed as follows for checking the system connections: 330 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.2 Checking Connections * * Circuit breakers for the auxiliary power supply and the measuring voltage must be opened. Check the continuity of all current and voltage transformer connections against the system and connection diagrams: - Are the current transformers grounded properly? - Are the polarities of the current transformer connections the same? - Is the phase assignment of the current transformers correct? - Are the voltage transformers grounded properly? - Are the polarities of the voltage transformer connections the same and correct? - Is the phase assignment of the voltage transformers correct? - Is the polarity for the current input N, Ns (if used)? - Is the polarity for the voltage input V3 correct (if used e.g. for broken delta winding or busbar voltage)? * If test switches are used for the secondary testing of the device, their functions must also be checked, in particular that in the "Check" position the current transformer secondary lines are automatically shortcircuited * 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 current input should correspond to the power input in neutral position of the device. The measured steady state current should be insignificant. 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 protective switches for the voltage transformers and the power supply. Check the trip and close circuits to the power system circuit breakers. Verify that the control wiring to and from other devices is correct. Check the signaling connections. Switch the mcb back on. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 331 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 grounded at the protective conductor terminal. Hazardous voltages can exist in all switchgear components connected to the power supply and to measurement 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 switching off the auxiliary voltage, wait a minimum of 10 seconds before reconnecting this voltage so that steady conditions can be established. The limit values given in Technical Data (Chapter 4) must not be exceeded, neither during testing nor during commissioning. When testing the device with secondary test equipment, make sure that no other measurement quantities are connected and that the trip and close circuits to the circuit breakers and other primary switches are disconnected from the device. ! 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. Switching operations have to be carried out during commissioning. A prerequisite for the prescribed tests is that these switching operations can be executed without danger. They are accordingly not intended for operational checks. ! WARNING Warning of dangers evolving from improper primary tests Non-observance of the following measures can result in death, personal injury or substantial property damage. 332 Primary tests are only allowed to be carried out by qualified personnel, who are familiar with the commissioning of protection systems, the operation of the plant and the safety rules and regulations (switching, grounding, etc.). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning 3.3.1 Test Mode and Transmission Block Activation and Deactivation If the device is connected to a central or main computer system via the SCADA interface, then the information that is transmitted can be influenced. This is only possible with some of the protocols available (see Table "Protocol- dependent functions" in the Appendix E.6 Protocol-dependent Functions). If the test mode is switched on, the messages sent by a SIPROTEC 4 device to the main system has an additional test bit. This bit allows the messages to be recognized as not resulting from actual faults. Furthermore, it can be determined by activating the transmission block that no annunciations are transmitted via the system interface during test mode. The SIPROTEC 4 System Manual describes in detail how to activate and deactivate the test mode and blocked data transmission. Please note that when DIGSI is being used for device editing, the program must be in the online operating mode for the test features to be used. 3.3.2 Testing the System Interface (at Port B) Prefacing Remarks If the device features a system interface and this is used to communicate with the control center, 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 "real" operation. ! DANGER Danger evolving from operating the equipment (e.g. circuit breakers, disconnectors) by means of the test function 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 test function during "real" operation by transmitting or receiving messages via the system interface. NOTE After termination of the system interface 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 screen. Double-click Generate Indications in the list view. The Generate Indications dialog box opens (see following figure). Structure of the Test Dialog Box In the column Indication the display texts of all indications are displayed which were allocated to the system interface in the matrix. In the column SETPOINT Status the user has to define the value for the messages to be tested. Depending on annunciation type, several input fields are offered (e.g. message ON / message OFF). By clicking on one of the fields you can select the desired value from the pull-down menu. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 333 Mounting and Commissioning 3.3 Commissioning [schnittstelle-testen-110402-wlk, 1, en_US] Figure 3-19 System interface test with the dialog box: Creating messages - example Changing the Operating State When clicking one of the buttons in the column Action for the first time, 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 on the corresponding line. The corresponding message is issued and can be read out either from the event log of the SIPROTEC 4 device or from the substation control system. As long as the window is open, further tests can be performed. Test in Message Direction For all information that is transmitted to the central station, test the options in the list which appears in SETPOINT Status: * Make sure that each checking process is carried out carefully without causing any danger (see above and refer to DANGER!) * Click on Send in the function to be tested and check whether the transmitted information reaches the central station and shows the desired reaction. Data which are normally linked via binary inputs (first character ">") are likewise indicated to the central power system with this procedure. The function of the binary inputs itself is tested separately. Exiting the Test Mode To end the System Interface Test, click on Close. The device is briefly out of service while the start-up routine is executed. The dialog box closes. Test in Command Direction The information transmitted in command direction must be indicated by the central station. Check whether the reaction is correct. 3.3.3 Configuring Communication Modules Required Settings in DIGSI 4 The following applies in general: 334 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning In the case of a first-time installation or replacement of a communication module, the ordering number (MLFB) does not need to be changed. The ordering number can be retained. Thus, all previously created parameter sets remain valid for the device. Changes in the DIGSI Manager In order that the protection device can access the new communication module, a change has to be made in the parameter set within the DIGSI Manager. Select the SIPROTEC device in DIGSI 4 Manager project and choose the menu entry Edit > Object Properties to open the dialog Properties - SIPROTEC 4 Device (see the following figure). Select an Interfac for 11. Port B (on back of device bottom) and for 12. Port A (on front of device bottom) in the properties box Communications modules. For Profibus DP, Modbus or DNP3.0, the entry additional Protocols, see MLFB Ext L has to be selected. For port B, click L... and select the type of communication protocol in the dialog Additional information [sx80-komm-prot-l-071112, 1, en_US] Figure 3-20 DIGSI 4.3: Profibus DP protocol selection (example) Mapping File For Profibus DP, Modbus, DNP3.0 and VDEW Redundant, a matching bus mapping has to be selected. For the selection of the mapping file please open the SIPROTEC device in DIGSI and choose Settings > Interfaces (see Figure 3-21). The dialog Interface Settings shows under Additional protocols at device the following: * Display of the selected communication module * Selection Mapping file, listing all Profibus DP, Modbus, DNP3.0 and VDEW Redundant mapping files available for the respective device type, with their names and reference to the corresponding bus mapping document * Edit field Module-specific settings for changing the bus-specific parameters SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 335 Mounting and Commissioning 3.3 Commissioning [auswahl-mapping-071122, 1, en_US] Figure 3-21 i DIGSI 4.3: Selection of a mapping file and setting of bus-specific parameters NOTE If the mapping file assignment for a SIPROTEC device has been changed, this is usually connected with a change of the allocations of the SIPROTEC objects to the system interface. After having selected a new mapping file, please check the allocations to "Target system interface" or "Source system interface" in the DIGSI allocation matrix. Edit Field "Module-specific settings" Change only the numbers in the lines not starting with "//" and observe the semicolon at the end of the lines in the field Module-specific settings. Further changes in the field might lead to an error message when closing the dialog box Interface settings. Select the bus mapping corresponding to your requirements. The documentation of the individual bus mappings is available on the Internet (www.siprotec.com in the download area). After having selected the bus mapping, the area of the mapping file in which you can make device-specific settings appears in the window (see Figure 3-22). The type of this setting depends of the protocol used and is described in the protocol documentation. Please only perform the described changes in the settings window and confirm your entries with "OK". 336 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning [modulspez-071122, 1, en_US] Figure 3-22 Module-specific settings Transfer the data to the protection device (see the following figure). [daten-uebertragen-071122, 1, en_US] Figure 3-23 Transmitting data SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 337 Mounting and Commissioning 3.3 Commissioning Terminal Test The system interface (EN 100) is preassigned with the default value zero and the module is thus set to DHCP mode. The IP address can be set in the DIGSI Manager (Object properties... / Communication parameters / System interface [Ethernet]). The Ethernet interface is preassigned with the following IP address and can be changed on the device at any time (DIGSI device processing / Parameters / Interfaces / Ethernet service): IP address: 192.168.100.10 Network mask: 255.255.255.0 The following restrictions must be observed: For subnet mask: 255.255.255.0 the IP bandwidth 192.168.64.xx is not available For subnet mask 255.255.255.0, the IP-Band 192.168.1.xx is not available For subnet mask: 255.255.0.0 the IP bandwidth 192.168.xx.xx is not available For subnet mask: 255.0.0.0 the IP band 192.xx.xx.xx is not available. 3.3.4 Checking the Status of Binary Inputs and 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 "real" operation. ! DANGER Danger evolving from operating the equipment (e.g. circuit breakers, disconnectors) by means of the test function 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 test function during real operation by transmitting or receiving messages via the system interface. NOTE After finishing the hardware tests, the device will reboot. Thereby, all annunciation buffers are erased. If required, these buffers should be read out with DIGSI and saved prior to the test. The hardware test can be 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 screen. Double-click in the list view on Hardware Test. The dialog box of the same name opens (see the following figure). Structure of the Test Dialog Box The dialog box is classified into three groups: BI for binary inputs, REL for output relays, and LED for lightemitting diodes. On the left of each of these groups is an accordingly labeled button. By double-clicking a button, information regarding the associated group can be shown or hidden. 338 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning In the column Status the present (physical) state of the hardware component is displayed. Indication is made by symbols. The physical actual states of the binary inputs and outputs are indicated by an open or closed switch symbol, the LEDs by a dark or illuminated LED symbol. The opposite state of each element is displayed in the column Scheduled. The display is made 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_US] Figure 3-24 Test of the binary inputs/outputs -- example Changing the Operating State To change the status of a hardware component, click on the associated button in the Scheduled column. Password No. 6 (if activated during configuration) will be requested before the first hardware modification is allowed. After entry of the correct password a status change will be executed. Further status changes remain possible while the dialog box is open. Test of the Output Relays Each individual output relay can be energized allowing to check the wiring between the output relay of the 7SJ80 and the system, without having to generate the message that is assigned to the relay. As soon as the first status change for any one 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 for example means that a switching 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: * Ensure that the switching of the output relay can be executed without danger (see above under DANGER!). * * Each output relay must be tested via the corresponding Scheduled-cell in the dialog box. Finish the testing (see margin title below "Exiting the Test Mode"), so that during further testings no unwanted switchings are initiated. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 339 Mounting and Commissioning 3.3 Commissioning Test of the Binary Inputs To test the wiring between the plant and the binary inputs of the 7SJ80 the condition in the plant which initiates the binary input must be generated and the response of the device checked. To do so, the dialog box Hardware Test must be opened again to view the physical state of the binary inputs. The password is not yet required. Proceed as follows in order to check the binary inputs: * Activate each of function in the system which causes a binary input to pick up. * Check the reaction in the Status column of the dialog box. To do so, the dialog box must be updated. The options may be found below under the margin heading "Updating the Display". * Finish the testing (see margin heading below "Exiting the Test Mode"). If ,however, the effect of a binary input must be checked without carrying out any switching in the plant, 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 plant and can only be activated via the hardware test function. Test of the LEDs The 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 As the Hardware Test dialog opens, the operating states of the hardware components which are current at this time are read in and displayed. An update is made: * for each hardware component, if a command to change the condition is successfully performed, * * for all hardware components if the Update button is clicked, for all hardware components with cyclical updating (cycle time is 20 seconds) if the Automatic Update (20sec) field is marked. Exiting the Test Mode To end the hardware test, click on Close. The dialog box is closed. The device becomes unavailable for a brief start-up period immediately after this. Then all hardware components are returned to the operating conditions determined by the plant settings. 3.3.5 Tests for Breaker Failure Protection General If the device provides a breaker failure protection and if this is used, the integration of this protection function in the system must be tested under practical conditions. Due to the variety of application options and the available system configurations, it is not possible to make a detailed description of the necessary tests. It is important to observe local conditions and protection and system drawings. Before starting the circuit breaker tests it is recommended to isolate the circuit breaker of the tested feeder at both ends, i.e. line isolators and busbar isolators should be open so that the breaker can be operated without risk. 340 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning ! 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. Therefore, primarily it is recommended to interrupt the tripping commands to the adjacent (busbar) breakers, e.g. by interrupting the corresponding pickup voltages. Before the breaker is finally closed 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 lists do not claim to be complete, they may also contain points which are to be ignored in the current application. 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 be started by external protection devices, the external start conditions must be checked. In order for the breaker failure protection to be started, a current must flow at least via the monitored phase. This may be a secondary injected current. * Start by trip command of the external protection: binary input functions >50BF ext SRC (FNo 1431) (in spontaneous or fault annunciations). * After every start, the message 50BF ext Pickup (FNo 1457) must appear in the spontaneous or fault annunciations. * After time expiration TRIP-Timer (address 7005) tripping command of the breaker failure protection. Switch off test current. If start is possible without current flow: * Closing the circuit breaker to be monitored to both sides with the disconnector switches open. * Start by trip command of the external protection: Binary input functions >50BF ext SRC (FNo 1431) (in spontaneous or fault annunciations). * After every start, the message 50BF ext Pickup (FNo 1457) must appear in the spontaneous or fault annunciations. * After time expiration TRIP-Timer (address 7005) tripping command of the breaker failure protection. Open the circuit breaker again. Busbar Tripping For testing the distribution of the trip commands in the substation in the case of breaker failures it is important to check that the trip commands to the adjacent circuit breakers are correct. 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. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 341 Mounting and Commissioning 3.3 Commissioning In particular with multiple busbars, the trip distribution logic for the adjacent circuit breakers must be checked. Here it should be checked 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. Termination 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. 3.3.6 Testing User-Defined Functions CFC Logic 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. Of course, general test procedures cannot be given. Configuration of these functions and the target conditions must be actually known beforehand and tested. Possible interlocking conditions of switching devices (circuit breakers, disconnectors, ground switch) are of particular importance. They must be observed and tested. 3.3.7 Current, Voltage, and Phase Rotation Testing Preliminary Remark i NOTE The voltage and phase rotation test is only relevant for devices with voltage transformers. 10 % of Load Current The connections of the current and voltage transformers are tested using primary quantities. Secondary 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. 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. Current and Voltage Values Currents and voltages can be seen in the display field on the front of the device or the operator interface via a PC. They can be compared to the quantities measured by an independent source, 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 209 PHASE SEQ.). If the phase rotation is incorrect, the alarm Fail Ph. Seq. (FNo 171) is generated. 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 measurement must then be repeated. 342 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning Voltage Transformer Miniature Circuit Breaker (VT mcb) The VT mcb of the feeder (if used) must be opened. 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 annunciations that the VT mcb trip was entered (annunciation >FAIL:FEEDER VT "ON" in the spontaneous annunciations). 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 messages appear under the spontaneous messages as "OFF", i.e. >FAIL:FEEDER VT "OFF". If one of the events does not appear, the connection and allocation of these signals must be checked. If the ON-state and OFF-state are swapped, the contact type (H-active or L-active) must be checked and remedied. 3.3.8 Test for High Impedance Protection Polarity of Transformers When the device is used for high-impedance protection, the current at N or Ns is equivalent to the fault current in the protected object. It is essential in this case that all current transformers feeding the resistor whose current is measured at N(S) have the same polarity. The test currents used for this are through currents. Each CT must be included in a measurement. The current at N(S) may never exceed half the pickup value of the single-phase time overcurrent protection. 3.3.9 Testing the Reverse Interlocking Scheme (only if used) Testing reverse interlocking is available if at least one of the binary inputs available is configured for this purpose (e.g. presetting of binary input BI1 >BLOCK 50-2 and >BLOCK 50N-2 to open circuit system). Tests can be performed with phase currents or ground current. For ground current the corresponding ground current settings apply. Please note that the blocking function can either be configured for the pickup current connected (open circuit system) or the pickup current missing (closed circuit system). For open circuit system the following tests are to be proceeded: The feeder protection relays of all associated feeders must be in operation. At the beginning no auxiliary voltage is fed to the reverse interlocking system. A test current higher than the pickup values of 50-2 PICKUP and 50-1 PICKUP or 51 PICKUP is set. As a result of the missing blocking signal, the protection function trips after (short) time delay 50-2 DELAY. ! CAUTION Tests with currents that exceed more than 4 times the nominal device current cause an overload of the input circuits. Perform test only for a short time (see Technical Data, Section 4.1 General Device Data). Afterwards the device has to cool off ! The direct voltage for reverse interlocking is now switched on to the line. The precedent test is repeated, the result will be the same. Subsequently, at each of the protection devices of the feeders, a pickup is simulated. Meanwhile, another fault is simulated for the protection function of the infeed, as described before. Tripping is performed within time 50-1 DELAY (longer time period) (with definite time overcurrent protection) or according to characteristic (with inverse time overcurrent protection). These tests also check the proper functioning of the wiring for reverse interlocking. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 343 Mounting and Commissioning 3.3 Commissioning 3.3.10 Direction Check with Load Current Preliminary Remark i NOTE The direction check is only relevant for devices with voltage transformers. 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 * Nom. 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 any 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 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_US] Figure 3-25 Apparent Load Power All signs of powers may be inverted deliberately. Check whether polarity is inverted in address 1108 P,Q sign in the P.System Data 2. In that case the signs for active and reactive power are inverse as well. The power measurement provides an initial indication as to whether the measured values have the correct polarity. If both the active power and the reactive power have the wrong sign and 1108 P,Q sign is set to not reversed, the polarity according to address 201 CT Starpoint must be checked and corrected. However, power measurement itself is not able to detect all connection errors. For this reason, directional messages should be generated by means of the directional overcurrent protection. Therefore, pickup thresholds must be reduced so that the available load current causes a continuous pickup of the element. The direction reported in the messages, such as Phase A forward or Phase A reverse must correspond to the actual power flow. Be careful that the "Forward" direction of the protective element is in the direction of the line (or object to be protected). This is not necessarily identical with the direction of the normal the power flow. For all three phases, the directional messages to the power flow must be reported properly. If all directions differ from each other, individual phases in current or voltage transformer connections are interchanged, not connected properly or phase assignment is incorrect. After isolation of the line and shortcircuiting of the current transformers the connections must be checked and corrected. The measurements must then be repeated. Finally, switch off the protected power line. 344 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning i NOTE Reset the pickup values changed for the check to valid values. 3.3.11 Polarity Check for Voltage Input V3 Depending on the application of the voltage measuring input V3 of a 7SJ80, a polarity check may be necessary. If no measuring voltage is connected to this input, this section is irrelevant. If input V3 is used for the measurement of the displacement voltage VN (Power System Data 1 address 213 VT Connect. 3ph = Vab, Vbc, VGnd), the polarity is checked together with the current input N/Ns (see further below). If the input V3 is used for measuring a voltage for synchrocheck (Power System Data 1, address 213 VT Connect. 3ph = Vab, Vbc, VSyn or Vph-g, VSyn), the following is to be observed: * * The single-phase voltage V2 to be synchronized must be connected to input V3. The correct polarity is to be checked as follows using the synchrocheck function: The device must provide the synchrocheck function which is to be configured in address 161 = 25 Function 1 = SYNCHROCHECK. The voltage V2 to be synchronized must be set correctly in address 6123 CONNECTIONof V2. If a transformer is located between the measuring points of the reference voltage V1 and the voltage to be synchronized V2, its phase rotation must be taken into consideration. For this purpose, a corresponding angle is entered in address 6122 ANGLE ADJUSTM., in the direction of the busbar seen from the feeder. An example is shown in Section 2.20 Synchrocheck. If necessary different transformation ratios of the transformers on the busbar and the feeder may have to be considered under address Balancing V1/V2. The synchrocheck function must be activated at address 6101 Synchronizing = ON. A further aid for checking the connections are the messages 170.2090 25 V2>V1, 170.2091 25 V2<V1, 170.2094 25 2>1 and 170.2095 25 2<1 in the spontaneous messages. * Circuit breaker is open. The feeder is de-energized. The circuit breakers of both voltage transformer circuits must be closed. * For the synchrocheck, the program Direct CO is set to YES (address 6110); the other programs (addresses 6107 to 6109) are set to NO. * Via a binary input (170.0043 >25 Sync requ.) a measurement request is entered. The synchrocheck must release closing (message 170.0049 25 CloseRelease). If not, check all relevant parameters again (synchrocheck configured and enabled correctly, see Sections 2.1.1 Functional Scope and 2.20 Synchrocheck). * * Set address 6110 Direct CO to NO. * * For the synchrocheck, the program 25 Function 1 is set to SYNCHROCHECK (address 161) Then the circuit breaker is closed while the line isolator is open (see Figure 3-26). Thus, both voltage transformers receive the same voltage. Via a binary input (170.0043 >25 Sync requ.) a measurement request is entered. The synchrocheck must release closing (message 170.0049 25 CloseRelease). SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 345 Mounting and Commissioning 3.3 Commissioning * If not, first check whether one of the aforesaid messages 170.2090 25 V2>V1 or 170.2091 25 V2<V1 or 170.2094 25 2>1 or 170.2095 25 2<1 is available in the spontaneous messages. The message 25 V2>V1 or 25 V2<V1 indicates that the magnitude adaption is incorrect. Check address 6121 Balancing V1/V2 and recalculate the adaptation factor. The message 25 2>1 or 25 2<1 indicates that the phase relation of the busbar voltage does not match the setting under address CONNECTIONof V2 (see Section 2.20 Synchrocheck). When measuring via a transformer, address 6122 ANGLE ADJUSTM. must also be checked; this must adapt the vector group. If these are correct, there is probably a reverse polarity of the voltage transformer terminals for V1. * * * * * * For the synchrocheck, the program SYNC V1>V2< is set to YES (address 6108) Open the VT mcb of the busbar voltage. Via a binary input (170.0043 >25 Sync requ.) a measurement request is entered. There is no close release. If there is, the VT mcb for the busbar voltage is not allocated. Check whether this is the required state, alternatively check the binary input >FAIL: BUS VT (6510). Close the VT mcb of the busbar voltage again. Open the circuit breaker. For the synchrocheck, the program SYNC V1<V2>is set to YES (address 6107) and SYNC V1>V2< is set to NO (address 6108). * Via a binary input (170.0043 >25 Sync requ.) a measurement request is entered. The synchrocheck must release closing (message 170.0049 25 CloseRelease). Otherwise check all voltage connections and the corresponding parameters again thoroughly as described in Section2.20 Synchrocheck. * * Open the VT mcb of the feeder voltage. * Via a binary input (170.0043 >25 Sync requ.) a measurement request is entered. No close release is given. Close the VT mcb of the busbar voltage again. Addresses 6107 to 6110 must 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. [messspan-synch-kontr-20070716, 1, en_US] Figure 3-26 346 Measuring voltages for synchrocheck SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning 3.3.12 Ground Fault Check Ungrounded Systems The ground fault check is only necessary if the device is connected to an isolated or resonant-grounded system and the ground fault detection is applied. The device must thus have been preset during configuration of the device functions to Sens. Gnd Fault = Enabled (address 131). In all other cases, this section is irrelevant. Ground fault direction detection only works with devices in which the 15th digit of the is B or C. If none of this is the case, this section is not relevant. Determination of the ground fault direction only works in devices that have an B or C in the 15th position of their MLFB number. The primary check serves to find out the correct polarity of the transformer connections for the determination of the ground fault direction. ! 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 grounded equipment of the power system ! Using the primary ground fault method a most reliable test result is guaranteed. Therefore please proceed as follows: * Isolate the line and ground it on both ends. During the whole testing procedure the line must be open at the remote end. * Make a test connection between a single phase and ground. On overhead lines it can be connected anywhere, however, it must be located behind the current transformers (looking from the busbar of the feeder to be checked). Cables are grounded on the remote end (sealing end). * * * * Remove the protective grounding of the line. Connect a circuit breaker to the line end that is to be tested. Check the direction indication (LED if allocated) The faulty phase (FNo 1272 for A or 1273 for B or 1274 for C) and the direction of the line, i.e. SensGnd Forward (FNo 1276) must be indicated in the ground fault protocol. * The active and reactive components of the ground current are also indicated (INs Reac, FNo. 702). The reactive current INs Real, FNo. 701) is the most relevant for isolated systems. If the display shows the message SensGnd Reverse (FNo. 1277), either the current or voltage transformer terminals are swapped in the neutral path. If message SensGnd undef. (FNo 1278) appears, the ground current may be too low. * Deenergize and ground the line. The test is then finished. 3.3.13 Polarity Check for Current Input E General If the standard connection of the device is used with current input N connected in the neutral point of the set of current transformers (see also connection circuit diagram in Appendix C Connection Examples), then the correct polarity of the ground current path usually occurs automatically. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 347 Mounting and Commissioning 3.3 Commissioning If, however, current N is derived from a separate summation CT (see e.g. a connection circuit diagram in the Appendix C Connection Examples), an additional direction check with this current is necessary. If the device features the sensitive current input for N and if it is used in an isolated or resonant-grounded system, the polarity check for N was already carried out with the ground fault check according to the previous section. Then this section is not relevant. Otherwise the test is done with a disconnected trip circuit and primary load current. It must be noted that during all simulations that do not exactly correspond with situations that may occur in practice, the nonsymmetry of measured values may cause the measured value monitoring to pick up. This 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. Directional Testing for Grounded Systems The check can either be carried out with function "directional ground fault protection" (address 116) or with the function "ground fault detection" (address 131), which can be operated as additional fault protection. In the following the check is described using the "directional ground fault protection" function (address 116) as an example. To generate a displacement voltage, the e-n winding of one phase in the voltage transformer set (e.g. A) is bypassed (see Figure 3-27). If no connection on the e-n windings of the voltage transformer is provided, the corresponding phase is disconnected on the secondary side (see Figure 3-28). Only the current of the transformer which is not provided with voltage in its voltage path is fed into the current path. If the line carries resistive- inductive load, the protection is subject to the same conditions as exist during a ground fault in line direction. The directional ground fault protection must be configured to enabled and activated (address 116 or 131). Its pickup threshold must be below the load current of the line; if necessary the pickup threshold must be reduced. The parameters that have been changed, must be noted. After switching the line on and off again, the direction indication must be checked: In the fault log the messages 67N picked up and Ground forward must at least be present. If the directional pickup is not present, either the ground 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 ground 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. If the pickup message is missing, the measured ground (residual) current or the displacement voltage emerged may be too small. This can be checked via operational measured values. Important! If parameters were changed for this test, they must be returned to their original state after completion of the test ! 348 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning [polaritaetspruefung-ie-mituen-gemessen, 1, en_US] Figure 3-27 Polarity testing for N, example with current transformers configured in a Holmgreen-connection (VTs with broken delta connection -- e-n winding) [polaritaetspruefung-ie-mituen-berechnet-211002-kn, 1, en_US] Figure 3-28 Polarity testing for N, example with current transformers configured in a Holmgreen-connection (VTs Wye-connected) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 349 Mounting and Commissioning 3.3 Commissioning 3.3.14 Trip/Close Tests for the Configured Operating Devices Control 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 circuit breaker position injected via binary inputs is read out at the device and compared with the actual breaker position. For devices with graphic display this is easy to do with the control display. The switching procedure is described in the SIPROTEC 4 System Description. The switching authority must be set according to the command source used. The switching mode can be selected from interlocked and noninterlocked switching. Please note that non-interlocked switching can be a safety hazard. Control by Protective Functions For OPEN-commands sent to the circuit breaker please take into consideration that if the internal or external automatic reclosure function is used a TRIP-CLOSE test cycle is initiated. ! DANGER A test cycle successfully started by the automatic reclosure function can lead to the closing of the circuit breaker ! Non-observance of the following statement will result in death, severe personal injury or substantial property damage. Be fully aware that OPEN-commands sent to the circuit breaker can result in a trip-close-trip event of the circuit breaker by an external reclosing device. Control from a Remote Control Center If the device is connected to a remote substation via a system 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. 3.3.15 Creating Oscillographic Recordings for Tests General In order to be able to test the stability of the protection during switchon procedures also, switchon trials can also be carried out at the end. Oscillographic records obtain the maximum information about the behaviour of the protection. Requirements To be able to trip an oscillographic recording, parameter Osc Fault Rec. must be configured to Enabled in the Functional Scope. Apart from the capability of storing fault recordings via pickup of the protection function, the 7SJ80 also has the capability of initiating a measured value recording via the operator program DIGSI, the serial interface or binary input. In the latter case, the information >Trig.Wave.Cap. must be allocated to a binary input. Triggering for the oscillographic recording then occurs, for instance, via the binary input when the protection object is energized. Those that are externally triggered (that is, without a protective element pickup) are processed by the device as a normal oscillographic record. For each oscillographic record a fault record is created which is given its individual number to ensure that assignment can be made properly. However, these recordings are not displayed in the fault indication buffer, as they are not fault events. 350 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Mounting and Commissioning 3.3 Commissioning Triggering Oscillographic Recording To trigger test measurement recording with DIGSI, click on Test in the left part of the window. Double click the entry Test Wave Form in the list of the window. [digsi-fenster-testmessschrieb-starten-260602-kn, 1, en_US] Figure 3-29 Start oscillographic recording with DIGSI Oscillographic recording is started immediately. During recording, a report is given in the left part of the status bar. Bar segments additionally indicate the progress of the procedure. The SIGRA or the Comtrade Viewer program is required to view and analyse the oscillographic data. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 351 Mounting and Commissioning 3.4 Final Preparation of the Device 3.4 Final Preparation of the Device Firmly tighten all screws. Tighten all terminal screws, including those that are not used. ! CAUTION Inadmissable Tightening Torques Non-observance of the following measure can result in minor personal injury or property damage. The tightening torques must not be exceeded as the threads and terminal chambers may otherwise be damaged! The settings should be checked again, if they were changed during the tests. Check if all protection, control and auxiliary functions to be found with the configuration parameters are set correctly (Section 2.1.1 Functional Scope, Functional Scope) and all desired functions are set to ON. Keep a copy of all setting values on a PC. The device-internal clock should be checked and set, if necessary. The annunciation buffers are deleted under MAIN MENU Annunciations Set/Reset, so that future information will only apply to actual events and states (see also SIPROTEC 4 System Description). The counters in the switching statistics should be reset to the values that were existing prior to the testing (see also SIPROTEC 4 System Description). Reset the counter of the operational measured values (e.g. operation counter, if available) under MAIN MENU Measured Values Reset (also see SIPROTEC 4 System Description). Press the ESC key (several times if necessary), to return to the default display. The default display appears in the display box (e.g. the display of operational measured values). Clear the LEDs on the front panel of the device by pressing the LED key, so that they show only real events and states in the future. In this context, also output relays probably memorized are reset. 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 pushed. Any LEDs that are lit after the clearing attempt are displaying actual conditions. 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. 352 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 4 Technical Data This chapter provides the technical data of the device SIPROTEC 7SJ80 and its individual functions, including the limit values that may not be exceeded under any circumstances. The electrical and functional data for the maximum functional scope are followed by the mechanical specifications with dimensioned drawings. 4.1 General Device Data 354 4.2 Definite-time Overcurrent Protection 363 4.3 Inverse-time Overcurrent Protection 365 4.4 Directional Overcurrent Protection 376 4.5 Inrush Restraint 378 4.6 Dynamic Cold Load Pickup 379 4.7 1-phase Overcurrent Protection 380 4.8 Voltage Protection 381 4.9 Negative Sequence Protection (definite-time characteristic) 383 4.10 Negative Sequence Protection (inverse-time characteristics) 384 4.11 Frequency Protection 81 O/U 390 4.12 Undervoltage-controlled reactive power protection (27/Q) 391 4.13 Thermal Overload Protection 393 4.14 Ground Fault Detection (Sensitive/Insensitive) 395 4.15 Intermittent Ground Fault Protection 401 4.16 Directional intermittent ground fault protection 402 4.17 Automatic Reclosing 403 4.18 Fault Locator 404 4.19 Breaker Failure Protection 50BF 405 4.20 Flexible Protection Functions 406 4.21 Synchrocheck 25 409 4.22 User-defined Functions (CFC) 411 4.23 Auxiliary Functions 416 4.24 Switching Device Control 421 4.25 Dimensions 422 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 353 Technical Data 4.1 General Device Data 4.1 General Device Data 4.1.1 Analog Inputs Current Inputs Nominal Frequency fNom 50 Hz or 60 Hz (adjustable) Operating range frequency (not dependent on the nominal frequency 25 Hz to 70 Hz Nominal current Nom 1 A or 5 A Ground current, sensitive Ns 1.6* Nom linear range 1) Burden per phase and ground path 0.05 VA 0.3 VA 0.05 VA 0.3 VA - at N = 1 A - at N = 5 A - for sensitive ground fault detection at 1 A - for sensitive ground fault detection at 5 A Load capacity current path - thermal (rms) 500 A for 1 s 150 A for 10 s 20 A continuous 1250 A (half-cycle) - dynamic (peak value) Load capacity input for sensitive ground fault detection Ns 1) - thermal (rms) 300 A for 1 s 100 A for 10 s 15 A continuous 750 A (half-cycle) - dynamic (peak value) 1) only in models with input for sensitive ground fault detection (see ordering data in the Appendix) Voltage Inputs Nominal voltage 34 V - 225 V (adjustable) for connection of phase-to-ground voltages 34 V - 200 V (adjustable) for connection of phase-to-phase voltages Measuring Range 0 V to 200 V Burden at 100 V approx. 0.005 VA Overload capacity in the voltage path - thermal (rms) 4.1.2 230 V continuous Auxiliary voltage Direct Voltage Voltage supply via an integrated converter 354 Nominal auxiliary DC voltage VAux DC 24 V to 48 V DC 60 V to 250 V Permissible voltage ranges DC 19 V to 60 V DC 48 V to 300 V Overvoltage category, IEC 60255-27 III AC ripple voltage peak to peak, IEC 60255-11 15 % of auxiliary voltage SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.1 General Device Data Power input Quiescent Energized 7SJ80 approx. 5 W approx. 12 W Bridging time for failure/short-circuit, IEC 60255- 50 ms at V 110 V 11 10 ms at V < 110 V Alternating Voltage Voltage supply via an integrated converter 4.1.3 Nominal auxiliary AC voltage VAux AC 115 V AC 230 V Permissible voltage ranges AC 92 V to 132 V AC 184 V to 265 V Overvoltage category, IEC 60255-27 III Power input (at AC 115 V/230 V) < 15 VA Bridging time for failure/short-circuit 10 ms at V = 115 V/230 V Binary Inputs and Outputs Binary Input Variant Quantity 7SJ801/803 3 (configurable) 7SJ802/804 7 (configurable) 7SJ807/808 11 (configurable) Nominal direct voltage range 24 V to 250 V Current input, energized (independent of the control voltage) approx. 0.4 mA Pickup time Response Time of the binary output after trigger signal via binary input approx. 3 ms approx. 9 ms Dropout time Response Time of the binary output after trigger signal via binary input approx. 4 ms approx. 5 ms Secured switching thresholds (adjustable) for nominal voltages DC 24 V to 125 V V high > DC 19 V V low < DC 10 V for nominal voltages DC 110 V to 250 V V high > DC 88 V V low < DC 44 V for nominal voltages DC 220 V and 250 V V high > DC 176 V V low < DC 88 V Maximum permissible voltage DC 300 V Input interference suppression DC 220 V across 220 nF Output Relays Signal/command Relay, Alarm Relay Quantity and data depending on the order variant (allocatable) Order variant NO contact NO/NC selectable 7SJ801/803/807/808 3 2 (+ 1 life contact not allocatable) 7SJ802/804 6 2 (+ 1 life contact not allocatable) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 355 Technical Data 4.1 General Device Data Switching Capability MAKE 1000 W / 1000 VA Switching capability BREAK 40 W or 30 VA at L/R 40 ms Switching voltage AC and DC 250 V Admissible current per contact (continuous) 5A Permissible current per contact (close and hold) Interference supporession capacitor at the relay outputs 2.2 nF, 250 V, ceramic 4.1.4 30 A for 1 s (NO contact) Frequency Impedance 50 Hz 1.4* 106 20 % 60 Hz 1.2* 106 20 % Communication Interfaces User Interface Terminal Front side, non-isolated, USB type B socket for connecting a personal computer Operation from DIGSI V4.82 via USB 2.0 full speed (PELV) Operation with DIGSI Transmission speed up to 12 Mbit/s max. Bridgeable distance 5m Port A Ethernet electrical for DIGSI or SICAM I/O Unit 7XV5673 Operation with DIGSI Terminal Front case bottom, mounting location "A", RJ45 socket 100BaseT according to IEEE802.3 LED yellow: 10-/100 MBit/s (on/off) LED green: connection/no connection (on/off) Test voltage (PELV) 500 V; 50 Hz Transmission speed 10/100 MBit/s Bridgeable distance 20 m Port B IEC 60870-5-103 single RS232/RS485/FO depending on the order variant Isolated interface for data transfer to a control center RS232 Terminal Back case bottom, mounting location "B", 9- pin DSUB socket Test voltage (PELV) 500 V; 50 Hz Transmission speed min. 1,200 Bd, max. 115,000 Bd; factory setting 9,600 Bd Bridgeable distance 15 m RS485 356 Terminal Back case bottom, mounting location "B", 9- pin DSUB socket Test voltage (PELV) 500 V; 50 Hz SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.1 General Device Data Transmission speed min. 1,200 Bd, max. 115,000 Bd; factory setting 9,600 Bd Bridgeable distance max. 1 km Fiber optic cable (FO) FO connector type ST connector Terminal Back case bottom, mounting location "B" Optical wavelength = 820 nm Laser Class 1 according to EN 60825-1/-2 When using glass fiber 50 m/125 m or glass fiber 62.5 m/125 m Permissible optical signal attenuation max. 8 dB, with glass fiber 62.5/125 m Bridgeable distance max. 1.5 km Character idle state Configurable; factory setting "Light off" IEC 60870-5-103 redundant, RS485 Isolated interface for data transfer to a control center Terminal Back case bottom, mounting location "B", RJ45 socket Test voltage (PELV) 500 V; 50 Hz Transmission speed min. 2,400 Bd, max. 57,600 Bd; factory setting 19,200 Bd Bridgeable distance max. 1 km Profibus RS485 (DP) Terminal Back case bottom, mounting location "B", 9- pin DSUB socket Test voltage (PELV) 500 V; 50 Hz Transmission speed Up to 1.5 MBd Bridgeable distance 1 000 m (3 300 ft) at 93.75 kBd 500 m (1 600 ft) at 187.5 kBd 200 m (660 ft) at 1.5 MBd Profibus FO (DP) FO connector type ST connector Double ring Terminal Back case bottom, mounting location "B" Transmission speed up to 1.5 MBd Recommended: > 500 kBd with normal casing Optical wavelength = 820 nm Laser Class 1 according to EN 60825-1/-2 When using glass fiber 50/125 m or glass fiber 62.5/125 m Permissible optical signal attenuation max. 8 dB, with glass fiber 62.5/125 m Bridgeable distance max. 1.5 km DNP3.0 /MODBUS RS485 Terminal Back case bottom, mounting location "B", 9- pin DSUB socket Test voltage (PELV) 500 V; 50 Hz Transmission speed up to 19,200 Bd Bridgeable distance max. 1 km SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 357 Technical Data 4.1 General Device Data DNP3.0 /MODBUS FO FO connector type ST connector transmitter/receiver Terminal Back case bottom, mounting location "B" Transmission speed up to 19,200 Bd Optical wavelength = 820 nm Laser Class 1 according to EN 60825-1/-2 When using glass fiber 50 m/125 m or glass fiber 62.5/125 m Permissible optical signal attenuation max. 8 dB, with glass fiber 62.5/125 m Bridgeable distance max. 1.5 km Ethernet electrical (EN 100) for DIGSI, IEC61850, DNP3 TCP, Modbus TCP, IEC60870-5-104, PROFINET, SICAM I/O Unit 7XV5673 Terminal Back case bottom, mounting location "B", 2 x RJ45 socket 100BaseT according to IEEE802.3 Test voltage (with regard to the socket) (PELV) 500 V; 50 Hz Transmission speed 100 MBit/s Bridgeable distance 20 m Ethernet optical (EN 100) for DIGSI, IEC61850, DNP3 TCP, Modbus TCP, IEC60870-5-104, PROFINET, SICAM I/O Unit 7XV5673 4.1.5 Terminal Back case bottom, mounting location "B", Duplex-LC, 100BaseF according to IEEE802.3 Transmission speed 100 MBit/s Optical wavelength 1300 nm Bridgeable distance max. 2 km (1.24 mi) Electrical Tests Regulations Standards: IEC 60255 IEEE Std C37.90, see individual functions VDE 0435 for more standards see also individual functions Insulation Test Standards: IEC 60255-27 and IEC 60870-2-1 Voltage test (routine test) of all circuits except 2.5 kV, 50 Hz auxiliary voltage, binary inputs and communication ports 358 Voltage test (routine test) of auxiliary voltage and binary inputs DC 3.5 kV Voltage test (routine test) of isolated communication ports only (A and B) 500 V, 50 Hz Impulse voltage test (type test) of all process circuits (except for communication ports) against the internal electronics 6 kV (peak value); 1.2 s/50 s; 0.5 J; 3 positive and 3 negative impulses at intervals of 1 s SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.1 General Device Data Impulse voltage test (type test) of all process 5 kV (peak value); circuits against each other (except for communica- 1.2 s/50 s; 0.5 J; tion ports) and against the PE terminal of class III 3 positive and 3 negative impulses at intervals of 1 s EMC Tests for Immunity (Type Tests) Standards: IEC 60255-26, (product standard) IEC/EN 61000-6-2 VDE 0435 For more standards see also individual functions Immunity to damped oscillatory waves IEC 60255-22-1 IEC 61000-4-18 2.5 kV (Peak); 100 kHz and 1 MHz; = 15 ms; 400 Surges per s; Test duration 2 s; Ri = 200 Electrostatic discharge, Class IV EN 61000-6-2, IEC 60255-22-2 8 kV contact discharge; 15 kV air discharge, both polarities; 150 pF; Ri = 330 , rating criteria B Radio frequency electromagnetic field, amplitude-modulated, Class III EN 61000-6-2, IEC 60255-22-3 10 V/m; 80 MHz to 2.7 GHz 80 % AM; 1 kHz Fast transient bursts, Class IV EN 61000-6-2, IEC 60255-22-4 4 kV; 5 ns/50 ns; 5 kHz; 1 min. test length, rating criteria B High energy surge voltages (SURGE), Installation Class III, EN 61000-6-2, IEC 60255-22-5 Impulse: 1.2 s/50 s, rating criteria B Auxiliary voltage common mode: 4 kV; 12 ; 9 F diff. mode: 1 kV; 2 ; 18 F Measuring inputs, binary inputs and relay outputs common mode: 4 kV; 42 ; 0.5 F diff. mode: 1 kV; 42 ; 0.5 F Immunity to Conducted Disturbance by RF fields, injected Current EN 61000-6-2, IEC 60255-22-6 10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz; 27 Mhz and 68 MHz spot freq. Dwell time > 10 sec. Power system frequency magnetic field EN 61000-6-2, IEC 61000-4-8 30 A/m continuous; 300 A/m and 1000 V/m for 3 s; Radiated Electromagnetic Interference IEEE Std C37.90.2 20 V/m; 80 MHz to 1 GHz; 80 % AM; 1 kHz 35 V/m pulsed, 50% duty cycle 1 Hz rep. rate Power frequency on binary input ports IEC 60255-26, IEC 61000-4-16 Common mode Zone A and B: 300 Veff (220 , 0.47 F) Differential Mode Zone B: 100 Veff (100 , 0.047 F) testet with 3.9 K termination resistor Ripple on d.c. input power port inmunity test, IEC 61000-4-17 15 % of nominal auxiliary voltage Gradual shutdown / start-up for d.c. power supply IEC 60255-26 Shut-down ramp: 60 s Power off: 5 min. Start-up ramp: 60 s EMC Tests for Noise Emission (Type Test) Standard: SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 EN 61000-6-4 /01.07 + A1 EN 55011 /11.2009 + A1 class A 359 Technical Data 4.1 General Device Data Radio noise voltage to lines, only auxiliary voltage IEC/CISPR 16-2-1 150 kHz to 30 MHz Limit Class A Interference field strength IEC/CISPR 16-2-3 30 MHz bis 1000 MHz Limit Class A 1 GHz to 6 GHz Limit Class A Harmonic currents on the network lead at AC 230 V Device is to be assigned Class D (applies only to devices with > 50 VA power consumption) IEC 61000-3-2 Voltage dips, interruptions and fluctuations IEC 60255-11, IEC 61000-4-29 4.1.6 Tolerate Voltage interruptions < 60 ms for the nominal auxiliary voltage. Mechanical Tests Vibration and Shock Stress during Steady-State 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 bis 150 Hz: 1g acceleration frequency sweep rate 1 octave/min 20 cycles in 3 orthogonal axes. Shock IEC 60255-21-2, Class 1; IEC 60068-2-27 Semi-sinusoidal acceleration, duration 11 ms, each 3 shocks in both directions of the 3 axes Seismic Vibration IEC 60255-21-3, Class 2; IEC 60068-3-3 Sinusoidal 1 Hz to 8 Hz: 7,5 mm amplitude (horizontal axis) 1 Hz to 8 Hz: 3,5 mm amplitude (vertical axis) 8 Hz to 35 Hz: 2 g acceleration (horizontal axis) 8 Hz to 35 Hz: 1 g acceleration (vertical axis) Frequency sweep 1 octave/min 1 cycle in 3 orthogonal axes Vibration and Shock Stress during Transport 4.1.7 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, each 1000 shocks (in both directions of the 3 axes) Climatic Stress Tests Temperatures Standards: 360 IEC 60255-1, IEC 60068-2-1/2, IEC 60068-2-78, IEC 60068-2-30 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.1 General Device Data Type test (in acc. with IEC 60068-2-1 and -2, Test Bd for 16 h) -25 C to +85 C oder -13 F to +185 F Damp heat, steady state - Test Cab IEC 60255-1 and IEC 60068-2-78. 40 C, 93 % RH, 56 days Damp heat, cyclic - Test Db IEC 60255-1 and IEC 60068-2-30 25 C to/down 40 C in 3 hr., > 93 % RH, dwell time 9 hr. 6 cycles Permissible temporary operating temperature (tested for 96 h) -20 C to +70 C oder -4 F to +158 F (clearness of the display may be impaired from +55 C or +131 F) Recommended for permanent operation (in acc. with IEC 60255-6) -5 C to +55 C or +23 F to +131 F Limit temperatures for storage -25 C to +55 C or -13 F to +131 F Limit temperatures for transport -25 C to +70 C or -13 F to +158 F Storage and transport with factory packaging Humidity Permissible humidity Mean value per year 75 % relative humidity; on 56 days of the year up to 93 % relative humidity; condensation must be avoided! Siemens recommends that all devices be installed such that they are not exposed to direct sunlight, nor subject to large fluctuations in temperature that may cause condensation to occur. 4.1.8 Service Conditions The protective device is designed for use in an industrial environment and an electrical utility environment. Proper installation procedures should be followed to ensure electromagnetic compatibility (EMC). In addition, the following is recommended: * All contacts and relays that operate in the same cubicle, cabinet, or relay panel as the numerical protective device should, as a rule, be equipped with suitable surge suppression components. For substations with operating voltages of 100 kV and above, all external cables should be shielded with * a conductive shield grounded at both ends. For substations with lower operating voltages, no special measures are normally required. * Do not withdraw or insert individual modules or boards while the protective device is energized. In withdrawn condition, some components are electrostatically endangered; during handling the ESD standards (for Electrostatic Sensitive Devices) must be observed. They are not endangered when inserted into the case. 4.1.9 Constructive Design Case 7XP20 Dimensions see dimensional drawings, Section 4.25 Dimensions Device Case Size Weight 7SJ80**-*B for panel surface mounting 1/ 6 4.5 kg (9.9 lb) 7SJ80**-*E for panel flush mounting 1/ 6 4 kg (8.8 lb) Protection type acc. to IEC 60529 For equipment in the surface-mounting case IP 50 For equipment in flush mounting case Front IP 51 Rear IP 50 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 361 Technical Data 4.1 General Device Data For operator protection IP 2x for current terminal IP 2x for voltage terminal Degree of pollution, IEC 60255-27 2 4.1.10 UL certification conditions Output Relays DC 24 V 5 A General Purpose DC 48 V 0,8 A General Purpose DC 240 V 0,1 A General Purpose AC 240 V 5 A General Purpose AC 120 V 1/3 hp AC 250 V 1/2 hp B300, R300 Voltage Inputs Input voltage range 300 V Battery Servicing of the circuitry involving the batteries and replacement of the lithium batteries shall be done by a trained technician. Replace Battery with VARTA or Panasonic Cat. Nos. CR 1/2 AA or BR 1/2 AA only. Use of another Battery may present a risk of fire or explosion. See manual for safety instructions. Caution: The battery used in this device may present a fire or chemical burn hazard if mistreated. Do not recharge, disassemble, heat above 100 C (212 F) or incinerate. Dispose of used battery promptly. Keep away from children. Climatic Stress Tests Surrounding air temperature Design Field Wires of Control Circuits shall be separated from other circuits with respect to the end use requirements! tsurr: max. 70 C (158 F), normal operation Type 1 if mounted into a door or front cover of an enclosure. 362 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.2 Definite-time Overcurrent Protection 4.2 Definite-time Overcurrent Protection Operating Modes Three-phase Standard Two-phase Phases A and C Measuring Method All elements First harmonic, rms value (true rms) 50-3, 50N-3 Instantaneous values Setting Ranges / Increments Pickup current 50-1, 50-2 (phases) for Nom = 1 A 0.10 A to 35.00 A or (disabled) Increments 0.01 A for Nom = 5 A 0.50 A to 175.00 A or (disabled) Pickup current 50-3 (phases) for Nom = 1 A 1.0 A to 35.00 A or (disabled) for Nom = 5 A 5.0 A to 175.00 A or (disabled) Pickup Current 50N-1, 50N-2 (ground) for Nom = 1 A 0.05 A to 35.00 A or (disabled) Pickup Current 50N-3 (ground) for Nom = 1 A 0.25 A to 35.00 A or (disabled) Increments 0.01 A for Nom = 5 A 0.25 A to 175.00 A or (disabled) for Nom = 5 A 1.25 A to 175.00 A or (disabled) Time delays T 0.00 s to 60.00 s or (disabled) Increments 0.01 s Dropout time delays 50 T DROP-OUT, 50N T DROP-OUT 0.00 s to 60.00 s Increments 0.01 s Times Pickup times (without inrush restraint, with restraint + 1 period) First harmonic, rms value for 2 x setting value - for 10 x setting value Instantaneous value - for 2 x setting value - for 10 x setting value Dropout Times First harmonic, rms value Instantaneous value approx. 30 ms approx. 20 ms approx. 16 ms approx. 16 ms approx. 30 ms approx. 40 ms Dropout Ratio Dropout ratio for - first harmonic, rms value - instantaneous value approx. 0.95 for /Nom 0.3 approx. 0.90 for /Nom 0.3 Tolerances Pickup times for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Time delays T SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 1 % or 10 ms 363 Technical Data 4.2 Definite-time Overcurrent Protection Influencing Variables for Pickup and Dropout Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz 364 Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic at instantaneous value of 50-3/50N-3 elements 1% 1% Increased tolerances Transient overreaction for > 100 ms (with full displacement) <5 % SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.3 Inverse-time Overcurrent Protection 4.3 Inverse-time Overcurrent Protection Operating Modes Three-phase Standard Two-phase Phases A and C voltage-independent, voltage-controlled, voltage-dependent Measuring Method All elements First harmonic, rms value (true rms) Setting Ranges / Increments Pickup current 51 (phases) (Phasen) for N = 1 A 0.10 A to 4.00 A for N = 5 A 0.50 A to 20.00 A Pickup current 51N ground for N = 1 A 0.05 A to 4.00 A for N = 5 A 0.25 A to 20.00 A Increments 0.01 A Increments 0.01 A Time multiplier T for 51, 51N for IEC-Kennlinien 0.05 s to 3.20 s or (disabled) Increments 0.01 s Time multiplier D for 51, 51N for ANSI-Kennlinien Increments 0.01 s 0.50 s to 15.00 s or (disabled) Undervoltage threshold 51V V< for for release 10.0 V to 125.0 V of 51 Increments 0.1V Trip Time Curves acc. to IEC Acc. to IEC 60255-151 or BS 142, Section 3.5.2 (see also Figure 4-1 and Figure 4-2) The tripping times for /p 20 are identical with those for /p = 20 For zero sequence current, read 30p instead of p and T30p instead of Tp for ground fault, read Ep instead of p and TEp instead of Tp Pickup threshold SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 approx. 1.10 * p 365 Technical Data 4.3 Inverse-time Overcurrent Protection Dropout Time Characteristics with Disk Emulation acc. to IEC Acc. to IEC 60255-151 or BS 142, Section 3.5.2 (see also Figure 4-1 and Figure 4-2) The dropout time curves apply to (/p) 0.90 For zero sequence current, read 30p instead of p and T30p instead of Tp; for ground fault, read Ep instead of p and TEp instead of Tp Dropout Setting IEC without Disk Emulation approx. 1.05 * setting value p for p/N 0.3, this corresponds to approx. 0.95 * pickup value Reset of the Integration Timer IEC with Disk Emulation approx. 0.90 * setting value p Tolerances Pickup/dropout thresholdsp, Ep for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Trip time for 2 /p 20 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Dropout time for /p 0.90 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Influencing Variables for Pickup and Dropout Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz 366 Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.3 Inverse-time Overcurrent Protection Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic at instantaneous value of 50-3/50N-3 elements 1% 1% Increased tolerances Transient overreaction for > 100 ms (with full displacement) <5 % [ausloese-rueckfall-kennli-amz-iec-norm-stark-170502-wlk, 1, en_US] Figure 4-1 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to IEC SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 367 Technical Data 4.3 Inverse-time Overcurrent Protection [ausl-rueckfall-kennl-amz-iec-extrem-langzeit-170502-wlk, 1, en_US] Figure 4-2 368 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to IEC SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.3 Inverse-time Overcurrent Protection Trip Time Curves acc. to ANSI Acc. to ANSI/IEEE (see also Figure 4-3 bis Figure 4-6) The tripping times for /p 20 are identical with those for /p = 20 For zero sequence current read 30p instead of p and T30p instead of Tp; for ground fault read Ep instead of p and TEp instead of Tp Pickup threshold ca. 1.10 * p Dropout Time Characteristics with Disk Emulation acc. to ANSI/IEEE Acc. to ANSI/IEEE (see also Figure 4-3 bis Figure 4-6) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 369 Technical Data 4.3 Inverse-time Overcurrent Protection The dropout time curves apply to (/p) 0.90 For zero sequence current read 30p instead of p and T30p instead of Tp; for ground fault read Ep instead of p and TEp instead of Tp Dropout Setting ANSI without Disk Emulation approx. 1.05 * setting value p for p/N 0.3; corresponds to approx. 0.95 * pickup value Reset of the Integration Timer ANSI with Disk Emulation approx. 0.90 * setting value p Tolerances Pickup and Dropout Thresholds p, Ep for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Trip Time for 2 /p 20 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Dropout Time for /p 0.90 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Influencing Variables for Pickup and Dropout Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 370 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.3 Inverse-time Overcurrent Protection Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic at instantaneous value of 50-3/50N-3 elements 1% 1% Increased tolerances Transient overreaction for > 100 ms (with full displacement) <5 % SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 371 Technical Data 4.3 Inverse-time Overcurrent Protection [ausl-rueckfallkennl-amz-ansi-inv-short-170502-wlk, 1, en_US] Figure 4-3 372 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.3 Inverse-time Overcurrent Protection [ausl-rueckfallkennl-amz-ansi-lang-maessig-170502-wlk, 1, en_US] Figure 4-4 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 373 Technical Data 4.3 Inverse-time Overcurrent Protection [ausloese-rueckfallkennl-ansi-amz-stark-extrem-170502-wlk, 1, en_US] Figure 4-5 374 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.3 Inverse-time Overcurrent Protection [ausloese-rueckfall-amz-ansi-gleichmaessig-170502-wlk, 1, en_US] Figure 4-6 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 375 Technical Data 4.4 Directional Overcurrent Protection 4.4 Directional Overcurrent Protection Time Overcurrent Elements The same specifications and characteristics apply as for non-directional time overcurrent protection (see previous Sections). Determination of Direction Moreover, the following data apply to direction determination: For Phase Faults Polarization With cross-polarized voltages; with voltage memory 2 s Forward Range Vref,rot 86 Rotation of the reference voltage Vref,rot -180 to +180 Increments 1 Dropout difference 3 Directional sensitivity Unlimited for single and two phase faults For three phase faults, dynamically unlimited, steadystate approx. 7V phase-to-phase For Ground Faults Polarization with zero sequence quantities 3V0, 30 Forward Range Vref,rot 86 Rotation of the reference voltage Vref,ot -180 to +180 Increments 1 Dropout difference 3 Directional Sensitivity VN 2.5 V displacement voltage, measured 3V0 5 V displacement voltage, calculated Polarization with negative sequence quantities 3V2, 32 Forward Range Vref,rot 86 Rotation of the reference voltage Vref,rot -180 to +180 Increments 1 Dropout difference 3 Directional Sensitivity 3V2 5 V negative sequence voltage 32 45 mA negative sequence current with Nom = 1 A 32 225 mA negative sequence current with Nom = 5A Times Pickup times (without inrush restraint, with restraint + 1 period) 50-1, 50-2, 50-3, 50N-1, 50N-2, 50N-3 - for 2 x setting value - for 10 x setting value 376 approx. 45 ms approx. 40 ms SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.4 Directional Overcurrent Protection Dropout Times 50-1, 50-2, 50-3, 50N-1, 50N-2, 50N-3 approx. 40 ms Angle faults for phase and ground faults 1 electrical Tolerances Influencing Variables Frequency Influence - With no memory voltage SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 approx 1 in range 25 Hz to 50 Hz 377 Technical Data 4.5 Inrush Restraint 4.5 Inrush Restraint Controlled Elements Time Overcurrent Elements 50-1, 50N-1, 51, 51N, 67-1, 67N-1 Setting Ranges / Increments 10 % to 45 % Stabilization factor 2f/ Increments 1 % Functional Limits Lower Function Limit Phases Lower Function Limit ground Upper Function Limit, configurable for Nom = 1 A at least one phase current (50 Hz and 100 Hz) 50 mA for Nom = 5 A at least one phase current (50 Hz and 100 Hz) 125 mA for Nom = 1 A Ground current (50 Hz and 100 Hz) 50 mA for Nom = 5 A Ground current (50 Hz and 100 Hz) 125 mA for Nom = 1 A 0.30 A to 25.00 A Increments 0.01 A for Nom = 5 A 1.50 A to 125.00 A Increments 0.01 A Crossblock Crossblock A, B, C 378 ON/OFF SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.6 Dynamic Cold Load Pickup 4.6 Dynamic Cold Load Pickup Timed Changeover of Settings Controlled functions Directional and non-directional time overcurrent protection (separated acc. to phases and ground) Initiation criteria Current Criteria "BkrClosed I MIN" Interrogation of the circuit breaker position Automatic reclosing function ready 3 time elements Time control 3 time elements (TCB Open., TActive, TStop) Current control Current threshold "BkrClosed I MIN" (reset on current falling below threshold: monitoring with timer) Setting Ranges / Increments Current Control for N = 1 A 0.04 A to 1.00 A for N = 5 A 0.20 A to 5.00 A Increments 0.01 A Time Until Changeover To Dynamic Settings TCB Open 0 s to 21600 s (= 6 h) Increments 1 s Period Dynamic Settings are Effective After a Reclo- 1 s to 21600 s (= 6 h) sure TActive Increments 1 s Fast Reset Time TStop 1 s to 600 s (= 10 min) or (fast reset inactive) Increments 1 s Dynamic Settings of Pickup Currents and Time Delays or Time Multipliers Adjustable within the same ranges and with the same increments as the directional and non-directional time overcurrent protection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 379 Technical Data 4.7 1-phase Overcurrent Protection 4.7 1-phase Overcurrent Protection Current Elements High-set current elements 50-2 for Nom = 1 A 0.001 A to 1.6 A or (element disabled) Increments 0.001 A for Nom = 5 A 0.005 A to 8 A or (element disabled) T50-2 Definite time current element 50-1 0.00 s to 60.00 s or (no trip) for Nom = 1 A 0.001 A to 1.6 A or (element disabled) Increments 0.01 s Increments 0.001 A for Nom = 5 A 0.005 A to 8 A or (element disabled) T50-1 0.00 s to 60.00 s or (no trip) Increments 0.01 s Operating Times Pickup/Dropout Times Frequency Pickup Time 50 Hz 60 Hz minimum 14 ms 13 ms maximum 35 ms 35 ms Dropout time approx. 25 ms 22 ms Dropout Ratios Current Elements approx 0.95 for /Nom 0.5 Currents 5 % of setting value or 1 mA Times 1 % of setting value or 10 ms Tolerances Influencing Variables for Pickup Values Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1.15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz 380 Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.8 Voltage Protection 4.8 Voltage Protection Setting Ranges / Increments Undervoltages 27-1, 27-2 Measured quantity used with three-phase connection - Positive sequence system of voltages - Smallest phase-to-phase voltages - Smallest phase-to-ground voltage Measured quantity used with single-phase connection Single-phase phase-to-ground or phase-to-phase voltage Connection of phase-to-ground voltages - Bewertung Leiter-ground voltages - Evaluation of phase-to-phase voltages - Evaluation of positive-sequence system 10 V to 120 V 10 V to 210 V 10 V to 210 V Increment 1 V Increment 1 V Increment 1 V Connection of phase-to-phase voltages 10 V to 120 V Increment 1 V Connection: single-phase 10 V to 120 V Increment 1 V 1.01 to 3.00 Increment 0.01 Dropout ratio r for 27-1, 27-21) Dropout threshold for (r * 27-1) or (r * 27-2) max.130 V for phase-to-phase voltage max. 225 V for phase-to-ground voltage Minimum hysteresis 0.6 V Time delays 27-1 DELAY, 27-2 DELAY 0.00 s to 100.00 s oder (disabled) Increment 0.01 s for N = 1 A 0.04 A to 1.00 A Increment 0.01 A for N = 5 A 0.20 A to 5.00 A Current criterion BkrClosed I MIN Overvoltages 59-1, 59-2 Measured quantity used with three-phase connection - Positive sequence system of the voltages - Negative sequence system of the voltages - Largest phase-to-phase voltage - Largest phase-to-ground voltage Measured quantity used with single-phase connection Connected single-phase phase-togroundvoltage or phase-to-phase voltage Connection of phase-to-ground voltages - Evaluation of phase-to-ground voltages - Evaluation of phase-to-phase voltages - Evaluation of positive-sequence system - Evaluation of negative-sequence system 20 V to 150 V 20 V to 260 V 20 V to 150 V 2 V to 150 V Increment 1 V Increment 1 V Increment 1 V Increment 1 V Connection of phase-to-phase voltages - Evaluation of phase-to-phase voltages - Evaluation of positive-sequence system - Evaluation of negative-sequence system 20 V to 150 V 20 V to 150 V 2 V to 150 V Increment 1 V Increment 1 V Increment 1 V Connection: single-phase 20 V to 150 V Increment 1 V 0.90 to 0.99 Increment 0.01 V Dropout ratio r for 59-1, 59-21) Dropout threshold for (r * 59-1) or (r * 59-2) max. 150 V for phase-to-phase voltage max. 260 V for phase-to-ground voltage Minimum hysteresis 0.6 V Time delays 59-1 DELAY, 59-2 DELAY 0.00 s to 100.00 s or (disabled) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Increment 0.01 s 381 Technical Data 4.8 Voltage Protection 1) r = Vdropout/Vpickup Times Pickup Times Undervoltage 27-1, 27-2, 27-1 V1, 27-2 V1 - Overvoltage 59-1, 59-2 - Overvoltage 59-1 V1, 59-2 V1, 59-1 V2 , 59-2 V2 approx. 50 ms approx. 50 ms approx. 60 ms Dropout Times - Undervoltage 27-1, 27-2, 27-1 V1, 27-2 V1 - Overvoltage 59-1, 59-2 - Overvoltage 59-1 V1, 59-2 V1, 59-1 V2 , 59-2 V2 approx. 50 ms approx. 50 ms approx. 60 ms Pickup Voltage Limits 3 % of setting value or 1 V Delay times T 1 % of setting value or. 10 ms Tolerances Influencing Variables Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz 382 Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.9 Negative Sequence Protection (definite-time characteristic) 4.9 Negative Sequence Protection (definite-time characteristic) Setting Ranges / Increments Unbalanced load tripping element 46-1.46-2 for N = 1 A 0.05 A to 3.00 A or (disabled) for N = 5 A 0.25 A to 15.00 A or (disabled) Increments 0.01 A Delay Times 46-1, 46-2 0.00 s to 60.00 s or (disabled) Increments 0.01 s Dropout Delay Times 46 T DROP-OUT 0.00 s to 60.00 s Increments 0.01 s Functional Limit Functional Limit for Nom = 1 A all phase currents 10 A for Nom = 5 A all phase currents 50 A for Nom = 1 A one phase current 0.1 A for Nom = 5 A one phase current 0.5 A Times Pickup Times Dropout Times approx. 35 ms approx. 35 ms Dropout Ratio Characteristic 46-1, 46-2 approx. 0.95 for 2/Nom 0,3 Tolerances Pickup values 46-1, 46-2 Nom = 1 A 3 % of setting value or 10 mA Nom = 5 A 3 % of setting value or 50 mA Time Delays 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Influencing Variables for Pickup Values Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% Transient overreaction for > 100 ms (with full displacement) <5 % SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 383 Technical Data 4.10 Negative Sequence Protection (inverse-time characteristics) 4.10 Negative Sequence Protection (inverse-time characteristics) Setting Ranges / Increments Pickup value 46-TOC (2p) for Nom = 1 A 0.05 A to 2.00 A for Nom = 5 A 0.25 A to 10.00 A Increments 0.01 A Time Multiplier TI2p (IEC) 0.05 s to 3.20 s or (disabled) Increments 0.01 s Time Multiplier DI2p (ANSI) 0.50 s to 15.00 s or (disabled) Increments 0.01 s Functional Limit Functional Limit for Nom = 1 A all phase currents 10 A for Nom = 5 A all phase currents 50 A Trip Time Curves acc. to IEC See also Figure 4-7 The trip times for 2/2p 20 are identical to those for 2/2p = 20 Pickup Threshold 384 approx. 1.10* 2p SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.10 Negative Sequence Protection (inverse-time characteristics) Trip Time Curves acc. to ANSI It can be selected one of the represented trip time characteristic curves in Figure 4-8 and Figure 4-9 each on the right side of the figure. The trip times for 2/2p 20 are identical to those for 2/2p = 20 Pickup Threshold approx. 1.10* 2p Toleranzen Pickup threshold2p Nom = 1 A 3 % of setting value or 15 mA Nom = 5 A 3 % of setting value or 75 mA Time for 2 /2p 20 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Dropout Time Curves with Disk Emulation acc. to ANSI Representation of the possible dropout time curves, see Figure 4-8 and Figure 4-9 each on the left side of the figure SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 385 Technical Data 4.10 Negative Sequence Protection (inverse-time characteristics) The dropout time constants apply to (2/2p) 0.90 Dropout Value IEC and ANSI (without Disk Emulation) approx. 1.05 2p, setting value, which is approx. 0.95 * pickup threshold 2 ANSI with Disk Emulation approx. 0.90 2p setting value Tolerances Dropout value 2p Nom = 1 A 3 % of setting value or 15 mA Nom = 5 A 3 % of setting value or 75 mA Time for 2 /2p 0.90 5 % of reference (calculated) value + 2 % current tolerance, or 30 ms Influencing Variables for Pickup Values Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz 386 Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% Transient overreaction for > 100 ms (with full displacement) <5 % SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.10 Negative Sequence Protection (inverse-time characteristics) [ausloese-iec-schieflast-inv-stark-extr-170502-wlk, 1, en_US] Figure 4-7 Trip time characteristics of the inverse time negative sequence element 46-TOC, acc. to IEC SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 387 Technical Data 4.10 Negative Sequence Protection (inverse-time characteristics) [ausloese-rueckfall-ansi-schieflast-inv-mod-170502-wlk, 1, en_US] Figure 4-8 388 Dropout time and trip time characteristics of the inverse time unbalanced load stage, acc. to ANSI SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.10 Negative Sequence Protection (inverse-time characteristics) [ausl-rueckfall-schieflast-ansi-stark-extrem-170502-wlk, 1, en_US] Figure 4-9 Dropout time and trip time characteristics of the inverse time unbalanced load stage, acc. to ANSI SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 389 Technical Data 4.11 Frequency Protection 81 O/U 4.11 Frequency Protection 81 O/U Setting Ranges / Increments Setting Ranges / Increments 4; each can be set to f> or f< Pickup values f> or f< for fNom = 50 Hz 40.00 Hz to 60.00 Hz Increments 0.01 Hz Pickup values f> or f< for fNom = 60 Hz 50.00 Hz to 70.00 Hz Increments 0.01 Hz Dropout threshold = |pickup threshold - dropout threshold| 0.02 Hz to 1.00 Hz Increments 0.01 Hz Time delays T 0.00 s to 100.00 s or (disabled) Increments 0.01 s Undervoltage blocking with three-phase connection: Positive sequence component V1 10 V to 150 V Increments 1 V with single-phase connection ("Vphn, Vsyn"): single-phase Phase-to-ground voltage Times Pickup times f>, f< approx. 100 ms at fNom = 50 Hz approx. 80 ms at fNom = 60 Hz Dropout times f>, f< approx. 100 ms at fNom = 50 Hz approx. 80 ms at fNom = 60 Hz Dropout Difference f = pickup value - dropout value 0.02 Hz to 1 Hz Dropout Ratio Dropout Ratio for Undervoltage Blocking approx. 1.05 Tolerances Pickup frequencies 81/O or 81U 5 mHz Tolerance (at V = VNom, fNom - 0.5 Hz < f < fNom + 0.5 Hz) < 15 mHz Tolerance (at V = VNom, fNom - 5 Hz < f < fN - 0.5 Hz) Undervoltage blocking Time delays 81/O or 81/U < 15 mHz Tolerance (at V = VNom, fNom + 0.5 Hz < f < fNom + 5 Hz) 3 % of setting value or 1 V 1 % of setting value or 10 ms Influencing Variables 390 Power supply direct voltage in range 0.8 VPS/VPSNom 1.15 1% Temperature in range 23 F (-5 C) amb 131 F (55 C) 0,5 %/10 K Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.12 Undervoltage-controlled reactive power protection (27/Q) 4.12 Undervoltage-controlled reactive power protection (27/Q) Measured Values / Modes of Operation 3-phase 1, V, Q, Measuring method for , V Fundamental wave Pickup when Exceeding threshold value or falling below threshold value Setting Ranges / Increments Pickup thresholds: for Nom = 1 A 0.02 to 0.20 A for Nom = 5 A 0.10 to 1.00 A Voltage V 10.0 to 210.00 V Increments 0.1 V Power Q for Nom = 1 A 1.0 to 100 VAR Increments 0.01 VAR for Nom = 5 A 5.0 to 500 VAR Current 1 Increments 0.01 A Tripping delay time 0.00 to 60.00 s Increments 0.01 s Release delay time 0.00 to 3600.00 s Increments 0.01 s Dropout delay 0.00 to 60.00 s Increments 0.01 s Function Limits Power measurement 3-phase for Nom = 1 A Positive sequence system current > 0.03 A for Nom = 5 A Positive sequence system current > 0.15 A Times Pickup times: QU protection typical maximum (small signals and thresholds) approx. 120 ms approx. 350 ms Binary input approx. 20 ms Dropout times: QU protection typical maximum < 50 ms < 350 ms Binary input < 10 ms Tolerances Pickup thresholds: Current for Nom = 1 A 1% of set value or 10 mA at Nom 0.03 A 2% of set value or 20 mA bei Nom < 0.03 A for Nom = 5 A 1% of set value or 50 mA at Nom 0.25 A 2% of set value or 100 mA at Nom <0.25 A Current (symmetrical components) Voltage SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 for Nom = 1 A 2% of set value or 20 mA for Nom = 5 A 2% of set value or 100 mA 1% of set value or 0.1 V 391 Technical Data 4.12 Undervoltage-controlled reactive power protection (27/Q) Voltage (symmetrical components) 2% of set value or 0.2 V Power 1% of set value or 0.3 VAR Times 1% of set value or 10 ms Influencing Variables for Pickup Values 392 Auxiliary direct voltage in the range from 0.8 VPS/VPSNom 1.15 1% Temperature in the range from 23.00 F (-5 C) amb 131.00 F (55 C) 0.5 %/10 K Frequency in the range from 25 Hz to 70 Hz 1% Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.13 Thermal Overload Protection 4.13 Thermal Overload Protection Setting ranges / increments Factor k according to IEC 60255-8 0.10 to 4.00 Increments 0.01 Time constant th 1.0 min to 999.9 min Increments 0.1 min for Nom = 1A 0.10 A to 4.00 A Increments 0.01 A for Nom = 5A 0.50 A to 20.00 A Current alarm element Alarm Extension with machine at rest k factor 1.0 to 10.0 relative to the time constant for the machine running Increments 0.1 Dropout time (emergency start) TEmergency 10 s to 15000 s Increments 1 s Trip Characteristic Formula for primary values: Trip Characteristic curve for / (k Nom) 8 with t Trip time in minutes th Heating-up time constant n Actual load current pre Preload current k Setting factor per IEC 60255-8 Nom Nominal current for the protected object Dropout Ratios /Trip Drops out with Alarm /Alarm approx. 0.99 approx. 0.97 /Alarm Tolerances Referring to k * Nom 2 % or 10 mA for Nom = 1 A, or 50 mA fur Nom = 5 A, 2 % class according to IEC 60255-8 Referring to Trip Time 3 % or 1 s for /(k *Nom) > 1,25; 3 % class according to IEC 60255-8 Influencing Variables Referring to k * Nom Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 393 Technical Data 4.13 Thermal Overload Protection Frequency in the range of 25 Hz to 70 Hz Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances [ausloesekennlinie-ueberlast-1111203-he, 1, en_US] Figure 4-10 394 Trip time curves for the thermal overload protection (49) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.14 Ground Fault Detection (Sensitive/Insensitive) 4.14 Ground Fault Detection (Sensitive/Insensitive) Displacement Voltage Pickup for All Types of Ground Faults Displacement voltage, measured V0> 1.8 V to 200.0 V or Increments 0.1 V Displacement voltage, calculated 3V0> 10.0 V to 225.0 V Increments 0.1 V Pickup delay T-DELAY Pickup 0 s to 320.00 s or Increments 0.01 s Additional tripping delay 64-1 DELAY 0.10 s to 40000.00 s or (disabled) Increments 0.01 s Operating time approx. 50 ms Dropout value 0.95 or (pickup value - 0.6 V) Measurement tolerance V0> (measured) 3V0> (calculated) 3 % of setting value or 0.3 V 3 % of setting value or 3 V Operating time tolerances 1 % of setting value or 10 ms Phase Detection for Ground Faults on an Ungrounded System Measuring Principle Voltage measurement (phase-ground) VPHASE MIN (Ground Fault Phase) 10 V to 100 V Increments 1 V VPHASE MAX (Healthy Phase) 10 V to 100 V Increments 1 V Measurement Tolerance acc. to VDE 0435, Part 3 % of setting value or 1 V 303 Ground Fault Pickup for All Types of Ground Faults (Definite Time Characteristic) Pickup current 50Ns-2 PICKUP, 50Ns-1 PICKUP for sensitive 1 A transformer for sensitive 5 A transformer for normal 1 A transformer for normal 5 A transformer 0.001 A to 1.600 A 0.005 A to 8.000 A 0.05 A to 35.00 A 0.25 A to 175.00 A Increments 0.001 A Increments 0.005 A Increments 0.01 A Increments 0.05 A Time delay50Ns-2 DELAY, 50Ns-1 DELAY 0.00 s to 320.00 s or (disabled) Increments 0.01 s Dropout time delay 50Ns T DROP-OUT 0.00 s to 60.00 s Increments 0.01 s Operating time 50 ms (non-directional) 50 ms (directional) Dropout ratio approx. 0.95 for Ns > 50 mA Measurement tolerance sensitive for Nom = 1 A 3 % of setting value or 1 mA Nom = 5 A 3 % of setting value or 5 mA for setting values < 10 mA ca. 20 % non-sensitive for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Operating time tolerance SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 1 % of setting value or 10 ms 395 Technical Data 4.14 Ground Fault Detection (Sensitive/Insensitive) Ground Fault Pickup for All Types of Ground Faults (Inverse Time Characteristic) User-defined characteristic (defined by a maximum of 20 value pairs of current and time delay in direction measurement method "cos phi and sin phi") Pickup current 51Ns for sensitive 1 A transformer for sensitive 5 A transformer for normal 1 A transformer for normal 5 A transformer 0.001 A to 1.400 A 0.005 A to 7.000 A 0.05 A to 4.00 A 0.25 A to 20.00 A Increments 0.001 A Increments 0.005 A Increments 0.01 A Increments 0.05 A Time multiplier T51Ns 0.10 s to 4.00 s or (disabled) Increments 0.01 s Pickup threshold approx. 1.10 * 51Ns Dropout ratio approx. 1.05 * 51Ns for 51Ns > 50 mA Measurement tolerance sensitive for Nom = 1 A 3 % of setting value or 1 mA for Nom = 5 A 3 % of setting value or 5 mA for setting values < 10 mA ca. 20 % non-sensitive for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Operating time tolerance in linear range 7 % of reference (calculated) value for 2 /51Ns 20 + 2 % current tolerance, or 70 ms Influencing Variables Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1.15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% Note: When using the sensitive transformer, the linear range of the measuring input for sensitive ground fault detection is from 0.001 A to 1.6 A or 0.005 A to 8.0 A, depending on parameter 205 CT SECONDARY. The function is however still preserved for larger currents. Direction Determination for all Types of Ground Fault with cos / sin Measurement Direction measurement - N and VN measured - 30 and 3V0 calculated Measuring principle Active/reactive power measurement Measuring release RELEASE DIRECT. 396 (current component perpendicular (90) to directional limit line) for sensitive 1 A transformer for sensitive 5 A transformer for normal 1 A transformer for normal 5-A transformer 0.001 A to 1.600 A 0.005 A to 8.000 A 0.05 A to 35.00 A 0.25 A to 175.00 A Dropout ratio approx. 0.80 Measurement method cos and sin Increments 0.001 A Increments 0.005 A Increments 0.01 A Increments 0.05 A SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.14 Ground Fault Detection (Sensitive/Insensitive) Directional limit line PHI CORRECTION -45.0 to +45.0 Increments 0.1 Dropout delay RESET DELAY 1 s to 60 s Increments 1 s Limitation of the directional areas using 1 and 2 1 to 15 Increments 1 Angle tolerance 3 Direction Determination for all Types of Ground Fault with V0 / I0 Measurement Direction measurement - N and VN measured - 30 and 3V0 calculated Measuring principle V0 / 0 phase angle measurement 50Ns-1 element Minimum voltage 50Ns-1 Vmin V0 measured 3V0 calculated 0.4 V to 50 V 10 V to 90 V Increments 0.1 V Increments 1 V Phase angle 50Ns-1 Phi - 180 tos 180 Increments 1 Delta phase angle 50Ns-1 DeltaPhi 0 bis 180 Increments 1 V0 measured 3V0 calculated 0.4 V to 50 V 10 V to 90 V Increments 0.1 V Increments 1 V Phase angle 50Ns-2 Phi - 180 to 180 Increments 1 Delta phase angle 50Ns-2 DeltaPhi 0 to 180 Increments 1 Angle tolerance 3 50Ns-2 element Minimum voltage 50Ns-2 Vmin Angle tolerance Angle correction for cable converter in two operating points F1/I1 and F2/I2: Angle correction F1, F2 (for resonant-grounded system) Current values 1, for angle correction for sensitive 1 A transformer for sensitive 5 A transformer for normal 1 A transformer for normal 5 A transformer 0.0 to 5.0 Increments 0.1 0.001 A to 1.600 A 0.005 A to 8.000 A 0.05 A to 36.00 A 0.25 A to 175.00 A Increments 0.001 A Increments 0.005 A Increments 0.01 A Increments 0.05 A Measurement tolerance sensitive for Nom = 1 A 3 % of setting value or 1 mA for Nom = 5 A 3 % of setting value or 5 mA for setting values < 10 mA ca. 20 % non-sensitive for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Note: Due to the high sensitivity, the linear range of the measuring input N with integrated sensitive input transformer is from 0.001 * Nom to 1.6 * Nom. For currents greater than 1.6 * Nom, correct direction determination can no longer be guaranteed. EPTR Setting Ranges / Increments Pickup current SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 for N = 1 A 0.001 A to 2.400 A for N = 5 A 0.005 A to 7.000 A Increments0.001 A 397 Technical Data 4.14 Ground Fault Detection (Sensitive/Insensitive) Current at Maximum Time Delay for N = 1 A 0.001 A to 2.400 A for N = 5 A 0.005 A to 7.000 A for N = 1 A 0.003 A to 4.000 A for N = 5 A 0.015 A to 20.000 A for N = 1 A 0.003 A to 4.000 A for N = 5 A 0.015 A to 20.000 A Current at Minimum Time Delay Current at Knee Point Increments0.001 A Increments0.001 A Increments0.001 A Time delay at Knee Point 0.20 s to 100.00 s Increments0.01 s Minimum Time Delay 0.10 s to 30.00 s Increments0.01 s Maximum Time Delay 0.50 s to 300.00 s Increments0.01 s Delay Time T of the whole function -0.50 s to 30.00 s Increments0.01 s Pickup current 0.05 A to 4.00 A Increments 0.01 A Current at Maximum Time Delay 0.05 A to 4.00 A Increments 0.01 A Current at Minimum Time Delay 0.05 A to 20.00 A Increments 0.01 A Current at Knee Point 0.05 A to 17.00 A Increments 0.01 A Time delay at Knee Point 0.20 s to 100.00 s Increments 0.01 s Minimum Time Delay 0.10 s to 30.00 s Increments 0.01 s Maximum Time Delay 0.50 s to 300.00 s Increments 0.01 s Delay Time T of the whole function -0.50 s to 30.00 s Increments 0.01 s TNP Setting Ranges / Increments 398 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.14 Ground Fault Detection (Sensitive/Insensitive) EPTR/TNP Tripping Time Characteristic [7SJ80_knickpkt-kennlinie, 1, en_US] Figure 4-11 Tripping Time Characteristic Curves of the Inverse-Time Ground-Fault Protection with Logarithmic-Inverse Knee-Point Characteristic Curve, Example EPTR EPTR Trip Time characteristics for a primary short circuit current between: 0.5 A; 6 A t = 88.1 x (Ir)-2/3 Maximum Tolerance t+ = 105.7 x (Ir)-2/3 Maximum Tolerance t- = 70.5 x (Ir)-2/3 6 A; 80 A t = 160 x (Ir)-1 Maximum Tolerance t+ = 203.7 x (Ir)-1.034 Maximum Tolerance t- = 118.3 x (Ir)-0.956 80 A; 200 A t = 160 x (Ir)-1 Maximum Tolerance t+ = 175.8 x (Ir)-1.000 Maximum Tolerance t- = 143.9 x (Ir)-1.000 200 A; 300 A Maximum Tolerance t = 0.80 Maximum Tolerance t- = 0.72 300 A; 1000 A Maximum Tolerance t = 0.80 Maximum Tolerance t- = 1.26 x (Ir)-0.098 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 t+ = 0.88 t+ = 0.58 x (Ir)-0.073 399 Technical Data 4.14 Ground Fault Detection (Sensitive/Insensitive) EPTR/TNP Times Pickup Time Approx. 35 ms Dropout time Approx. 45 ms EPTR/TNP Dropout Setting Dropout Setting Approx. 0.95 for p/N > 0.005 EPTR/TNP Tolerance Pickup/dropout thresholds p 400 Nom = 1 A 3 % of setting value or 1 mA Nom = 5 A 3 % of setting value or 5 mA SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.15 Intermittent Ground Fault Protection 4.15 Intermittent Ground Fault Protection Intermittent Ground Fault Protection Pickup Threshold with N for Nom = 1 A 0.05 A to 35.00 A for = 5 A 0.25 A to 175.00 A Increments 0.01 A Increments 0.01 A with 30 for Nom = 1 A 0.05 A to 35.00 A for = 5 A 0.25 A to 175.00 A Increments 0.01 A Increments 0.01 A with Ns for Nom = 1 A 0.005 A to 1.500 A for = 5 A 0.025 A to 7.500 A Increments 0.001 A Increments 0.001 A Nom Nom Nom Pickup extension time Tv 0.00 s to 10.00 s Increments 0.01 s Ground Fault Accumulation Time Tsum 0.00 s to 100.00 s Increments 0.01 s Reset Time for Accumulation Tres 1 s to 600 s Increments 1 s Number of Pickups for Intermittent Ground Fault 2 to 10 Increments 1 Times Pickup Times - Current = 1.25 x Pickup Value - for 2 * Pickup Value Dropout Time (without extension time) approx. 30 ms approx. 22 ms approx. 22 ms Tolerances Pickup threshold ie> for Nom = 1 A 3 % of setting value or 10 mA for Nom = 5 A 3 % of setting value or 50 mA Times TV, Tsum, Tres 1 % of setting value or 10 ms Influencing Variables Power supply direct voltage in range 0.8 VPS/VPSNim 1.15 <1 % Temperature in range 23.00 F (-5 C) amb 131.00 F (55 C) <0.5 %/ K Frequency in range 25 Hz to 70 Hz <5 % relating to the set time SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 401 Technical Data 4.16 Directional intermittent ground fault protection 4.16 Directional intermittent ground fault protection Setting Ranges / Increments Pickup threshold Vgnd> / 3V0> 2.0 V .. 100.0 V Increments 1 V Monitoring time after pickup detected 0.04 s ... 10.00 s Increments 0.01 s Pulse no. for detecting the interm. E/F 2 ... 50 Increments 1 Dropout ratio Dropout ratio Vgnd> / 3V0> 0,95 or (pickup value - 0,6 V) Measurement tolerance Vgnd> / 3V0> 3 % of setting value Times 1 % of setting value or 10 ms Tolerances Influencing Variables 402 Power supply direct voltage in range 0.8 VPS/VPSNom 1.15 <1 % Temperature in range 23.00 F (-5 C) amb 131.00 F (55 C) <0,5 %/ K SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.17 Automatic Reclosing 4.17 Automatic Reclosing Number of Reclosures 0 to 9 (separated for phase and ground) Cycles 1 to 4 can be adjusted individually The following Protective Functions initiate the AR 50-3, 50-2, 50-1, 51, 67-3, 67-2, 67-1, 67-TOC 79 (no 79 start / 79 start / 79 blocked) 50N-3, 50N-2, 50N-1, 51N, 67N-3, 67N-2, 67N-1, 67- TOC TOCsensitive ground fault detection, unbalanced load, binary input Blocking of 79 by Pick up of protective elements for which 79 blocking is set (see above) 3-phase pickup (optional)3-polige Anregung (wahlweise) Binary input last trip command after the reclosing cycle is complete (unsuccessful reclosure) Trip command from the breaker failure Opening the circuit breaker without 79 External CLOSE Command Breaker failure monitoring Dead Time TDead 0.01 s to 320.00 s Increments 0.01 s (separate for phase and ground and individual for cycles 1 to 4) Extension of Dead Time using binary input with time monitoring Blocking Duration for Manual-CLOSE DetectionTBLK Manual Close 0.50 s to 320.00 s oder Increments 0.01 s Blocking Duration after reclosuree TBlocking Time 0.50 s to 320.00 s Increments 0.01 s Blocking Duration after Dynamic Blocking TBLK DYN 0.01 s to 320.00 s Increments 0.01 s Start Signal Monitoring Time TStart Mnitor 0.01 s to 320.00 s oder Increments 0.01 s Circuit Breaker Monitoring Time TCB Monitor 0.10 s to 320.00 s Increments 0.01 s Maximum Dead Time Extension TDead Exten 0.50 s to 320.00 s oder Increments 0.01 s Start delay of dead time using binary input with time monitoring Max. start delay of dead time TDead Delay 0,0 s to 1800,0 s oder Increments 1,0 s Operating time TOperate 0,01 s to 320,00 s oder Increments 0,01 s The following protection functions can be influenced by the automatic reclosing function individually for the cycles 1 to 4 (setting value T=T/ instantaneous T=0/ blocked T=infinite): 50-3, 50-2, 50-1, 51, 67-3, 67-2, 67-1, 67-TOC 50N-3, 50N-2, 50N-1, 51N, 67N-3, 67N-2, 67N-1, 67- TOC Additional Functions Lockout (Final Trip) Circuit breaker monitoring using breaker auxiliary contacts Synchronous closing (optionally with integrated or external synchrocheck, ) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 403 Technical Data 4.18 Fault Locator 4.18 Fault Locator Units of Distance Measurement in primary and secondary in km or miles line length or in % of line length1) Trigger Reactance Setting (secondary) trip command, Dropout of an Element, or External command via binary input for Nom = 1 A for Nom = 5 A 0.0050 to 9.5000 /km Increments 0.0001 0.0050 to 15.0000 /Meile Increments 0.0001 0.0010 to 1.9000 /km Increments 0.0001 0.0010 to 3.0000 /Meile Increments 0.0001 For the remaining parameters refer to the Power System Data 2. When configuring mixed lines, the reactance value must be set for each line section (A1 to A3). Measurement Tolerance acc. to VDE 0435, Part 303 for Sinusoidal Measurement Quantities 2,0 % fault location (without intermediate infeed) 30 K 90 and VK/VNom 0.1 and K/Nom 1.0 1) Homogeneous lines or correctly configured line sections are assumed when the fault distance is given in km, miles or %. 404 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.19 Breaker Failure Protection 50BF 4.19 Breaker Failure Protection 50BF Setting Ranges / Increments Pickup threshold 50-1 BF Pickup threshold 50N-1 BF for Nom = 1 A 0.05 A to 20.00 A Increments 0.01 A for Nom = 5 A 0.25 A to 100.00 A Increments 0.01 A for Nom = 1 A 0.05 A to 20.00 A Increments 0.01 A for Nom = 5 A 0.25 A to 100.00 A Increments 0.01 A Delay time 50 BF Trip timer 0.06 s to 60.00 s or Increments 0.01 s Delay time 50 BF-2 Delay 0.06 s to 60.00 s or Increments 0.01 s Times Pickup times - for internal start - for external start Included in time delay Included in time delay Dropout time approx. 25 ms1) Dropout ratio 0.95 (minimal hysteresis between pickup and tripping 32.5 mA) 1) A further delay for the current may be caused by compensation in the secondary CT circuit. Tolerances Pickup threshold 50-1 BF, 50N-1 BF for Nom = 1 A 3 % of setting value or 15 mA for Nom = 5 A 3 % of setting value or 75 mA Time delay 50 BF trip timer 1 % or 20 ms Influencing Variables for Pickup Values Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 405 Technical Data 4.20 Flexible Protection Functions 4.20 Flexible Protection Functions Measured Values / Modes of Operation Three-phase , 30, 1, 2, 2/1, V, 3V0, V1, V2, dV/dt, P forward, P reverse, Q forward, Q reverse, cos Single-phase , N, NN,N2, V, VN,Vx, P forward, P reverse, Q forward, Q reverse, cos Without fixed phase reference f, df/dt, binary input Measurement method for , V Fundamental, r.m.s. value (true RMS), positive sequence system, negative sequence system, zero sequence system Pickup on exceeding threshold value or falling below threshold value Setting Ranges / Increments Pickup thresholds: Current , 1, 2, 30, N for Nom = 1 A 0.05 A to 40.00 A for Nom = 5 A 0.25 A to 200.00 A Increments 0.01 A Relationship 2/1 15 % to 100 % Increments 1% Sensitive ground currentNs 0.001 A to 1.500 A Increments 0.001 A Voltage V, V1, V2, 3V0 2.0 V to 260.0 V Increments 0.1 V Displacement voltage V0 2.0 V to 200.0 V Increments 0.1 V for N = 1 A 2.0 W to 10000 W Increments 0.1 W for N = 5 A 10 W to 50000 W Power P, Q Power facto cos -0.99 to +0.99 Increments 0.01 40.0 Hz to 60.0 Hz 50.0 Hz to 70.0 Hz Increments 0.01 Hz Increments 0.01 Hz Frequency change df/dt 0.10 Hz/s to 20.00 Hz/s Increments 0.01 Hz/s Voltage change dV/dt 4 V/s to 100 V/s Increments 1 V/s Dropout ratio > element 1.01 to 3.00 Increments 0.01 Dropout ratio < element 0.70 to 0.99 Increments 0.01 Dropout difference f 0.02 Hz to 1.00 Hz Increments 0.01 Hz Pickup delay (standard) 0.00 s to 60.00 s Increments 0.01 s Pickup delay for 2/1 0.00 s to 28,800.00 s Increments 0.01 s Command delay time 0.00 s to 3,600.00 s Increments 0.01 s Dropout delay 0.00 s to 60.00 s Increments 0.01 s Frequency for fNom = 50 Hz for fNom = 60 Hz Fixed Dropout Difference 406 Dropout difference df/dt 0.1 Hz/s Dropout difference dV/dt 3 V/s SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.20 Flexible Protection Functions Function Limits Power measurement three-phase Power measurement single-phase Relationship 2/1 measurement for Nom = 1 A Positive sequence system current > 0.03 A for Nom = 5 A Positive sequence system current > 0.15 A for Nom = 1 A Phase current > 0.03 A for Nom = 5 A Phase current > 0.15 A for Nom = 1 A Positive or negative sequence system current > 0.1 A for Nom = 5 A Positive or negative sequence system current > 0.5 A Times Pickup times: Current, voltage (phase quantities) for 2 times the setting value for 10 times the setting value approx. 30 ms approx. 20 ms Current, voltage (symmetrical components) for 2 times the setting value for 10 times the setting value approx. 40 ms approx. 30 ms Power typical maximum (small signals and threshold values) approx. 120 ms approx. 350 ms Power factor 300 to 600 ms Frequency approx. 100 ms Frequency change for 1.25 times the setting value approx. 220 ms Voltage change dV/dt for 2 times the setting value approx. 220 ms Binary input approx. 20 ms Dropout times: Current, voltage (phase quantities) < 20 ms Current, voltage (symmetrical components) < 30 ms Power typical maximum < 50 ms < 350 ms Power factor < 300 ms Frequency < 100 ms Frequency change < 200 ms Voltage change < 200 ms Binary input < 10 ms Tolerances Pickup thresholds: Current Current (symmetrical components) for Nom = 1 A 3% of setting value or 15 mA for Nom = 5 A 3% of setting value or 75 mA for Nom = 1 A 4% of setting value or 20 mA for Nom = 5 A 4% of setting value or 100 mA Current (2/1) 4% of setting value Voltage 3% of setting value or 0,2 V Voltage (symmetrical components) 4% of setting value or 0,2 V SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 407 Technical Data 4.20 Flexible Protection Functions Voltage change dV/dt Power 5 % of setting value or 2 V/s for Nom = 1 A 3% of setting value or 0,5 W for Nom = 5 A 3% of setting value or 2,5 W Power factor 3 Frequency 15 mHz Frequency change 5% of setting value or 0,05 Hz/s Times 1% of setting value or 10 ms Influencing Variables for Pickup Values Auxiliary DC voltage in range 0.8 VAux/VAuxNom 1,15 1% Temperature in range -5 C (23 F) amb 55 C (131 F) 0.5 %/10 K Frequency in the range of 25 Hz to 70 Hz 408 Frequency in the range of 0.95 f/fNom 1.05 (fNom = 50 Hz or 60 Hz) 1% Frequency outside range 0.95 f/fNom 1.05 Increased tolerances Harmonics - up to 10 % 3rd harmonic - up to 10 % 5th harmonic 1% 1% SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.21 Synchrocheck 25 4.21 Synchrocheck 25 Modes of Operation - Synchrocheck Additional Release Conditions - Live bus / dead line, - Dead bus / live line, - Dead bus and dead line - Bypassing Voltages Maximum operating voltage Vmax 20 V to 140 V (phase-to-phase) Increments 1 V Minimum operating voltage Vmin 20 V to 125 V (phase-to-phase) Increments 1 V V< for dead line V> for live line 1 V to 60 V (phase-to-phase) Increments 1 V 20 V to 140 V (phase-to-phase) Increments 1 V Primary transformer rated voltage V2N 0.10 kV to 800.00 kV Tolerances 2 % of pickup value or 2 V Dropout Ratios approx. 0.9 (V>) or 1.1 (V<) Increments 0.01 kV Permissible Difference Voltages differences V2>V1; V2<V1 Tolerance 0.5 V to 50.0 V (phase-tophase) Increments 0.1 V 1V Frequency Difference f2>f1; f2<f1 Tolerance 0.01 Hz to 2.00 Hz 20 mHz Increments 0.01 Hz Angle Difference 2 > 1; 2 < 1 2 to 80 Increments 1 Tolerance 2 Max. angle error 5 for f 1 Hz 10 for f >1 Hz Vector group matching via angle 0 to 360 Increments 1 Different voltage transformer V1/V2 0.50 to 2.00 Increments 0.01 Minimum Measuring Time approx. 80 ms Maximum duration TSYN DURATION 0.01 s to 1200.00 s or (disabled) Increments 0.01 s Monitoring Time TSUP VOLTAGE 0.00 s to 60.00 s Increments 0.01 s Tolerance of all times 1 % of setting value or 10 ms Matching Times Measured Values of the Synchronism and Voltage Check Reference voltage V1 - Range - Tolerance 1) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 in kV primary, in V secondary or in % VNom 10 % to 120 % of VNom 1 % of measured value, or 0,5 % VNom 409 Technical Data 4.21 Synchrocheck 25 Voltage to be synchronized V2 - Range - Tolerance 1) 10 % to 120 % of VNom 1 % of measured value, or 0,5 % VNom Frequency of the voltage V1 - Range f1 in Hz fNom 5 Hz - Tolerance 1) 20 mHz Frequency of the voltage V2 - Range f2 in Hz fNom 5 Hz - Tolerance 1) 20 mHz Voltage difference V2-V1 - Range in kV primary, in V secondary or in % VN - Tolerance 1) 1 % of measured value, or 0,5 % VN 10 % bis 120 % of VN Frequency difference f2-f1 - Range in mHz fNom 5 Hz - Tolerance 1) 20 mHz Angle difference 2-1 - Range in 0 to 180 0,5 - Tolerance 1) 1) at 410 in kV primary, in V secondary or in % VNom nominal frequency SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.22 User-defined Functions (CFC) 4.22 User-defined Functions (CFC) Function Blocks and Their Possible Assignments to Task Levels Function block Explanation Task level MW_ BEARB PLC1_ BEARB PLC_ BEARB SFS_ BEARB ABSVALUE Magnitude Calculation X -- -- -- ADD Addition X X X X ALARM Alarm X X X X AND AND - Gate X X X X BLINK Blink 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 Metered value comparison X X X X CONNECT Connection -- X X X COUNTER Counter X X X X DI_GET_STATUS Decode status of double-point indication X X X X DI_SET_STATUS Generate double-point indication with status X X X X D_FF D- Flipflop -- X X X D_FF_MEMO Status Memory for Restart X X X X DI_TO_BOOL Double Point to Boolean (conversion) -- X X X DINT_TO_REAL Adaptor X X X X DIST_DECODE Convert double-point indication with status into four single-point indications with status 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 INT_TO_REAL Conversion X X X X IO_UNIT SICAM I/O Unit X X LIVE_ZERO Live-zero, non-linear Curve X -- -- -- LONG_TIMER Timer (max.1193h) X X X X LOOP Feedback Loop X X -- X LOWER_SETPOINT Lower Limit X -- -- -- MUL Multiplication X X X X MV_GET_STATUS Decode status of a value X X X X MV_SET_STATUS Set status of a value X X X X NAND NAND - Gate X X X X NEG Negator X X X X NOR NOR - Gate X X X X SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 411 Technical Data 4.22 User-defined Functions (CFC) Function block Explanation Task level MW_ BEARB PLC1_ BEARB PLC_ BEARB SFS_ BEARB OR OR - Gate X X X X REAL_TO_DINT Adaptor X X X X REAL_TO_INT Conversion X X X X REAL_TO_UINT Conversion X X X X RISE_DETECT Edge detector X X X X RS_FF RS- Flipflop -- X X X RS_FF_MEMO RS- Flipflop with status memory -- X X X SQUARE_ROOT Root Extractor X X X X SR_FF SR- Flipflop -- X X X SR_FF_MEMO SR- Flipflop with status memory -- X X X ST_AND AND gate with status X X X X ST_NOT Inverter 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 Conversion X X X X UPPER_SETPOINT Upper Limit X -- -- -- X_OR XOR - Gate X X X X ZERO_POINT Zero Supression X -- -- -- Device-specific CFC Blocks Table 4-1 Input Output ASWITCH - This block is used to switch between two REAL inputs (RMS values) Name Type Description Default function SWITCH BOOL Analog value selection FALSE IN1 REAL Analog value 0.0 IN2 REAL Analog value 0.0 OUT REAL Selected analog value Task levels: Recommendation: Into task levels PLC1_BEARB and PLC_BEARB, because these levels are directly triggered. Note: If you use thi block in the task levels MW_BEARB and SFS_BEARB, a change of the SWITCH signal is only recognized if the signal lasts longer than the processing cycle of the task level. Behavior of inputs and outputs: General Limits 412 Description Limit Comment Maximum number of all CFC charts considering all task levels 32 If the limit is exceeded, the device rejects the parameter set with an error message, restores the last valid parameter set and restarts using that parameter set. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.22 User-defined Functions (CFC) Description Limit Comment Maximum number of all CFC charts considering one task level 16 When the limit is exceeded, an error message is output by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. Maximum number of all CFC inputs considering all charts 400 When the limit is exceeded, an error message is output by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. Maximum number of reset-resistant flipflops D_FF_MEMO 350 When the limit is exceeded, an error message is output by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. Description Limit Comment Maximum number of synchronous changes of chart inputs per task level 165 When the limit is exceeded, an error message is output by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. Device-Specific Limits Maximum number of chart outputs per 150 task level Additional Limits Additional limits 1) for the following CFC blocks: Task Level Maximum Number of Modules in the Task Levels TIMER2) 3) MW_BEARB PLC1_BEARB PLC_BEARB SFS_BEARB TIMER_SHORT2) 3) -- -- 15 30 -- -- 1) When the limit is exceeded, an error message is iisued by the device. Consequently, the device starts monitoring. The red ERROR-LED lights up. 2) The following condition applies for the maximum number of timers: (2 * number of TIMER + number of TIMER_SHORT) < 30. TIMER and TIMER_SHORT hence share the available timer resources within the frame of this inequation. The limit does not apply to the LONG_TIMER. 3) The time values for the blocks TIMER and TIMER_SHORT must not be selected shorter than the time resolution of the device of 10 ms, as then, the blocks will not then start with the starting pulse. Maximum Number of TICKS in the Task Levels Task level Limit in TICKS 1) MW_BEARB (measured value processing) 10000 PLC1_BEARB (slow PLC processing) 12000 PLC_BEARB (fast PLC processing) SFS_BEARB (interlocking) 1) When 600 10000 the sum of TICKS of all blocks exceeds the limits mentioned before, an error message is output in the CFC. Processing Times in TICKS for the Individual Elements Individual element Number of TICKS Block, basic requirement 5 Each input from the 3rd additional input on for generic modules 1 Combination with input signal border 6 Combination with output signal border 7 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 413 Technical Data 4.22 User-defined Functions (CFC) Individual element Number of TICKS Additionally for each chart Arithmetic Base logic Information status Memory Control commands Type converter 414 1 ABS_VALUE 5 ADD 26 SUB 26 MUL 26 DIV 54 SQUARE_ROOT 83 AND 5 CONNECT 4 DYN_OR 6 NAND 5 NEG 4 NOR 5 OR 5 RISE_DETECT 4 X_OR 5 SI_GET_STATUS 5 CV_GET_STATUS 5 DI_GET_STATUS 5 MV_GET_STATUS 5 SI_SET_STATUS 5 DI_SET_STATUS 5 MV_SET_STATUS 5 ST_AND 5 ST_OR 5 ST_NOT 5 D_FF 5 D_FF_MEMO 6 RS_FF 4 RS_FF_MEMO 4 SR_FF 4 SR_FF_MEMO 4 BOOL_TO_CO 5 BOOL_TO_IC 5 CMD_INF 4 CMD_INF_EXE 4 CMD_CHAIN 34 CMD_CANCEL 3 LOOP 8 BOOL_TO_DI 5 BUILD_DI 5 DI_TO_BOOL 5 DM_DECODE 8 DINT_TO_REAL 5 DIST_DECODE 8 UINT_TO_REAL 5 REAL_TO_DINT 10 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.22 User-defined Functions (CFC) Individual element Comparison Number of TICKS REAL_TO_UINT 10 COMPARE 12 LOWER_SETPOINT 5 UPPER_SETPOINT 5 LIVE_ZERO 5 ZERO_POINT 5 Metered value (counter) COUNTER 6 Time and clock pulse TIMER 5 TIMER_LONG 5 Other TIMER_SHORT 8 ALARM 21 BLINK 11 IO_UNIT 17 Routable in Matrix In addition to the defined preassignments, indications and measured values can be freely routed to buffers, preconfigurations can be removed. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 415 Technical Data 4.23 Auxiliary Functions 4.23 Auxiliary Functions Operational Measured Values Currents in A (kA) primary and in A secondary or in % Nom A; B; C Positive sequence component 1 Negative sequence component 2 Nor 30 Range Tolerance 10 % to 150 % Nom 1) 1.5 % of measured value or 1 % Nom and between 151 % and 200 % INom 3 % of measured value Voltages (phase-to-ground) VA-N, VB-N, VC-N in kV primary, in V secondary or in % VNom Voltages (phase-to-phase) VA-B, VB-C, VC-A, VSYN VN, Vph-N, Vx or V0 Positive sequence component V1 Negative sequence component V2 Range 10 % to 120 % of VNom Tolerance 1) 1.5 % of measured value or 0.5 % VNom S, apparent power in kVAr (MVAR or GVAR) primary and in % SNom Range Tolerance 0 % to 120 % SNom 1) 1.5 % of SNom for V/VNom and /Nom = 50 to 120 % P, Active power with sign, total and phase-segregated in kW (MW or GW) primary and in % SNom Range 0 % to 120 % SNom Tolerance 1) 2 % of SNom for V/VNom and /Nom = 50 to 120 % and | cos | = 0.707 to 1 with SNom =3 * VNom * Nom Q, reactive power with sign, total and phase-segregated in kVAr (MVAr or GVAr) primary and in % SNom Range 0 % to 120 % SNom Tolerance 1) 2 % of SNom for V/VNom and /Nom = 50 to 120 % und | sin | = 0.707 to 1 with SNom = 3* VNom * Nom cos , power factor total and phase-segregated Range Tolerance 1) Frequencies f in Hz Range Tolerance Temperature overload protection /Trip 416 -1 to +1 2 % for | cos | 0.707 fNom 5 Hz 1) 20 mHz in % SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.23 Auxiliary Functions Range Tolerance 1) 0 % to 400 % 5 % class accuracy acc. to IEC 60255-8 Synchrocheck function 25 see Section (Synchrocheck) Currents of sensitive ground fault detection (total, real, and reactive current) in A (kA) primary and in mA secondary Ns, Nsreal; Nsreactive Range Tolerance 1) Phase angle between zero sequence voltage and sensitive ground current (3V0, Ns) Range Tolerance 1) 1) at 0 mA to 1600 mA or 0 A to 8 A for INom = 5 A 3 % of measured value or 1 mA in - 180 to + 180 1 nominal frequency 2) Displaying of cos as of /Nom and V/VNom greater than 10% Long-Term Mean Values Time Window 5, 15, 30 or 60 minutes Frequency of Updates adjustable Long-Term Averages of Currents of Real Power of Reactive Power of Apparent Power Admd; Bdmd; Cdmd; 1dmd in A (kA) Pdmd in W (kW, MW) Qdmd in VAr (kVAr, MVAr) Sdmd in VAr (kVAr, MVAr) Min./Max. Memory Storage of Measured Values with date and time Reset automatic Time of day adjustable (in minutes, 0 to 1439 min) Time frame and starting time adjustable (in days, 1 to 365 days, and ) Manual Reset Using binary input Using keypad Via communication Min/Max Values for Current A; B; C; 1 (positive sequence component) Min/Max Values for Voltages VA-N; VB-N; VC-N; V1 (positive sequence component); VA-B; VB-C; VC-A Min/Max Values for Power S, P; Q, cos ; frequency Min/Max Values for Overload Protection /tRIP Min/Max Values for Mean Values Admd; Bdmd; Cdmd; 1dmd (positive sequence component); Sdmd; Pdmd; Qdmd SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 417 Technical Data 4.23 Auxiliary Functions Fuse Failure Monitor Setting range of the displacement voltage 3V0 above which voltage failure is detected 10 - 100 V Setting range of the ground current above which no voltage failure is assumed 0.1 - 1 A for Bdmd = 1 A Setting range of the pickup threshold > above which no voltage failure is assumed 0.1 - 35 A for Bdmd = 1 A Measuring voltage monitoring depends on the MLFB and configuration with measured and calculated values VN and N 0.5 - 5A for Bdmd = 5A 0.5 - 175 A for Bdmd = 5A Broken-wire Monitoring of Voltage Transformer Circuits suited for single-, two- or three-pole broken-wire detection of voltage transformer circuits; only for connection of phase-ground voltages Local Measured Value Monitoring Current asymmetry max/min > symmetry factor, for > limit Voltage asymmetry Vmax/Vmin > symmetry factor, for V > Vlimit Current sum | iA + iB + iC + kI * iE | > limit value, with Current phase sequence Clockwise (ABC) / counter-clockwise (ACB) Voltage phase sequence Clockwise (ABC) / counter-clockwise (ACB) Fault Logging Recording of indications of the last 8 power system faults Recording of indications of the last 3 power system ground faults Time Allocation Resolution for Event Log (Operational Annunciations) 1 ms Resolution for Trip Log (Fault Annunciations) 1 ms Maximum Time Deviation (Internal Clock) 0.01 % Battery Lithium battery 3 V/1 Ah, Typ CR 1/2 AA Message "Battery Fault" for insufficient battery charge Fault Recording maximum of 8 fault records saved; memory maintained by buffer battery in the case of auxiliary voltage failure Recording time 5 s per fault record, in total up to 18 s at 50 Hz (max. 15 s at 60 Hz) Intervals at 50 Hz Intervals at 60 Hz 1 instantaneous value each per 1.0 ms 1 instantaneous value each per 0.83 ms Energy Counter Meter Values for Energy Wp, Wq (real and reactive energy) 418 in kWh (MWh or GWh) or in kVARh (MVARh or GVARh) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.23 Auxiliary Functions Range 28 Bit or 0 to 2 68 435 455 decimal for IEC 60870-5-103 (VDEW protocol) 31 Bit or 0 to 2 147 483 647 for other protocols (other than VDEW) 2 % for > 0.1 N, V > 0.1 VN and Tolerance 1) at | cos | 0.707 1) nominal frequency Switching Statistics Saved Number of Trips up to 9 digits Number of Automatic Reclosing Commands (segregated according to 1st and 2nd cycle) up to 9 digits Accumulated Interrupted Current (segregated according to pole) up to 4 digits Operating Hours Counter Display Range Up to 7 digits Criterion Overshoot of an adjustable current threshold (element 50-1, BkrClosed I MIN) Circuit Breaker Maintenance Calculation methods on true r.m.s value basis: , x, 2P; on instantaneous value basis: 2t Acquisition/conditioning of measured values phase-selective Evaluation one threshold per subfunction Number of saved statistic values up to 13 digits Trip Circuit Supervision With one or two binary inputs Commissioning Aids - Phase rotation field check - Operational measured values - Circuit breaker test by means of control function - Creation of a test measurement report - Creation of messages Clock Time synchronization Binary input Communication Modes of operation for time tracking No. Mode of operation Explanations 1 Internal Internal synchronization using RTC (presetting) 2 IEC 60870-5-103 External synchronization using port B (IEC 60870-5-103) 3 Pulse via binary input External synchronization with pulse via binary input 4 Fieldbus (DNP (serial or DNP3 TCP), External synchronization using field bus Modbus, IEC 60870-5-103 redundant) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 419 Technical Data 4.23 Auxiliary Functions 5 SNTP (IEC 61850, DNP3 TCP, PROFINET IO) External synchronization using port B (IEC 61850) - SNTP (no IEC61850) External synchronization via port A Parameterization via device; notes under 2.1.2.2 Setting Notes Setting Group Change Option of the Functional Settings Number of Available Setting Groups 4 (parameter group A, B, C and D) Switchover Performed using the keypad DIGSI using the front PC port Protocol using port B Binary Input IEC 61850 GOOSE (inter-relay 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. As from version V4.6 of the devices, applications with protective functions have to be checked with regard to their required runtime. In individual cases, the manufacturer has to be consulted with regard to the requirements to ensure that the application functions safely. 420 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.24 Switching Device Control 4.24 Switching Device Control Number of Controlled Switching Devices Depends on the number of binary inputs and outputs available Interlocking Freely programmable interlocking Messages Single command / double command Control Commands Single command / double command Switching Command to Circuit Breaker 1-, 11/2 - and 2-pole Programmable Logic Controller PLC logic, graphic input tool Local Control Control via menu control assignment of function keys Remote Control Using Communication Interfaces Using a substation automation and control system (e.g. SICAM) Using DIGSI (e.g. via Modem) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 421 Technical Data 4.25 Dimensions 4.25 Dimensions 4.25.1 Panel Flush and Cubicle Mounting (Housing Size 1/6) [abmess-sechstel-gehaeuse-7sx80-060606, 1, en_US] Figure 4-12 Note: 422 Dimensional drawing of a 7SJ80 for panel flush or cubicle mounting (housing size 1/6) A set of mounting brackets (consisting of upper and lower mounting rail) (order no. C73165-A63D200-1) is required for cubicle mounting. When using the Ethernet interface, it may be necessary to rework the lower mounting rail. Provide for sufficient space at the device bottom side or below the device to accommodate the cables of the communication modules. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Technical Data 4.25 Dimensions 4.25.2 Panel Surface Mounting (Housing Size 1/6) [abmess-sechstel-gehaeuse-aufbau-7sx80-060606, 1, en_US] Figure 4-13 Dimensional drawing of a 7SJ80 for panel surface mounting (housing size 1/6) 4.25.3 Bottom view [ansicht-unten-sechstel-gehaeuse-7sx80-070914, 1, en_US] Figure 4-14 Bottom view of a 7SJ80 (housing size 1/6) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 423 Technical Data 4.25 Dimensions 4.25.4 Varistor [varistor-20071105, 1, en_US] Figure 4-15 424 Dimensional drawing of the varistor for voltage limiting in high-impedance differential protection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 A Ordering Information and Accessories A.1 Ordering Information 7SJ80 426 A.2 Accessories 431 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 425 Ordering Information and Accessories A.1 Ordering Information 7SJ80 A.1 Ordering Information 7SJ80 Multifunctional protection device with control 6 7 S J 8 7 0 8 9 10 11 12 - 13 14 15 16 - F Zusatz + Number of binary inputs and outputs Pos. 6 Housing 1/6 19" 4 x , 3 BI, 5 BO (2 changeover contacts), 1 life status contact 1 Housing 1/6 19" 4 x , 7 BI, 8 BO (2 changeover contacts), 1 life status contact 2 Housing 1/6 19" 4 x , 3x V, 3 BI, 5 BO (2 changeover contacts), 1 life status contact 3 Housing 1/6 19" 4 x , 3 x V, 7 BI, 8 BO (2 changeover contacts), 1 life status contact 4 Housing 1/6 19" 4 x , 11 BI, 5 BO (2 changeover contacts), 1 life status contact 7 Housing 1/6 19" 4 x , 3 x V, 11 BI, 5 BO (2 changeover contacts), 1 life status contact 8 Measuring inputs (4 x ) Pos. 7 ph = 1 A, e = 1 A / 5 A 1 ph = 1 A, ns (sensitive) = 0.001 A to 1.6 A / 0.005 A to 8 A 2 Auxiliary voltage (power supply, pilot voltage) Pos. 8 DC 24 V/ 48 V 1 DC 60 V / 110 V / 125 V / 220 V / 250 V, AC 115 V, AC 230 V 5 Construction Pos. 9 Surface-mounting case, screw-type terminals B Flush mounting case, screw-type terminals E Region-specific default settings / function versions and language default settings Pos. 10 Region DE, IEC, language German (language can be changed, standard front panel A Region world, IEC/ANSI, language English (language can be changed), standard front panel B Region US, ANSI, language US-English (language can be changed), US front panel C Region FR, IEC/ANSI, language French (language can be changed), standard front panel D Region world, IEC/ANSI, language Spanish (language can be changed), standard front panel E Region world, IEC/ANSI, language Italian (language can be changed), standard front panel F Region RUS, IEC/ANSI, language Russian (language can be changed), standard front panel G Region CHN, IEC/ANSI, language Chinese (language can not be changed), standard front panel Chinese K Port B (bottom side of device, rear) Pos. 11 not equipped 0 IEC60870-5-103 or DIGSI4/Modem, electrical RS232 1 IEC60870-5-103 or DIGSI4/Modem, electrical RS485 2 IEC60870-5-103 or DIGSI4/Modem, optical 820nm, ST connector 3 For further interface options see Additional Information in the following 9 Additional information for additional ports (bottom side of device, rear, port B) Supplementary Profibus DP Slave, electrical RS485 +L0A Profibus DP Slave, 820 nm, optical double ring, ST connector +L0B Modbus, electrical RS485 +L0D Modbus, optical 820 nm, ST connector +L0E DNP3.0, electrical RS485 +L0G DNP3.0, optical 820 nm, ST connector +L0H 426 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Ordering Information and Accessories A.1 Ordering Information 7SJ80 Additional information for additional ports (bottom side of device, rear, port B) Supplementary IEC 60870-5-103 Protocol, redundant, electrical RS485, RJ45 connector +L0P IEC 61850, 100Mbit Ethernet electrical, double, RJ45 connector +L0R IEC 61850 100 Mbit Ethernet optical, double, LC connector +L0S DNP3 TCP, 100 Mbit Ethernet electrical, double, RJ45 connector +L2R DNP3 TCP, 100 Mbit Ethernet optical, double, LC connector +L2S PROFINET 100Mbit Ethernet electrical, double, RJ45 connector +L3R PROFINET 100 Mbit Ethernet optical, double, LC connector +L3S IEC 60870-5-104 and IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector +L4R IEC 60870-5-104 and IEC 61850, 100Mbit Ethernet, optical, double, LC connector +L4S MODBUS TCP and IEC 61850, 100Mbit Ethernet, electrical, double, RJ45 connector +L5R MODBUS TCP and IEC 61850, 100Mbit Ethernet, optical, double, LC connector +L5S Converter Order number Use SIEMENS OLM1) 6GK1502-2CB10 for single ring OLM1) 6GK1502-3CB10 for double ring SIEMENS 1) The converter requires an operating voltage of 24 VDC. If the available operating voltage is > 24 VDC the additional power supply 7XV5810-0BA00 is required. Port A (bottom side of device, front) Pos. 12 not equipped 0 with Ethernet interface (DIGSI interface, I/O unit connection, not IEC61850), RJ45 connector 6 Measurement / Fault Recording Pos. 13 With fault recording 1 With fault recording, average values, min/max values 3 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 427 Ordering Information and Accessories A.1 Ordering Information 7SJ80 Functions Pos. 15 Name ANSI-No. Description Basic function -- Control (included in all versions)3) 50/51 Time overcurrent protection phase 50-1, 50-2, 50-3, 51 50N/51N Time overcurrent protection ground 50N-1, 50N-2, 50N-3, 51N 50N(s)/ 51N(s) Ground fault protection/ ground short-circuit protection -- Intermittent ground fault protection 87N High-impedance ground fault differential protection (87N (REF) only available with sensitive ground current input (position 7 = 2) 49 Thermal overload protection 74TC Trip circuit supervision 46 Negative sequence overcurrent protection 50BF Breaker failure protection 50BF 37 Undercurrent surveillance 86 Lock out -- Cold-load pickup Monitoring functions Circuit breaker control Flexible protection functions (parameters from current) Inrush restraint 51V Voltage-controlled inverse-time overcurrent protection 67N Directional ground fault protection 67N-1, 67N-2, 67N-3, 67N-TOC 67N(s) Directional ground fault protection/ground short circuit protection Basic design 4) + ground fault direction detection + voltage protection + frequency protection A 50Ns-1, 50Ns-2, 51Ns1) B 67Ns-1, 67Ns-2, 67Ns-TOC 1) 428 64/59N Displacement voltage 27/59 Undervoltage / overvoltage 81 U/O Underfrequency / overfrequency, f< ,f> 47 Phase sequence 32/55/81R/ 27R/59R Flexible protection functions (parameters from current and voltage): Voltage protection, power protection, power factor protection, frequency change protection and voltage change protection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Ordering Information and Accessories A.1 Ordering Information 7SJ80 Functions Basic design 4) + ground fault direction detection + direction determination for phase + voltage protection + frequency protection Pos. 15 51V Voltage-controlled inverse-time overcurrent protection 67 Direction determination for overcurrent phases 67-1, 67- 2, 67-3, 67-TOC 67N Directional ground fault protection 67N-1, 67N-2, 67N-3, 67N-TOC 67N(s) Directional ground fault protection/ground short circuit protection C 67Ns-1, 67Ns-2, 67Ns-TOC 1) Basic design 4) + ground fault direction detection + direction determination for phase + voltage protection + frequency protection + QU protection + directional intermittent ground fault protection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 64/59N Displacement voltage 27/59 Undervoltage / overvoltage 81 U/O Underfrequency / overfrequency, f< ,f> 47 Phase sequence 32/55/81R/ 27R/59R Flexible protection functions (parameters from current and voltage): Voltage protection, power protection, power factor protection, frequency change protection and voltage change protection 51V Voltage-controlled inverse-time overcurrent protection 67 Direction determination for overcurrent phases 67-1, 67- 2, 67-3, 67-TOC 67N Directional ground fault protection 67N-1, 67N-2, 67N-3, 67N-TOC 67N(s) Directional ground fault protection/ground short circuit protection F 67Ns-1, 67Ns-2, 67Ns-TOC 1) 67Ns Directional intermittent ground fault protection 2) 64/59N Displacement voltage 27/59 Undervoltage / overvoltage 81 U/O Underfrequency / overfrequency, f< ,f> -- Undervoltage-controlled reactive power protection (Q>/U<) 47 Phase sequence 32/55/81R/ 27R/59R Flexible protection functions (parameters from current and voltage): Voltage protection, power protection, power factor protection, frequency change protection and voltage change protection 429 Ordering Information and Accessories A.1 Ordering Information 7SJ80 Functions Basic design 5) + direction determination for phase + voltage protection + frequency protection + synchrocheck Pos. 15 51V Voltage-controlled inverse-time overcurrent protection 67 Direction determination for overcurrent phases 67-1, 67- 2, 67-3, 67-TOC 27/59 Undervoltage / overvoltage 81 U/O Underfrequency / overfrequency, f< ,f> 47 Phase sequence 25 Synchronism check 81R/27R/5 9R Flexible protection functions (parameters from current and voltage): Voltage protection, power protection, power factor protection, frequency change protection and voltage change protection Q 1) depending on the ground current input at position 7, the function works either as ground fault protection (sensitive input) or as ground short circuit protection (normal Ie input) 2) only with sensitive input, Position 7=2 3) only deliverable with position 6 = 1, 2 or 7 4) only deliverable with position 6 = 3, 4 (3 x V) or 8 5) only deliverable with position 6 = 3, 4 (3 x V) or 8 and position 16 = 0 or 1 Automatic reclosing function 79AR / Fault locator 21FL 1) only Pos. 16 No 79, no fault locator 0 79 With 79 1 21FL With fault locator 1) 79, 21FL With AR, with fault locator 2 3 1) deliverable with position 6 = 1, 2 or 7 Conformal Coating Supplementary for 7SJ801, 7SJ803 +Z Y 15 for 7SJ802, 7SJ804, 7SJ807, 7SJ808 +Z Y 16 430 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Ordering Information and Accessories A.2 Accessories A.2 Accessories Exchangeable interface modules Name Order number RS232 C53207-A351-D641-1 RS485 C53207-A351-D642-1 FO 820 nm C53207-A351-D643-1 Profibus DP RS485 C53207-A351-D611-1 Profibus DP double ring C53207-A351-D613-1 Modbus RS 485 C53207-A351-D621-1 Modbus 820 nm C53207-A351-D623-1 DNP 3.0 RS 485 C53207-A351-D631-1 DNP 3.0 820 nm C53207-A351-D633-1 Ethernet electrical (EN 100) C53207-A351-D675-2 Ethernet optical (EN 100), 4 ST connectors C53207-A351-D678-1 Ethernet electrical (EN 100, PROFINET IO) C53207-A351-D688-1 Ethernet optical (EN 100, PROFINET IO) C53207-A351-D689-1 Ethernet electrical (EN 100, DNP3 TCP ) C53207-A351-D684-1 Ethernet optical (EN 100, DNP3 TCP), multimode C53207-A351-D686-1 Ethernet optical (EN100, DNP3 TCP), single mode, 24 km C53207-A351-D690-1 Ethernet electrical (EN 100, IEC 60870-5-104 ) C53207-A351-D692-1 Ethernet optical (EN 100, IEC 60870-5-104 ) C53207-A351-D693-1 Ethernet electrical (EN 100, Modbus TCP ) C53207-A351-D696-1 Ethernet optical (EN 100, Modbus TCP ) C53207-A351-D697-1 IEC 60870-5-103 protocoll, redundant, RS485 C53207-A351-D644-1 Ethernet port electrical at port A C53207-A351-D151-1 RS485 FO converter RS485 FO converter Order No. 820 nm, FC-Connector 7XV5650-0AA00 820 nm, with ST-Connector 7XV5650-0BA00 Mounting Rail for 19"-Racks Name Order Number Mounting Rail Set C73165-A63-D200-1 Surface mounting console (converts flush mounting variants into surface mounting variant) Surface mounting console C53207-A356-D850-1 Lithium battery 3 V/1 Ah, type CR 1/2 AA Order No. VARTA 6127 101 301 Panasonic BR-1/2AA Terminals Voltage terminal block C or block E C53207-A406-D181-1 Battery Terminals SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 431 Ordering Information and Accessories A.2 Accessories Voltage terminal block D (inverse print) C53207-A406-D182-1 Current terminal block 4xI C53207-A406-D185-1 Current terminal block 3xI,1xINs (sensitive) C53207-A406-D186-1 Current terminal short circuit links, 3 pieces C53207-A406-D193-1 Voltage terminal short circuit links, 6 pieces C53207-A406-D194-1 Varistor Voltage-limiting resistor for high-impedance differential protection 432 Name Order number 125 Veff, 600 A, 1S/S256 W73028-V3125-A1 240 Veff, 600 A, 1S/S1088 W73028-V3300-A2 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 B Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 434 433 Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting 7SJ801* [kl-uebers-7sx80-1, 1, en_US] Figure B-1 434 Block diagram 7SJ801* SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting 7SJ802* [kl-uebers-7sx80-2, 1, en_US] Figure B-2 Block diagram 7SJ802* SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 435 Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting 7SJ803* [kl-uebers-7sx80-3, 1, en_US] Figure B-3 436 Block diagram 7SJ803* SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting 7SJ804* [kl-uebers-7sx80-4, 1, en_US] Figure B-4 Block diagram 7SJ804* SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 437 Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting 7SJ807* [kl-uebers-7sx80-7, 1, en_US] Figure B-5 *) 438 Block diagram 7SJ807* The shield of the connecting cable is connected directly to the shield cover SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Terminal Assignments B.1 7SJ80 -- Housing for panel flush mounting and cubicle installation and for panel surface mounting 7SJ808* [kl-uebers-7sx80-8, 1, en_US] Figure B-6 *) Block diagram 7SJ808* The shield of the connecting cable is connected directly to the shield cover. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 439 440 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 C Connection Examples C.1 Connection Examples for Current and Voltage Transformers 442 C.2 Connection Examples for SICAM I/O Units 454 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 441 Connection Examples C.1 Connection Examples for Current and Voltage Transformers C.1 Connection Examples for Current and Voltage Transformers [anschl-3-stromwdl-sternpunktstrom-060606, 1, en_US] Figure C-1 Current transformer connections to three current transformers and neutral rpoint current (ground current) (Holmgreen connection) - appropriate for all networks [anschl-2-stromwdl-060606, 1, en_US] Figure C-2 Current transformer connections to two current transformers - only for isolated or resonantgrounded networks [anschl-3-stromwdl-summenstromw-060606, 1, en_US] Figure C-3 442 Current transformer connections to three current transformers, ground current from additional summation current transformer - preferably for effectively or low-resistance grounded networks SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Connection Examples C.1 Connection Examples for Current and Voltage Transformers Important: Grounding of the cable shield must be effected at the cable side The switchover of the current polarity (address 201) also reverses the polarity of the current input IN! [anschl-2-stromwdl-kabelumbauw-060606, 1, en_US] Figure C-4 Current transformer connections to two current transformers - additional cable-type current transformer for sensitive ground fault detection - only for isolated or resonant-grounded networks Important: Grounding of the cable shield must be effected at the cable side The switchover of the current polarity (address 201) also reverses the polarity of the current input IN! [anschl-3-stromwdl-kabelumbauw-060606, 1, en_US] Figure C-5 Current transformer connections to three current transformers - ground current from additional cable-type current transformer for sensitive ground fault detection Important: Grounding of the cable shield must be effected at the cable side The switchover of the current polarity (address 201) also reverses the polarity of the current input INs! SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 443 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-3-stromwdl-3-spannungsw-060606, 1, en_US] Figure C-6 444 Transformer connections to three current transformers and three voltage transformers (phaseto-ground voltages), normal circuit layout - appropriate for all networks SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-3-stromwdl-2-spannung-e-n-wickl-060606, 1, en_US] Figure C-7 Transformer connections to three current transformers, two voltage transformers (phasetophase voltages) and broken delta winding (da-dn) - appropriate for all networks SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 445 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-2-stromwdl-v-schaltung-060606, 1, en_US] Figure C-8 Current transformer connections to two current transformers and as open-delta connection the voltage transformer - for isolated or resonant-grounded networks when no directional ground protection is needed [anschl-3-stromwdl-sternp-v-schaltung-060606, 1, en_US] Figure C-9 Current transformer connections to three current transformers, two voltage transformers in open-deltaconnection, only for isolated or resonant-grounded networks; no directional ground protection since displacement voltage cannot be calculated Note: If the system has only 2 voltage transformers (open-delta connection), the device, too, should be connected in open-delta connection and the unused voltage input should be short-circuited. 446 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-3-stromwdl-kabelumbauw-e-n-wickl-060606, 1, en_US] Figure C-10 Transformer connections to three current transformers, cable-type current transformer and broken delta winding, maximum precision for sensitive ground fault detection Important! Grounding of the cable shield must be effected at the cable side For busbar-side grounding of the current transformers, the current polarity of the device is changed via address 0201. This also reverses the polarity of the current input IN/INs. When using a cable-type current transformer, the connection of k and I at F8 and F7 must be exchanged. [stromwdl-2phasenstrwdl-1erdstrwdl-080211, 1, en_US] Figure C-11 Current transformer connections to two phase-current transformers and a ground-current transformer; the ground current is taken via the highly sensitive and sensitive ground input. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 447 Connection Examples C.1 Connection Examples for Current and Voltage Transformers Important! Grounding of the cable shield must be effected at the cable side For busbar-side grounding of the current transformers, the current polarity of the device is changed via address 0201. This also reverses the polarity of the current input IN/INs. When using a cable-type current transformer, the connection of k and I at F8 and F7 must be exchanged. [7sj80-mess-2erdstroeme-20070301, 1, en_US] Figure C-12 Current transformer connections to two phase currents and two ground currents; IN/INs - ground current of the line, IN2 - ground current of the transformer starpoint Important! Grounding of the cable shield must be effected at the cable side For busbar-side grounding of the current transformers, the current polarity of the device is changed via address 0201. This also reverses the polarity of the current input IN/INs. When using a cable-type current transformer, the connection of k and I at F8 and F7 must be exchanged. 448 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [hochimpedanz-trafowgeerdet-060606, 1, en_US] Figure C-13 High-impedance differential protection for a grounded transformer winding (the illustration shows the partial connection for high-impedance differential protection) [anschl-u1e-u2e-u3e-abgang-20070129, 1, en_US] Figure C-14 Example for the connection type "VAN, VBN, VCN" with voltage connection on the feeder side [anschl-u12-u23-ue-20070129, 1, en_US] Figure C-15 Voltage transformer connections to two voltage transformers (phase-to-phase voltages) and broken delta winding (da-dn) - appropriate for all networks SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 449 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-u1e-u2e-u3e-ss-20070129, 1, en_US] Figure C-16 Example for connection type "VAN, VBN, VCN" busbar-side voltage connection [anschl-uph-usyn-20070129, 1, en_US] Figure C-17 Example for connection type "Vph-n, Vsyn" The connection can be established at any one of the three phases. The phase must be the same for Vph-n and Vsyn. 450 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-u12-u23-ux-20070129, 1, en_US] Figure C-18 Example for connection type "VAB, VBC, Vx" [anschl-u12-u23-20070129, 1, en_US] Figure C-19 Example for connection type "VAB, VBC" SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 451 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-u12-u23-v-schalt-20070129, 1, en_US] Figure C-20 Example for connection type "VAB, VBC" with phase voltage connection as open-delta connection [anschl-u12-u23-usyn-20070129, 1, en_US] Figure C-21 452 Example for connection type "VAB, VBC, VSYN" SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Connection Examples C.1 Connection Examples for Current and Voltage Transformers [anschl-u12-u23-usyn-v-schalt-20070129, 1, en_US] Figure C-22 Example for connection type "VAB, VBC, VSYN" with phase voltage connection as open-delta connection SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 453 Connection Examples C.2 Connection Examples for SICAM I/O Units C.2 Connection Examples for SICAM I/O Units [sicam-io-unit-01-20120731-kn, 1, en_US] Figure C-23 1 2 454 Connection of 2 SICAM I/O units to port A via Y cable (up to 2 SICAM I/O units connectable) Y cable 7KE6000-8GD00-0BA2 RJ45 cable SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 D Current Transformer Requirements The requirements for phase current transformers are usually determined by the overcurrent time protection, particularly by the high-current element settings. Besides, there is a minimum requirement based on experience. The recommendations are given according to the standard IEC 60044-1. The standards IEC 60044-6, BS 3938 and ANSI/IEEE C 57.13 are referred to for converting the requirement into the knee-point voltage and other transformer classes. D.1 Accuracy limiting factors 456 D.2 Class conversion 457 D.3 Cable core balance current transformer 458 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 455 Current Transformer Requirements D.1 Accuracy limiting factors D.1 Accuracy limiting factors Betriebs- und Nennuberstromziffer Required minimum effective accuracy limiting factor but at least 20 mit n' Minimum effective accuracy limiting factor >>Anr Primary pickup value of the high-current element pN Primary nominal transformer current Resulting rated accuracy limiting factor with KALF Rated accuracy limiting factor RBC Connected burden resistance (device and cables) RBN Nominal burden resistance RCt Transformer internal burden resistance Calculation example according to IEC 60044-1 sNom = 1 A KALF = 20 RBC = 0.6 (device and cables) RCt = 3 KALF set to 10, so that: 5P10, 5 VA RBN = 5 (5 VA) mit sNom = secondary transformer nominal current 456 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Current Transformer Requirements D.2 Class conversion D.2 Class conversion Table D-1 Conversion into other classes British Standard BS 3938 ANSI/IEEE C 57.13, Klasse C sNom = 5 A (typical value) IEC 60044-6 (transient response), class TPS K 1 KSSC KALF Classes TPX, TPY, TPZ Calaculation see Section above with: KSSC KALF TP depending on power system and specified closing sequence with SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 withk Knee-point voltage RCt Internal burden resistance RBN Nominal burden resistance sN Secondary nominal transformer current KALF Rated accuracy limiting factor Us.t.max Sec. terminal voltage at 20 pNom Ual Sec. magnetization limit voltage K Dimensioning factor KSSC Factor symmetr. Rated fault current TP Primary time constant 457 Current Transformer Requirements D.3 Cable core balance current transformer D.3 Cable core balance current transformer General The requirements to the cable core balance current transformer are determined by the function "sensitive ground fault detection". The recommendations are given according to the standards IEC 60044-1 and IEC61869-2. Requirements to the cable core balance current transformer according to IEC 60044-1 and IEC61869-2 Transformation ratio, typical It may be necessary to select a different transformation ratio to suit the specific power system and thus the corresponding amount of the maximum ground fault current. 60 / 1 Accuracy limiting factor FS = 10 Power 1 to 4 times the connected burden (device input plus infeeds) Notes concerning the power: The burden of the sensitive ground-current input is very low (0.05 VA or 0.1 VA). Thus, an underburden of more than factor 4 is probable. In this case, clarify the suitability of the class accuracy concerning an important underburden with the transformer manufacturer. If necessary, request the accuracy for the range from 0 VA to the rated burden. This specification is then outside the standard, but in practice, it is possible in most cases. (Relevant standard: IEC 61869-2, Chapter 5.6.201.4 Extended burden range. There, the range 1 VA to rated burden is specified for rated burdens smaller than 15 VA.) Class accuracy Table D-2 Minimum required class accuracy depending on neutral grounding and function operating principle Starpoint isolated compensated high-resistance grounded Function directional Class 1 Class 1 Class 1 Function non-directional Class 3 Class 1 Class 3 Note that the class accuracy according to IEC 61869-2 below 5% Irated (< 50 mA secondary) is not defined in general. For very sensitive directional measurements, Siemens recommends the classes 0.5S or 0.1S that define the class accuracy via an extended current range (up to 1% Irated) (see chapter 5.6.201.5, IEC 61869-2). Another possibility is to correct the phase-angle error of the transformer on the device, if this error is known (see function description Sensitive ground-fault detection). 458 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 E 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 summarized in the following table. E.1 LEDs 460 E.2 Binary Input 462 E.3 Binary Output 463 E.4 Function Keys 464 E.5 Default Display 465 E.6 Protocol-dependent Functions 468 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 459 Default Settings and Protocol-dependent Functions E.1 LEDs E.1 LEDs Table E-1 LEDs Default function Function No. Description LED1 Relay TRIP 511 Relay GENERAL TRIP command LED2 50/51 Ph A PU 1762 50/51 Phase A picked up LED3 50/51 Ph B PU 1763 50/51 Phase B picked up LED4 50/51 Ph C PU 1764 50/51 Phase C picked up LED5 50N/51NPickedup 1765 50N/51N picked up LED6 Failure I 162 Failure: Current Summation Fail I balance 163 Failure: Current Balance Fail Ph. Seq. I 175 Failure: Phase Sequence Current LED7 Not configured 1 No Function configured LED8 Brk OPENED Table E-2 Breaker OPENED 7SJ802* LEDs Default function Function No. Description LED1 Relay TRIP 511 Relay GENERAL TRIP command LED2 50/51 Ph A PU 1762 50/51 Phase A picked up LED3 50/51 Ph B PU 1763 50/51 Phase B picked up LED4 50/51 Ph C PU 1764 50/51 Phase C picked up LED5 50N/51NPickedup 1765 50N/51N picked up LED6 Failure I 162 Failure: Current Summation Fail I balance 163 Failure: Current Balance Fail Ph. Seq. I 175 Failure: Phase Sequence Current LED7 Not configured 1 No Function configured LED8 Brk OPENED Table E-3 Breaker OPENED 7SJ803* LEDs Default function Function No. Description LED1 Relay TRIP 511 Relay GENERAL TRIP command LED2 50/51 Ph A PU 1762 50/51 Phase A picked up 67 A picked up 2692 67/67-TOC Phase A picked up 50/51 Ph B PU 1763 50/51 Phase B picked up 67 B picked up 2693 67/67-TOC Phase B picked up 50/51 Ph C PU 1764 50/51 Phase C picked up LED3 LED4 460 7SJ801* 67 C picked up 2694 67/67-TOC Phase C picked up LED5 50N/51NPickedup 1765 50N/51N picked up LED6 Failure I 162 Failure: Current Summation Fail I balance 163 Failure: Current Balance Fail V balance 167 Failure: Voltage Balance Fail Ph. Seq. I 175 Failure: Phase Sequence Current Fail Ph. Seq. V 176 Failure: Phase Sequence Voltage VT brk. wire 253 Failure VT circuit: broken wire LED7 Not configured 1 No Function configured LED8 Brk OPENED Breaker OPENED SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Default Settings and Protocol-dependent Functions E.1 LEDs Table E-4 7SJ804* LEDs Default function Function No. Description LED1 Relay TRIP 511 Relay GENERAL TRIP command LED2 50/51 Ph A PU 1762 50/51 Phase A picked up 67 A picked up 2692 67/67-TOC Phase A picked up 50/51 Ph B PU 1763 50/51 Phase B picked up 67 B picked up 2693 67/67-TOC Phase B picked up 50/51 Ph C PU 1764 50/51 Phase C picked up 67 C picked up 2694 67/67-TOC Phase C picked up 50N/51NPickedup 1765 50N/51N picked up 67N picked up 2695 67N/67N-TOC picked up Failure I 162 Failure: Current Summation Fail I balance 163 Failure: Current Balance Fail V balance 167 Failure: Voltage Balance Fail Ph. Seq. I 175 Failure: Phase Sequence Current Fail Ph. Seq. V 176 Failure: Phase Sequence Voltage VT brk. wire 253 Failure VT circuit: broken wire LED7 Not configured 1 No Function configured LED8 Brk OPENED LED3 LED4 LED5 LED6 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Breaker OPENED 461 Default Settings and Protocol-dependent Functions E.2 Binary Input E.2 Binary Input Table E-5 Binary input presettings for all devices and ordering variants Binary Input Default function Function No. Description BI1 >BLOCK 50-2 1721 >BLOCK 50-2 >BLOCK 50N-2 1724 >BLOCK 50N-2 >52-b 4602 >52-b contact (OPEN, if bkr is closed) BI2 52Breaker BI3 >52-a 52 Breaker 4601 52Breaker Table E-6 52 Breaker Further binary input presettings for 7SJ802* or 7SJ804* Binary Input Default function Function No. Description BI4 not pre-assigned - - BI5 not pre-assigned - - BI6 not pre-assigned - - BI7 not pre-assigned - - Table E-7 462 >52-a contact (OPEN, if bkr is open) Further binary input presettings for 7SJ807* or 7SJ808* Binary Input Default function Function No. Description BI4 not pre-assigned - - BI5 not pre-assigned - - BI6 not pre-assigned - - BI7 not pre-assigned - - BI8 not pre-assigned - - BI9 not pre-assigned - - BI10 not pre-assigned - - BI11 not pre-assigned - - SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Default Settings and Protocol-dependent Functions E.3 Binary Output E.3 Binary Output Table E-8 Output Relay Presettings for All Devices and Ordering Variants Binary Output Default function Function No. Description BO1 Relay TRIP 511 Relay GENERAL TRIP command BO2 52Breaker 52 Breaker 52Breaker 52 Breaker 79 Close BO3 BO4 BO5 Table E-9 2851 52Breaker 79 - Close command 52 Breaker 79 Close 2851 79 - Close command Failure I 162 Failure: Current Summation Fail I balance 163 Failure: Current Balance Fail V balance 167 Failure: Voltage Balance Fail Ph. Seq. I 175 Failure: Phase Sequence Current Fail Ph. Seq. V 176 Failure: Phase Sequence Voltage VT brk. wire 253 Failure VT circuit: broken wire Relay PICKUP 501 Relay PICKUP Further Output Relay Presettings for 7SJ802* or 7SJ804* Binary Output Default function Function No. Description BO6 not pre-assigned - - BO7 not pre-assigned - - BO8 not pre-assigned - - SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 463 Default Settings and Protocol-dependent Functions E.4 Function Keys E.4 Function Keys Table E-10 464 Applies to All Devices and Ordered Variants Function Keys Default function F1 Display of the operational indications F2 Display of the primary operational measured values F3 Display of the last fault log buffer F4 not pre-assigned F5 not pre-assigned F6 not pre-assigned F7 not pre-assigned F8 not pre-assigned F9 not pre-assigned SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Default Settings and Protocol-dependent Functions E.5 Default Display E.5 Default Display A number of pre-defined measured value pages are available depending on the device type. The start page of the default display appearing after startup of the device can be selected in the device data via parameter 640 Start image DD auswahlen. for the 6-line Display of 7SJ80 [grundbild6zei-mit-u-ohne-erw-mw-20070116, 1, en_US] Figure E-1 Default display of the 7SJ80 for models with V without extended measured values SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 465 Default Settings and Protocol-dependent Functions E.5 Default Display With the V0/IO measurement, the measured ground current IN2 is displayed under N and the ground current IN or INs under Ns. [grundbild6zei-mit-u-und-erw-mw-20070116, 1, en_US] Figure E-2 466 Default display of the 7SJ80 for models with V with extended measured values SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Default Settings and Protocol-dependent Functions E.5 Default Display [grundbild6zei-ohne-u-ohne-erw-mw-20070116, 1, en_US] Figure E-3 Default display of the 7SJ80 for models without V and extended measured values [grundbild6zei-ohne-u-und-erw-mw-20070116, 1, en_US] Figure E-4 Default display of the 7SJ80 for models without V with extended measured values Spontaneous Fault Display After a fault has occurred, the most important fault data are automatically displayed after general device pickup in the order shown in the picture below. [anzeige-spontanmeldungen-im-display-des-geraetes-260602-kn, 1, en_US] Figure E-5 Representation of spontaneous messages on the device display SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 467 Default Settings and Protocol-dependent Functions E.6 Protocol-dependent Functions E.6 Protocol-dependent Functions Protocol Function IEC IEC 60870-5-1 60870-5-1 03, single 03, redundant IEC IEC 61850 PROFINET 60870-5-104 Ethernet (EN Ethernet Ethernet (EN 100) (EN100) 100) Profibus DP DNP 3 TCP DNP3.0 Ethernet Modbus (EN100) ASCII/RTU Operational Yes measured values Yes Yes Yes Yes Yes Yes Yes Metered values Yes Yes Yes Yes Yes Yes Yes Yes Fault recording Yes Yes Yes Yes No No Yes No Remote protection setting No Yes No Yes No No No No User-defined indications and switching objects Yes Yes Yes Yes Yes Yes Yes Yes Time synchroni- Yes zation Yes Yes Yes Yes Yes Yes Yes Messages with time stamp Yes Yes Yes Yes Yes Yes Yes Commissioning aids Data transmission stop Yes Yes Yes Yes No No No No Creating test messages Yes Yes Yes Yes No No No No Physical mode Asynchronous Asynchronous Transmission mode cyclically/ event cyclically/ event cyclically cyclically/ event cyclically cyclically cyclically/ event cyclically/ event(DNP) cyclically(Modbus) Baudrate 1 200 to 115 000 2 400 to 57 600 up to 100 MBaud up to 100 MBaud up to 100 MBaud up to 1.5 MBaud (Lichtwellenleiter) 6 MBaud (RS485) up to 100 MBaud 9600 to 57600(DNP) 300 to 57600(Modbu RS485 optical fiber (double ring) Ethernet TP Ethernet optical fiber Baud rate 468 RS232 RS485 optical fiber RS485 Synchronous Ethernet TP Ethernet TP Ethernet optical fiber Asynchronous Ethernet TP Asynchronous s) RS485 optical fiber SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 F Functions, Settings, Information F.1 Functional Scope 470 F.2 Settings 472 F.3 Information List 501 F.4 Group Alarms 539 F.5 Measured Values 541 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 469 Functions, Settings, Information F.1 Functional Scope F.1 Functional Scope Addr. Parameter Setting Options Default Setting Comments 103 Grp Chge OPTION Disabled Enabled Disabled Setting Group Change Option 104 OSC. FAULT REC. Disabled Enabled Enabled Oscillographic Fault Records 112 Charac. Phase Disabled Definite Time TOC IEC TOC ANSI Definite Time 50/51 113 Charac. Ground Disabled Definite Time TOC IEC TOC ANSI Definite Time 50N/51N 115 67/67-TOC Disabled Definite Time TOC IEC TOC ANSI Definite Time 67, 67-TOC 116 67N/67N-TOC Disabled Definite Time TOC IEC TOC ANSI Definite Time 67N, 67N-TOC 117 Coldload Pickup Disabled Enabled Disabled Cold Load Pickup 122 InrushRestraint Disabled Enabled Disabled 2nd Harmonic Inrush Restraint 127 50 1Ph Disabled Enabled Disabled 50 1Ph 130 S.Gnd.F.Dir.Ch cos / sin V0/I0 mea. cos / sin (sens.) Ground fault dir. characteristic 131 Sens. Gnd Fault Disabled Definite Time User Defined PU Disabled (sensitive) Ground fault 133 INTERM.EF Disabled with Ignd with 3I0 with Ignd,sens. Disabled Intermittent earth fault protection 134 Dir. Interm. EF Disabled Enabled Disabled Dir. Intermittent earth fault protection 135 E Flt(ext) Disabled EPTR Trans. Neutral Disabled Earth Fault(extend) 140 46 Disabled TOC ANSI TOC IEC Definite Time Disabled 46 Negative Sequence Protection 142 49 Disabled No ambient temp No ambient temp 49 Thermal Overload Protection 470 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.1 Functional Scope Addr. Parameter Setting Options Default Setting Comments 150 27/59 Disabled Enabled Disabled 27, 59 Under/Overvoltage Protection 154 81 O/U Disabled Enabled Disabled 81 Over/Underfrequency Protection 155 27/Q-Protection Disabled Enabled Disabled 27 / Q dir. con. Protection 161 25 Function 1 Disabled SYNCHROCHECK Disabled 25 Function group 1 170 50BF Disabled Enabled enabled w/ 3I0> Disabled 50BF Breaker Failure Protection 171 79 Auto Recl. Disabled Enabled Disabled 79 Auto-Reclose Function 172 52 B.WEAR MONIT Disabled Ix-Method 2P-Method I2t-Method Disabled 52 Breaker Wear Monitoring 180 Fault Locator Disabled Enabled Disabled Fault Locator 181 L-sections FL 1 Section 2 Sections 3 Sections 1 Section Line sections for fault locator 182 74 Trip Ct Supv Disabled 2 Binary Inputs 1 Binary Input Disabled 74TC Trip Circuit Supervision 617 ServiProt (CM) Disabled T103 DIGSI T103 Port B usage - FLEXIBLE FKT. 1...20 Flexible Funktion 01 Flexible Funktion 02 Flexible Funktion 03 Flexible Funktion 04 Flexible Funktion 05 Flexible Funktion 06 Flexible Funktion 07 Flexible Funktion 08 Flexible Funktion 09 Flexible Funktion 10 Flexible Funktion 11 Flexible Funktion 12 Flexible Funktion 13 Flexible Funktion 14 Flexible Funktion 15 Flexible Funktion 16 Flexible Funktion 17 Flexible Funktion 18 Flexible Funktion 19 Flexible Funktion 20 Bitte auswahlen Flexible Funktionen 1...20 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 471 Functions, Settings, Information F.2 Settings F.2 Settings Addresses which have an appended "A" can only be changed with DIGSI, under "Additional Settings". The table indicates region-specific default settings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Function Setting Options Default Setting Comments 0 FLEXIBLE FUNC. Flx OFF ON Alarm Only OFF Flexible Function 0 OPERRAT. MODE Flx 3-phase 1-phase no reference 3-phase Mode of Operation 0 BLK f out of r Flx YES NO YES Block while Freq. is out of range 0 MEAS. QUANTITY Flx Please select Current Voltage P forward P reverse Q forward Q reverse Power factor dV/dt rising dV/dt falling Frequency df/dt rising df/dt falling Binray Input Please select Selection of Measured Quantity 0 MEAS. METHOD Flx Fundamental True RMS Positive seq. Negative seq. Zero sequence Ratio I2/I1 Fundamental Selection of Measurement Method 0 PICKUP WITH Flx Exceeding Dropping below Exceeding Pickup with 0 CURRENT Flx Ia Ib Ic In In sensitive In2 Ia Current 472 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 0 VOLTAGE 0 C Setting Options Default Setting Comments Flx Please select Va-n Vb-n Vc-n Va-b Vb-c Vc-a Vn Vx Please select Voltage POWER Flx Ia Va-n Ib Vb-n Ic Vc-n Ia Va-n Power 0 VOLTAGE SYSTEM Flx Phase-Phase Phase-Ground Phase-Phase Voltage System 0 P.U. THRESHOLD Flx 0 P.U. THRESHOLD Flx 0 P.U. THRESHOLD Flx 0.05 .. 40.00 A 2.00 A Pickup Threshold 1A 0.05 .. 40.00 A 2.00 A Pickup Threshold 5A 0.25 .. 200.00 A 10.00 A 1A 0.001 .. 1.500 A 0.100 A 5A 0.005 .. 7.500 A 0.500 A Pickup Threshold 0 P.U. THRESHOLD Flx 2.0 .. 260.0 V 110.0 V Pickup Threshold 0 P.U. THRESHOLD Flx 2.0 .. 200.0 V 110.0 V Pickup Threshold 0 P.U. THRESHOLD Flx 40.00 .. 60.00 Hz 51.00 Hz Pickup Threshold 0 P.U. THRESHOLD Flx 50.00 .. 70.00 Hz 61.00 Hz Pickup Threshold 0 P.U. THRESHOLD Flx 0 P.U. THRESHOLD Flx 0 P.U. THRESHOLD Flx 0 P.U. THRESHOLD Flx -0.99 .. 0.99 0.50 Pickup Threshold 0 P.U. THRESHOLD Flx 15 .. 100 % 20 % Pickup Threshold 0 P.U. THRESHOLD Flx 4 .. 100 V/s 60 V/s Pickup Threshold 0 P.U. THRESHOLD Flx 2.0 .. 260.0 V 110.0 V Pickup Threshold 0 T TRIP DELAY Flx 0.00 .. 3600.00 sec 1.00 sec Trip Time Delay 0A T PICKUP DELAY Flx 0.00 .. 60.00 sec 0.00 sec Pickup Time Delay 0 T PICKUP DELAY Flx 0.00 .. 28800.00 sec 0.00 sec Pickup Time Delay 0A T DROPOUT DELAY Flx 0.00 .. 60.00 sec 0.00 sec Dropout Time Delay 0A BLK.by Vol.Loss Flx NO YES YES Block in case of Meas.Voltage Loss 0A DROPOUT RATIO Flx 0.70 .. 0.99 0.95 Dropout Ratio 0A DROPOUT RATIO Flx 1.01 .. 3.00 1.05 Dropout Ratio 0 DO differential Flx 0.02 .. 1.00 Hz 0.03 Hz Dropout differential 201 CT Starpoint P.System Data 1 towards Line towards Busbar towards Line CT Starpoint 202 Vnom PRIMARY P.System Data 1 0.10 .. 800.00 kV 20.00 kV Rated Primary Voltage 203 Vnom SECONDARY P.System Data 1 34 .. 225 V 100 V Rated Secondary Voltage (L-L) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 0.10 .. 20.00 Hz/s 5.00 Hz/s Pickup Threshold 1A 2.0 .. 10000.0 W 200.0 W Pickup Threshold 5A 10.0 .. 50000.0 W 1000.0 W 1A 2.0 .. 10000.0 VAR 200.0 VAR 5A 10.0 .. 50000.0 VAR 1000.0 VAR Pickup Threshold 473 Functions, Settings, Information F.2 Settings Addr. Parameter Function 204 CT PRIMARY 205 Setting Options Default Setting Comments P.System Data 1 10 .. 50000 A 400 A CT Rated Primary Current CT SECONDARY P.System Data 1 1A 5A 1A CT Rated Secondary Current 206A Vph / Vdelta P.System Data 1 1.00 .. 3.00 1.73 Matching ratio Phase-VT To Open-Delta-VT 207 Vol. Symmetry P.System Data 1 NO YES NO Assumption voltage symmetry 209 PHASE SEQ. P.System Data 1 ABC ACB ABC Phase Sequence 210A TMin TRIP CMD P.System Data 1 0.01 .. 32.00 sec 0.15 sec Minimum TRIP Command Duration 211A TMax CLOSE CMD P.System Data 1 0.01 .. 32.00 sec 1.00 sec Maximum Close Command Duration 212 BkrClosed I MIN P.System Data 1 1A 0.04 .. 1.00 A 0.04 A 5A 0.20 .. 5.00 A 0.20 A Closed Breaker Min. Current Threshold 213 VT Connect. 3ph P.System Data 1 Van, Vbn, Vcn Vab, Vbc, VGnd Vab, Vbc, VSyn Vab, Vbc Vph-g, VSyn Vab, Vbc, Vx Van, Vbn, Vcn VT Connection, threephase 214 Rated Frequency P.System Data 1 50 Hz 60 Hz 50 Hz Rated Frequency 215 Distance Unit P.System Data 1 km Miles km Distance measurement unit 217 Ignd-CT PRIM P.System Data 1 1 .. 50000 A 60 A Ignd-CT rated primary current 218 Ignd-CT SEC P.System Data 1 1A 5A 1A Ignd-CT rated secondary current 220 Threshold BI 1 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 1 221 Threshold BI 2 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 2 222 Threshold BI 3 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 3 223 Threshold BI 4 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 4 224 Threshold BI 5 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 5 225 Threshold BI 6 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 6 474 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 226 Threshold BI 7 227 Setting Options Default Setting Comments P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 7 Threshold BI 8 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 8 228 Threshold BI 9 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 9 229 Threshold BI 10 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 10 230 Threshold BI 11 P.System Data 1 Thresh. BI 176V Thresh. BI 88V Thresh. BI 19V Thresh. BI 176V Threshold for Binary Input 11 232 VXnom PRIMARY P.System Data 1 0.10 .. 800.00 kV 20.00 kV Rated Primary Voltage X 233 VXnom SECONDARY P.System Data 1 100 .. 225 V 100 V Rated Secondary Voltage X 235A ATEX100 P.System Data 1 NO YES YES Storage of th. Replicas w/o Power Supply 238 Ignd2-CT PRIM. P.System Data 1 1 .. 50000 A 400 A Ignd2-CT rated primary c. (conn. to I2) 239 Ignd2-CT SEC. P.System Data 1 1A 5A 1A Ignd2-CT rated secondary current (I2) 250A 50/51 2-ph prot P.System Data 1 OFF ON OFF 50, 51 Time Overcurrent with 2ph. prot. 251A CT Connect. P.System Data 1 A, B, C, (Gnd) A,G2,C,G; G->B A,G2,C,G; G2->B A, B, C, (Gnd) CT Connection 252 Ph LPCT pol. P.System Data 1 not reversed reversed not reversed Phase LPCT orientation / polarity 260 Ir-52 P.System Data 1 10 .. 50000 A 125 A Rated Normal Current (52 Breaker) 261 OP.CYCLES AT Ir P.System Data 1 100 .. 1000000 10000 Switching Cycles at Rated Normal Current 262 Isc-52 P.System Data 1 10 .. 100000 A 25000 A Rated Short-Circuit Breaking Current 263 OP.CYCLES Isc P.System Data 1 1 .. 1000 50 Switch. Cycles at Rated Short-Cir. Curr. 264 Ix EXPONENT P.System Data 1 1.0 .. 3.0 2.0 Exponent for the IxMethod 265 Cmd.via control P.System Data 1 (Einstellmoglichnone keiten anwendungsabhangig) 52 B.Wear: Open Cmd. via Control Device 266 T 52 BREAKTIME P.System Data 1 1 .. 600 ms 80 ms Breaktime (52 Breaker) 267 T 52 OPENING P.System Data 1 1 .. 500 ms 65 ms Opening Time (52 Breaker) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 C 475 Functions, Settings, Information F.2 Settings Addr. Parameter Function 280 Holmgr. for i 302 Setting Options Default Setting Comments P.System Data 1 NO YES NO Holmgreen-conn. (for fast sum-i-monit.) CHANGE Change Group Group A Group B Group C Group D Binary Input Protocol Group A Change to Another Setting Group 310 Iph-PRIM ref. P.System Data 1 10 .. 50000 A 400 A Primary refer. phase current for prot. 311 Iph-LPCT PRIM P.System Data 1 1 .. 5000 A 400 A Rated primary phase current LPCT 312 Ignd-PRIM ref. P.System Data 1 1 .. 50000 A 60 A Primary refer. ground current for prot. 313 Ignd-LPCT PRIM P.System Data 1 0.01 .. 5000.00 A 2.00 A Rated primary ground current LPCT 314 Vph-LPCT SEC P.System Data 1 10.0 .. 1000.0 mV 225.0 mV Rated secondary phase voltage LPCT 315 Vgnd-LPCT SEC P.System Data 1 10.0 .. 1000.0 mV 225.0 mV Rated secondary ground voltage LPCT 320A Corr.factor IL1 P.System Data 1 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IL1 321A Corr.factor IL2 P.System Data 1 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IL2 322A Corr.factor IL3 P.System Data 1 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IL3 323A Corr.factor IE P.System Data 1 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IE 324A Corr.factor IEE P.System Data 1 0.9000 .. 1.1000 1.0000 Correction factor for magnitude IEE 330 V-LPVT SEC P.System Data 1 3.00 .. 17.00 V 3.25 V rated secondary voltage LPVT 332A V-LPVT PHA P.System Data 1 -10.00 .. 10.00 0.00 phase angle LPVT 401 WAVEFORMTRIGGER Osc. Fault Rec. Save w. Pickup Save w. TRIP Start w. TRIP Save w. Pickup Waveform Capture 402 WAVEFORM DATA Osc. Fault Rec. Fault event Pow.Sys.Flt. Fault event Scope of Waveform Data 403 MAX. LENGTH Osc. Fault Rec. 0.30 .. 5.00 sec 2.00 sec Max. length of a Waveform Capture Record 404 PRE. TRIG. TIME Osc. Fault Rec. 0.05 .. 0.50 sec 0.25 sec Captured Waveform Prior to Trigger 405 POST REC. TIME Osc. Fault Rec. 0.05 .. 0.50 sec 0.10 sec Captured Waveform after Event 406 BinIn CAPT.TIME Osc. Fault Rec. 0.10 .. 5.00 sec; 0.50 sec Capture Time via Binary Input 610 FltDisp.LED/LCD Device, General Target on PU Target on TRIP Target on PU Fault Display on LED / LCD 476 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 611 Spont. FltDisp. 613A Setting Options Default Setting Comments Device, General YES NO NO Spontaneous display of flt.annunciations Gnd O/Cprot. w. P.System Data 1 Ignd (measured) 3I0 (calcul.) Ignd (measured) Ground Overcurrent protection with 614A OP. QUANTITY 59 P.System Data 1 Vphph Vph-n V1 V2 Vphph Opera. Quantity for 59 Overvolt. Prot. 615A OP. QUANTITY 27 P.System Data 1 V1 Vphph Vph-n V1 Opera. Quantity for 27 Undervolt. Prot. 616 STATIC GEN. P.System Data 1 YES NO NO Static or non self-exc. Asyn. Generator 640 Start image DD Device, General image 1 image 2 image 3 image 4 image 5 image 6 image 1 Start image Default Display 651 ParEN100(LC)blk Device, General OFF ON OFF DIGSI-config. over EN100 (LC) blocked 660 IP adr[0](Prim) Device, General 0 .. 255 0 IP address [0] (NTPPrimary) 661 IP adr[1](Prim) Device, General 0 .. 255 0 IP address [1] (NTPPrimary) 662 IP adr[2](Prim) Device, General 0 .. 255 0 IP address [2] (NTPPrimary) 663 IP adr[3](Prim) Device, General 0 .. 255 0 IP address [3] (NTPPrimary) 664 IP adr[0] (Sec) Device, General 0 .. 255 0 IP address [0] (NTPSekundary) 665 IP adr[1] (Sec) Device, General 0 .. 255 0 IP address [1] (NTPSekundary) 666 IP adr[2] (Sec) Device, General 0 .. 255 0 IP address [2] (NTPSekundary) 667 IP adr[3] (Sec) Device, General 0 .. 255 0 IP address [3] (NTPSekundary) 668 Client activ Device, General OFF ON OFF Client activ 669 Daylight Set Device, General OFF ON OFF Daylight Set 670 Offset TZ/min Device, General -1440 .. 1440 min 60 min Offset for time zone in minutes 671 Offset DayT/min Device, General -1440 .. 1440 min 60 min Offset for daylight in minutes 672 W2S month Device, General 1 .. 12 3 month of time set winter to summer 673 W2S week Device, General 1 .. 5 5 week of time set winter to summer SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 C 477 Functions, Settings, Information F.2 Settings Addr. Parameter Function 674 W2S day 675 Setting Options Default Setting Comments Device, General Monday Tuesday Wednesday Thursday Friday Saturday Sunday Sunday day of time set winter to summer W2S hour Device, General 1 .. 24 2 hour of time set winter to summer 676 S2W month Device, General 1 .. 12 10 month of time set summer to winter 677 S2W week Device, General 1 .. 5 5 week of time set summer to winter 678 S2W day Device, General Monday Tuesday Wednesday Thursday Friday Saturday Sunday Sunday day of time set summer to winter 679 S2W hour Device, General 1 .. 24 3 hour of time set summer to winter 700 GOOSE-Stop Device, General YES NO NO GOOSE-Stop 1101 FullScaleVolt. P.System Data 2 0.10 .. 800.00 kV 20.00 kV Measurem:FullScaleVoltage(Equipm.rating) 1102 FullScaleCurr. P.System Data 2 10 .. 50000 A 400 A Measurem:FullScaleCurrent(Equipm.rating) 1103 RE/RL P.System Data 2 -0.33 .. 7.00 1.00 Zero seq. compensating factor RE/RL 1104 XE/XL P.System Data 2 -0.33 .. 7.00 1.00 Zero seq. compensating factor XE/XL 1105 x' P.System Data 2 1A 0.0050 .. 15.0000 /mi 0.2420 /mi feeder reactance per mile: x' 5A 0.0010 .. 3.0000 /mi 0.0484 /mi 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km 1A 0.40 .. 10.00 A 2.50 A 5A 2.00 .. 50.00 A 12.50 A 1106 1107 x' I MOTOR START P.System Data 2 P.System Data 2 C feeder reactance per km: x' Motor Start Current (Block 49, Start 48) 1108 P,Q sign P.System Data 2 not reversed reversed not reversed P,Q operational measured values sign 1109 Line angle P.System Data 2 10 .. 89 85 Line angle 1110 Line length P.System Data 2 0.1 .. 1000.0 km 100.0 km Line length in kilometer 1111 Line length P.System Data 2 0.1 .. 650.0 Miles 62.1 Miles Line length in miles 478 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 1201 FCT 50/51 1202 C Setting Options Default Setting Comments 50/51 Overcur. ON OFF ON 50, 51 Phase Time Overcurrent 50-2 PICKUP 50/51 Overcur. 1A 0.10 .. 35.00 A; 4.00 A 50-2 Pickup 0.50 .. 175.00 A; 20.00 A 1203 50-2 DELAY 50/51 Overcur. 1204 50-1 PICKUP 50/51 Overcur. 1A 5A 5A 0.00 .. 60.00 sec; 0.00 sec 50-2 Time Delay 0.10 .. 35.00 A; 1.00 A 50-1 Pickup 0.50 .. 175.00 A; 5.00 A 1205 50-1 DELAY 50/51 Overcur. 0.00 .. 60.00 sec; 0.50 sec 50-1 Time Delay 1207 51 PICKUP 50/51 Overcur. 1A 0.10 .. 4.00 A 1.00 A 51 Pickup 0.50 .. 20.00 A 5.00 A 1208 51 TIME DIAL 50/51 Overcur. 0.05 .. 3.20 sec; 0.50 sec 51 Time Dial 1209 51 TIME DIAL 50/51 Overcur. 0.50 .. 15.00 ; 5.00 51 Time Dial 1210 51 Drop-out 50/51 Overcur. Instantaneous Disk Emulation Disk Emulation Drop-out characteristic 1211 51 IEC CURVE 50/51 Overcur. Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1212 51 ANSI CURVE 50/51 Overcur. Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1213A MANUAL CLOSE 50/51 Overcur. 50-3 instant. 50-2 instant. 50 -1 instant. 51 instant. Inactive 50-2 instant. Manual Close Mode 1214A 50-2 active 50/51 Overcur. Always with 79 active Always 50-2 active 1215A 50 T DROP-OUT 50/51 Overcur. 0.00 .. 60.00 sec 0.00 sec 50 Drop-Out Time Delay 1216A 50-3 active 50/51 Overcur. Always with 79 active Always 50-3 active 1217 50/51 Overcur. 1A 1.00 .. 35.00 A; A 50-3 Pickup 5.00 .. 175.00 A; A 5A 50-3 PICKUP 5A 1218 50-3 DELAY 50/51 Overcur. 0.00 .. 60.00 sec; 0.00 sec 50-3 Time Delay 1219A 50-3 measurem. 50/51 Overcur. Fundamental True RMS Instantaneous Fundamental 50-3 measurement of 1220A 50-2 measurem. 50/51 Overcur. Fundamental True RMS Fundamental 50-2 measurement of 1221A 50-1 measurem. 50/51 Overcur. Fundamental True RMS Fundamental 50-1 measurement of 1222A 51 measurem. 50/51 Overcur. Fundamental True RMS Fundamental 51 measurement of SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 479 Functions, Settings, Information F.2 Settings Addr. Parameter Function 1223 VOLT. INFLUENCE 1224 C Setting Options Default Setting Comments 50/51 Overcur. NO Volt. controll. Volt. restraint NO 51V Voltage Influence 51V V< 50/51 Overcur. 10.0 .. 125.0 V 75.0 V 51V V< Threshold for Release Ip 1301 FCT 50N/51N 50/51 Overcur. ON OFF ON 50N, 51N Ground Time Overcurrent 1302 50N-2 PICKUP 50/51 Overcur. 1A 0.05 .. 35.00 A; 0.50 A 50N-2 Pickup 0.25 .. 175.00 A; 2.50 A 5A 1303 50N-2 DELAY 50/51 Overcur. 0.00 .. 60.00 sec; 0.10 sec 50N-2 Time Delay 1304 50N-1 PICKUP 50/51 Overcur. 1A 0.05 .. 35.00 A; 0.20 A 50N-1 Pickup 0.25 .. 175.00 A; 1.00 A 1305 50N-1 DELAY 50/51 Overcur. 1307 51N PICKUP 50/51 Overcur. 1A 5A 5A 0.00 .. 60.00 sec; 0.50 sec 50N-1 Time Delay 0.05 .. 4.00 A 0.20 A 51N Pickup 0.25 .. 20.00 A 1.00 A 1308 51N TIME DIAL 50/51 Overcur. 0.05 .. 3.20 sec; 0.20 sec 51N Time Dial 1309 51N TIME DIAL 50/51 Overcur. 0.50 .. 15.00 ; 5.00 51N Time Dial 1310 51N Drop-out 50/51 Overcur. Instantaneous Disk Emulation Disk Emulation Drop-Out Characteristic 1311 51N IEC CURVE 50/51 Overcur. Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1312 51N ANSI CURVE 50/51 Overcur. Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1313A MANUAL CLOSE 50/51 Overcur. 50N-3 instant. 50N-2 instant. 50N-1 instant. 51N instant. Inactive 50N-2 instant. Manual Close Mode 1314A 50N-2 active 50/51 Overcur. Always With 79 Active Always 50N-2 active 1315A 50N T DROP-OUT 50/51 Overcur. 0.00 .. 60.00 sec 0.00 sec 50N Drop-Out Time Delay 1316A 50N-3 active 50/51 Overcur. Always with 79 active Always 50N-3 active 1317 50N-3 PICKUP 50/51 Overcur. 0.25 .. 35.00 A; A 50N-3 Pickup 1318 50N-3 DELAY 50/51 Overcur. 0.00 .. 60.00 sec; 0.05 sec 50N-3 Time Delay 1319A 50N-3 measurem. 50/51 Overcur. Fundamental True RMS Instantaneous Fundamental 50N-3 measurement of 1320A 50N-2 measurem. 50/51 Overcur. Fundamental True RMS Fundamental 50N-2 measurement of 480 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 1321A 50N-1 measurem. Setting Options Default Setting Comments 50/51 Overcur. Fundamental True RMS Fundamental 50N-1 measurement of 1322A 51N measurem. 50/51 Overcur. Fundamental True RMS Fundamental 51N measurement of 1501 FCT 67/67-TOC 67 Direct. O/C OFF ON OFF 67, 67-TOC Phase Time Overcurrent 1502 67-2 PICKUP 67 Direct. O/C 1A 0.10 .. 35.00 A; 2.00 A 67-2 Pickup 5A 0.50 .. 175.00 A; 10.00 A 1503 67-2 DELAY 67 Direct. O/C 1504 67-1 PICKUP 67 Direct. O/C 1505 67-1 DELAY 67 Direct. O/C 1507 67-TOC PICKUP 67 Direct. O/C C 0.00 .. 60.00 sec; 0.10 sec 67-2 Time Delay 1A 0.10 .. 35.00 A; 1.00 A 67-1 Pickup 5A 0.50 .. 175.00 A; 5.00 A 0.00 .. 60.00 sec; 0.50 sec 67-1Time Delay 1A 0.10 .. 4.00 A 1.00 A 67-TOC Pickup 5A 0.50 .. 20.00 A 5.00 A 1508 67 TIME DIAL 67 Direct. O/C 0.05 .. 3.20 sec; 0.50 sec 67-TOC Time Dial 1509 67 TIME DIAL 67 Direct. O/C 0.50 .. 15.00 ; 5.00 67-TOC Time Dial 1510 67-TOC Drop-out 67 Direct. O/C Instantaneous Disk Emulation Disk Emulation Drop-Out Characteristic 1511 67- IEC CURVE 67 Direct. O/C Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1512 67- ANSI CURVE 67 Direct. O/C Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 1513A MANUAL CLOSE 67 Direct. O/C 67-3 instant. 67-2 instant. 67-1 instant. 67-TOC instant. Inactive 67-2 instant. Manual Close Mode 1514A 67-2 active 67 Direct. O/C with 79 active always always 67-2 active 1518A 67 T DROP-OUT 67 Direct. O/C 0.00 .. 60.00 sec 0.00 sec 67 Drop-Out Time Delay 1519A ROTATION ANGLE 67 Direct. O/C -180 .. 180 45 Rotation Angle of Reference Voltage 1520A 67-2 MEASUREM. 67 Direct. O/C Fundamental True RMS Fundamental 67-2 measurement of 1521A 67-1 MEASUREM. 67 Direct. O/C Fundamental True RMS Fundamental 67-1 measurement of 1522A 67-TOC MEASUR. 67 Direct. O/C Fundamental True RMS Fundamental 67-TOC measurement of 1523 67 Direct. O/C Forward Reverse Non-Directional Forward 67-2 Direction 67-2 Direction SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 481 Functions, Settings, Information F.2 Settings Addr. Parameter Function 1524 67-1 Direction 1525 1526 Setting Options Default Setting Comments 67 Direct. O/C Forward Reverse Non-Directional Forward 67-1 Direction 67-TOC Direct. 67 Direct. O/C Forward Reverse Non-Directional Forward 67-TOC Direction 67-3 Direction 67 Direct. O/C Forward Reverse Non-Directional Forward 67-3 Direction 1527A 67-3 MEASUREM. 67 Direct. O/C Fundamental True RMS Fundamental 67-3 measurement of 1528 67 Direct. O/C 1A 1.00 .. 35.00 A; A 67-3 Pickup 5A 5.00 .. 175.00 A; A 67-3 PICKUP C 1529 67-3 DELAY 67 Direct. O/C 0.00 .. 60.00 sec; 0.00 sec 67-3 Time Delay 1530 67 67 Direct. O/C 1.00 .. 20.00 I/Ip; 0.01 .. 999.00 TD 67 1531 MofPU Res T/Tp 67 Direct. O/C 0.05 .. 0.95 I/Ip; 0.01 .. 999.00 TD Multiple of Pickup <-> T/Tp 1532A 67-3 active 67 Direct. O/C always with 79 active always 67-3 active 1601 FCT 67N/67N-TOC 67 Direct. O/C OFF ON OFF 67N, 67N-TOC Ground Time Overcurrent 1602 67N-2 PICKUP 67 Direct. O/C 1A 0.05 .. 35.00 A; 0.50 A 67N-2 Pickup 5A 0.25 .. 175.00 A; 2.50 A 1603 67N-2 DELAY 67 Direct. O/C 1604 67N-1 PICKUP 67 Direct. O/C 1605 67N-1 DELAY 67 Direct. O/C 1607 67N-TOC PICKUP 67 Direct. O/C 1608 67N-TOC T-DIAL 67 Direct. O/C 1609 67N-TOC T-DIAL 1610 0.00 .. 60.00 sec; 0.10 sec 67N-2 Time Delay 1A 0.05 .. 35.00 A; 0.20 A 67N-1 Pickup 5A 0.25 .. 175.00 A; 1.00 A 0.00 .. 60.00 sec; 0.50 sec 67N-1 Time Delay 1A 0.05 .. 4.00 A 0.20 A 67N-TOC Pickup 5A 0.25 .. 20.00 A 1.00 A 0.05 .. 3.20 sec; 0.20 sec 67N-TOC Time Dial 67 Direct. O/C 0.50 .. 15.00 ; 5.00 67N-TOC Time Dial 67N-TOC DropOut 67 Direct. O/C Instantaneous Disk Emulation Disk Emulation Drop-Out Characteristic 1611 67N-TOC IEC 67 Direct. O/C Normal Inverse Very Inverse Extremely Inv. Long Inverse Normal Inverse IEC Curve 1612 67N-TOC ANSI 67 Direct. O/C Very Inverse Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. Very Inverse ANSI Curve 482 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 1613A MANUAL CLOSE Setting Options Default Setting Comments 67 Direct. O/C 67N-3 instant. 67N-2 instant. 67N-1 instant. 67N-TOC instant Inactive 67N-2 instant. Manual Close Mode 1614A 67N-2 active 67 Direct. O/C always with 79 active always 67N-2 active 1617 67 Direct. O/C with VN and IN with V2 and I2 with VN and IN Ground Polarization 1618A 67N T DROP-OUT 67 Direct. O/C 0.00 .. 60.00 sec 0.00 sec 67N Drop-Out Time Delay 1619A ROTATION ANGLE 67 Direct. O/C -180 .. 180 -45 Rotation Angle of Reference Voltage 1620A 67N-2 MEASUREM. 67 Direct. O/C Fundamental True RMS Fundamental 67N-2 measurement of 1621A 67N-1 MEASUREM. 67 Direct. O/C Fundamental True RMS Fundamental 67N-1 measurement of 1622A 67N-TOC MEASUR. 67 Direct. O/C Fundamental True RMS Fundamental 67N-TOC measurement of 1623 67N-2 Direction 67 Direct. O/C Forward Reverse Non-Directional Forward 67N-2 Direction 1624 67N-1 Direction 67 Direct. O/C Forward Reverse Non-Directional Forward 67N-1 Direction 1625 67N-TOC Direct. 67 Direct. O/C Forward Reverse Non-Directional Forward 67N-TOC Direction 1626 67N-3 Direction 67 Direct. O/C Forward Reverse Non-Directional Forward 67N-3 Direction 1627A 67N-3 MEASUREM. 67 Direct. O/C Fundamental True RMS Fundamental 67N-3 measurement of 1628 67N-3 PICKUP 67 Direct. O/C 0.50 .. 35.00 A; A 67N-3 Pickup 1629 67N-3 DELAY 67 Direct. O/C 0.00 .. 60.00 sec; 0.00 sec 67N-3 Time Delay 1630 M.of PU TD 67 Direct. O/C 1.00 .. 20.00 I/Ip; 0.01 .. 999.00 TD Multiples of PU Time-Dial 1631 I/IEp Rf T/TEp 67 Direct. O/C 0.05 .. 0.95 I/Ip; 0.01 .. 999.00 TD 67N TOC 1632A 67N-3 active 67 Direct. O/C always with 79 active always 67N-3 active 67N POLARIZAT. C 1701 COLDLOAD PICKUP ColdLoadPickup OFF ON OFF Cold-Load-Pickup Function 1702 Start Condition ColdLoadPickup No Current Breaker Contact 79 ready No Current Start Condition 1703 CB Open Time ColdLoadPickup 0 .. 21600 sec 3600 sec Circuit Breaker OPEN Time 1704 Active Time ColdLoadPickup 0 .. 21600 sec 3600 sec Active Time SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 483 Functions, Settings, Information F.2 Settings Addr. Parameter Function C 1705 Stop Time ColdLoadPickup 1801 50c-2 PICKUP ColdLoadPickup 1A 5A Setting Options Default Setting Comments 1 .. 600 sec; 600 sec Stop Time 0.10 .. 35.00 A; 10.00 A 50c-2 Pickup 0.50 .. 175.00 A; 50.00 A 1802 50c-2 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.00 sec 50c-2 Time Delay 1803 50c-1 PICKUP ColdLoadPickup 1A 0.10 .. 35.00 A; 2.00 A 50c-1 Pickup 0.50 .. 175.00 A; 10.00 A 1804 50c-1 DELAY ColdLoadPickup 1805 51c PICKUP ColdLoadPickup 1A 5A 5A 0.00 .. 60.00 sec; 0.30 sec 50c-1 Time Delay 51c Pickup 0.10 .. 4.00 A 1.50 A 0.50 .. 20.00 A 7.50 A 1806 51c TIME DIAL ColdLoadPickup 0.05 .. 3.20 sec; 0.50 sec 51c Time dial 1807 51c TIME DIAL ColdLoadPickup 0.50 .. 15.00 ; 5.00 51c Time dial 1808 50c-3 PICKUP ColdLoadPickup 1A 1.00 .. 35.00 A; A 50c-3 Pickup 5.00 .. 175.00 A; A 5A 1809 50c-3 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.00 sec 50c-3 Time Delay 1901 50Nc-2 PICKUP ColdLoadPickup 1A 0.05 .. 35.00 A; 7.00 A 50Nc-2 Pickup 0.25 .. 175.00 A; 35.00 A 5A 1902 50Nc-2 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.00 sec 50Nc-2 Time Delay 1903 50Nc-1 PICKUP ColdLoadPickup 1A 0.05 .. 35.00 A; 1.50 A 50Nc-1 Pickup 0.25 .. 175.00 A; 7.50 A 1904 50Nc-1 DELAY ColdLoadPickup 1905 51Nc PICKUP ColdLoadPickup 1A 5A 5A 0.00 .. 60.00 sec; 0.30 sec 50Nc-1 Time Delay 51Nc Pickup 0.05 .. 4.00 A 1.00 A 0.25 .. 20.00 A 5.00 A 1906 51Nc T-DIAL ColdLoadPickup 0.05 .. 3.20 sec; 0.50 sec 51Nc Time Dial 1907 51Nc T-DIAL ColdLoadPickup 0.50 .. 15.00 ; 5.00 51Nc Time Dial 1908 50Nc-3 PICKUP ColdLoadPickup 0.05 .. 35.00 A; A 50Nc-3 Pickup 1909 50Nc-3 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.00 sec 50Nc-3 Time Delay 2001 67c-2 PICKUP ColdLoadPickup 1A 0.10 .. 35.00 A; 10.00 A 67c-2 Pickup 0.50 .. 175.00 A; 50.00 A 5A 2002 67c-2 DELAY ColdLoadPickup 2003 67c-1 PICKUP ColdLoadPickup 1A 5A 0.00 .. 60.00 sec; 0.00 sec 67c-2 Time Delay 0.10 .. 35.00 A; 2.00 A 67c-1 Pickup 0.50 .. 175.00 A; 10.00 A 2004 67c-1 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.30 sec 67c-1 Time Delay 2005 67c-TOC PICKUP ColdLoadPickup 1A 0.10 .. 4.00 A 1.50 A 67c Pickup 0.50 .. 20.00 A 7.50 A 2006 67c-TOC T-DIAL ColdLoadPickup 0.05 .. 3.20 sec; 0.50 sec 67c Time Dial 2007 67c-TOC T-DIAL ColdLoadPickup 0.50 .. 15.00 ; 5.00 67c Time Dial 2008 67c-3 PICKUP ColdLoadPickup 1A 1.00 .. 35.00 A; A 67c-3 Pickup 5.00 .. 175.00 A; A 2009 67c-3 DELAY ColdLoadPickup 2101 67Nc-2 PICKUP ColdLoadPickup 1A 5A 5A 5A 2102 67Nc-2 DELAY ColdLoadPickup 2103 67Nc-1 PICKUP ColdLoadPickup 1A 5A 0.00 .. 60.00 sec; 0.00 sec 67c-3 Time Delay 0.05 .. 35.00 A; 7.00 A 67Nc-2 Pickup 0.25 .. 175.00 A; 35.00 A 0.00 .. 60.00 sec; 0.00 sec 67Nc-2 Time Delay 0.05 .. 35.00 A; 1.50 A 67Nc-1 Pickup 0.25 .. 175.00 A; 7.50 A 2104 67Nc-1 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.30 sec 67Nc-1 Time Delay 2105 67Nc-TOC PICKUP ColdLoadPickup 1A 0.05 .. 4.00 A 1.00 A 67Nc-TOC Pickup 0.25 .. 20.00 A 5.00 A 5A 484 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function C 2106 67Nc-TOC T-DIAL ColdLoadPickup 0.05 .. 3.20 sec; 0.50 sec 67Nc-TOC Time Dial 2107 67Nc-TOC T-DIAL ColdLoadPickup 0.50 .. 15.00 ; 5.00 67Nc-TOC Time Dial 2108 67Nc-3 PICKUP ColdLoadPickup 0.25 .. 35.00 A; A 67Nc-3 Pickup 2109 67Nc-3 DELAY ColdLoadPickup 0.00 .. 60.00 sec; 0.00 sec 67Nc-3 Time Delay 2201 INRUSH REST. 50/51 Overcur. OFF ON OFF Inrush Restraint 2202 2nd HARMONIC 50/51 Overcur. 10 .. 45 % 15 % 2nd. harmonic in % of fundamental 2203 CROSS BLOCK 50/51 Overcur. NO YES NO Cross Block 2204 CROSS BLK TIMER 50/51 Overcur. 0.00 .. 180.00 sec 0.00 sec Cross Block Time 2205 I Max 50/51 Overcur. 1A 0.30 .. 25.00 A 7.50 A 1.50 .. 125.00 A 37.50 A Maximum Current for Inrush Restraint OFF ON OFF 50 1Ph 1A 0.001 .. 1.600 A; 0.300 A 50 1Ph-2 Pickup 5A 0.005 .. 8.000 A; 1.500 A 5A 2701 50 1Ph 50 1Ph 2703 50 1Ph-2 PICKUP 50 1Ph 2704 50 1Ph-2 DELAY 50 1Ph 2706 50 1Ph-1 PICKUP 50 1Ph Setting Options Default Setting Comments 0.00 .. 60.00 sec; 0.10 sec 50 1Ph-2 Time Delay 1A 0.001 .. 1.600 A; 0.100 A 50 1Ph-1 Pickup 5A 0.005 .. 8.000 A; 0.500 A 2707 50 1Ph-1 DELAY 50 1Ph 0.00 .. 60.00 sec; 0.50 sec 50 1Ph-1 Time Delay 3101 Sens. Gnd Fault Sens. Gnd Fault OFF ON ON with GF log Alarm Only OFF (Sensitive) Ground Fault 3102 CT Err. I1 Sens. Gnd Fault 1A 0.001 .. 1.600 A 0.050 A 5A 0.005 .. 8.000 A 0.250 A Current I1 for CT Angle Error 0.05 .. 35.00 A 1.00 A 0.25 .. 175.00 A 5.00 A Current I1 for CT Angle Error 3102 CT Err. I1 Sens. Gnd Fault 1A 5A 3103 CT Err. F1 Sens. Gnd Fault 0.0 .. 5.0 0.0 CT Angle Error at I1 3104 CT Err. I2 Sens. Gnd Fault 1A 0.001 .. 1.600 A 1.000 A 5A 0.005 .. 8.000 A 5.000 A Current I2 for CT Angle Error 0.05 .. 35.00 A 10.00 A 0.25 .. 175.00 A 50.00 A Current I2 for CT Angle Error 3104 CT Err. I2 Sens. Gnd Fault 1A 5A 3105 CT Err. F2 Sens. Gnd Fault 0.0 .. 5.0 0.0 CT Angle Error at I2 3106 VPH MIN Sens. Gnd Fault 10 .. 100 V 40 V L-Gnd Voltage of Faulted Phase Vph Min 3107 VPH MAX Sens. Gnd Fault 10 .. 100 V 75 V L-Gnd Voltage of Unfaulted Phase Vph Max 3109 64-1 VGND Sens. Gnd Fault 1.8 .. 200.0 V; 40.0 V 64-1 Ground Displacement Voltage 3110 64-1 VGND Sens. Gnd Fault 10.0 .. 225.0 V; 70.0 V 64-1 Ground Displacement Voltage 3111 T-DELAY Pickup Sens. Gnd Fault 0.04 .. 320.00 sec; 1.00 sec Time-DELAY Pickup 3112 64-1 DELAY Sens. Gnd Fault 0.10 .. 40000.00 sec; 10.00 sec 64-1 Time Delay SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 485 Functions, Settings, Information F.2 Settings Addr. Parameter Function 3113 50Ns-2 PICKUP C Setting Options Default Setting Comments Sens. Gnd Fault 1A 0.001 .. 1.600 A 0.300 A 50Ns-2 Pickup 5A 0.005 .. 8.000 A 1.500 A 0.05 .. 35.00 A 10.00 A 3113 50Ns-2 PICKUP Sens. Gnd Fault 1A 0.25 .. 175.00 A 50.00 A 3114 50Ns-2 DELAY Sens. Gnd Fault 0.00 .. 320.00 sec; 1.00 sec 50Ns-2 Time Delay 3115 67Ns-2 DIRECT Sens. Gnd Fault Forward Reverse Non-Directional Forward 67Ns-2 Direction 3117 50Ns-1 PICKUP Sens. Gnd Fault 1A 0.001 .. 1.600 A 0.100 A 50Ns-1 Pickup 5A 0.005 .. 8.000 A 0.500 A 5A 3117 50Ns-1 PICKUP Sens. Gnd Fault 1A 5A 0.05 .. 35.00 A 2.00 A 0.25 .. 175.00 A 10.00 A 0.00 .. 320.00 sec; 2.00 sec 50Ns-1 Time delay 51Ns Pickup 3118 50Ns-1 DELAY Sens. Gnd Fault 3119 51Ns PICKUP Sens. Gnd Fault 1A 0.001 .. 1.400 A 0.100 A 5A 0.005 .. 7.000 A 0.500 A 3119 51Ns PICKUP Sens. Gnd Fault 1A 5A 3120 0.05 .. 4.00 A 1.00 A 0.25 .. 20.00 A 5.00 A 50Ns-1 Pickup 51Ns Pickup Sens. Gnd Fault 0.10 .. 4.00 sec; 1.00 sec 51Ns Time Dial 3121A 50Ns T DROP-OUT Sens. Gnd Fault 0.00 .. 60.00 sec 0.00 sec 50Ns Drop-Out Time Delay 3122 67Ns-1 DIRECT. Sens. Gnd Fault Forward Reverse Non-Directional Forward 67Ns-1 Direction 3123 RELEASE DIRECT. Sens. Gnd Fault 1A 0.001 .. 1.200 A 0.010 A 5A 0.005 .. 6.000 A 0.050 A Release directional element 3123 51NsTIME DIAL 50Ns-2 Pickup RELEASE DIRECT. Sens. Gnd Fault 1A 5A 0.05 .. 30.00 A 0.50 A 0.25 .. 150.00 A 2.50 A Release directional element 3124 PHI CORRECTION Sens. Gnd Fault -45.0 .. 45.0 0.0 Correction Angle for Dir. Determination 3125 MEAS. METHOD Sens. Gnd Fault COS SIN COS Measurement method for Direction 3126 RESET DELAY Sens. Gnd Fault 0 .. 60 sec 1 sec Reset Delay 3130 PU CRITERIA Sens. Gnd Fault Vgnd OR INs Vgnd AND INs Vgnd OR INs Sensitive Ground Fault PICKUP criteria 3131 M.of PU TD Sens. Gnd Fault 1.00 .. 20.00 MofPU; 0.01 .. 999.00 TD 3150 50Ns-2 Vmin Sens. Gnd Fault 0.4 .. 50.0 V 2.0 V 50Ns-2 minimum voltage 3150 50Ns-2 Vmin Sens. Gnd Fault 10.0 .. 90.0 V 10.0 V 50Ns-2 minimum voltage 3151 50Ns-2 Phi Sens. Gnd Fault -180.0 .. 180.0 -90.0 50Ns-2 angle phi 3152 50Ns-2 DeltaPhi Sens. Gnd Fault 0.0 .. 180.0 30.0 50Ns-2 angle delta phi 3153 50Ns-1 Vmin Sens. Gnd Fault 0.4 .. 50.0 V 6.0 V 50Ns-1 minimum voltage 3153 50Ns-1 Vmin Sens. Gnd Fault 10.0 .. 90.0 V 15.0 V 50Ns-1 minimum voltage 3154 50Ns-1 Phi Sens. Gnd Fault -180.0 .. 180.0 -160.0 50Ns-1 angle phi 3155 50Ns-1 DeltaPhi Sens. Gnd Fault 0.0 .. 180.0 100.0 50Ns-1 angle delta phi 486 Multiples of PU Time-Dial SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 3160 1 red.dir.area 3161 Setting Options Default Setting Comments Sens. Gnd Fault 1 .. 15 2 Alpha1 (reduction directional area) 2 red.dir.area Sens. Gnd Fault 1 .. 15 2 Alpha2 (reduction directional area) 3301 INTERM.EF Intermit. EF OFF ON OFF Intermittent earth fault protection 3302 Iie> Intermit. EF 1A 0.05 .. 35.00 A 1.00 A 5A 0.25 .. 175.00 A 5.00 A Pick-up value of interm. E/F stage 1A 0.05 .. 35.00 A 1.00 A 5A 0.25 .. 175.00 A 5.00 A 3302 Iie> Intermit. EF C Pick-up value of interm. E/F stage 3302 Iie> Intermit. EF 0.005 .. 1.500 A 1.000 A Pick-up value of interm. E/F stage 3303 T-det.ext. Intermit. EF 0.00 .. 10.00 sec 0.10 sec Detection extension time 3304 T-sum det. Intermit. EF 0.00 .. 100.00 sec 20.00 sec Sum of detection times 3305 T-reset Intermit. EF 1 .. 600 sec 300 sec Reset time 3306 Nos.det. Intermit. EF 2 .. 10 3 No. of det. for start of int. E/F prot 3401 Dir. Interm. EF Dir. Interm. EF OFF ON ON with GF log Alarm Only OFF Dir. Intermittent earth fault protection 3402 Direction Dir. Interm. EF Forward Reverse Forward Direction to be protected 3403 No. of pulses Dir. Interm. EF 2 .. 50 5 Pulse no. for detecting the interm. E/F 3404 Monitoring time Dir. Interm. EF 0.04 .. 10.00 sec 2.00 sec Monitoring time after pickup detected 3405 Vgnd> / 3V0> Dir. Interm. EF 2.0 .. 100.0 V 20.0 V Vgnd> measured / 3V0> calculated 3406 Pickup Dir. Interm. EF with Vgnd/3V0> with oper. dir. with Vgnd/3V0> Pickup of the function 3501 EPTR E Flt(ext) OFF ON OFF EPTR 3502 Trans. Neutral E Flt(ext) OFF ON OFF Transformer Neutral protection(TNP) 3503 Pickup current E Flt(ext) 1A 0.001 .. 1.400 A 0.008 A Pickup current 5A 0.005 .. 7.000 A 0.040 A 3504 Pickup current E Flt(ext) 0.05 .. 4.00 A 0.12 A Pickup current 3505 EPTR I Tmax E Flt(ext) 1A 0.001 .. 1.400 A 0.008 A 5A 0.005 .. 7.000 A 0.040 A Current at Maximum Time Delay 0.05 .. 4.00 A 0.12 A Current at Maximum Time Delay 1A 0.003 .. 4.000 A 3.333 A 5A 0.015 .. 20.000 A 16.665 A Current at Minimum Time Delay 0.05 .. 20.00 A 1.00 A Current at Minimum Time Delay 1A 0.003 .. 1.400 A 0.100 A Current at Knee Point 5A 0.015 .. 7.000 A 0.500 A 0.05 .. 17.00 A 0.20 A 3506 TNP I Tmax E Flt(ext) 3507 EPTR I Tmin E Flt(ext) 3508 TNP I Tmin E Flt(ext) 3509 EPTR I Tknee E Flt(ext) 3510 TNP I Tknee E Flt(ext) SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Current at Knee Point 487 Functions, Settings, Information F.2 Settings Addr. Parameter Function 3511 T knee 3512 Setting Options Default Setting Comments E Flt(ext) E Flt(ext) 0.20 .. 100.00 sec 26.70 sec Time Delay at Knee Point T min E Flt(ext) E Flt(ext) 0.10 .. 30.00 sec 0.80 sec Minimum Time Delay 3513 T max E Flt(ext) E Flt(ext) 0.50 .. 300.00 sec 139.90 sec Maximum Time Delay 3514 TRANSLATION T E Flt(ext) E Flt(ext) -0.50 .. 30.00 sec 0.00 sec Delay time T of the whole function 4001 FCT 46 46 Negative Seq OFF ON OFF 46 Negative Sequence Protection 4002 46-1 PICKUP 46 Negative Seq 1A 0.05 .. 3.00 A 0.10 A 46-1 Pickup 5A 0.25 .. 15.00 A 0.50 A 4003 46-1 DELAY 46 Negative Seq 4004 46-2 PICKUP 46 Negative Seq C 0.00 .. 60.00 sec; 1.50 sec 46-1 Time Delay 1A 0.05 .. 3.00 A 0.50 A 46-2 Pickup 5A 0.25 .. 15.00 A 2.50 A 4005 46-2 DELAY 46 Negative Seq 0.00 .. 60.00 sec; 1.50 sec 46-2 Time Delay 4006 46 IEC CURVE 46 Negative Seq Normal Inverse Very Inverse Extremely Inv. Extremely Inv. IEC Curve 4007 46 ANSI CURVE 46 Negative Seq Extremely Inv. Inverse Moderately Inv. Very Inverse Extremely Inv. ANSI Curve 4008 46-TOC PICKUP 46 Negative Seq 1A 0.05 .. 2.00 A 0.90 A 46-TOC Pickup 5A 0.25 .. 10.00 A 4.50 A 4009 46-TOC TIMEDIAL 46 Negative Seq 0.50 .. 15.00 ; 5.00 46-TOC Time Dial 4010 46-TOC TIMEDIAL 46 Negative Seq 0.05 .. 3.20 sec; 0.50 sec 46-TOC Time Dial 4011 46-TOC RESET 46 Negative Seq Instantaneous Disk Emulation Instantaneous 46-TOC Drop Out 4012A 46 T DROP-OUT 46 Negative Seq 0.00 .. 60.00 sec 0.00 sec 46 Drop-Out Time Delay 4201 FCT 49 49 Th.Overload OFF ON Alarm Only OFF 49 Thermal overload protection 4202 49 K-FACTOR 49 Th.Overload 0.10 .. 4.00 1.10 49 K-Factor 4203 TIME CONSTANT 49 Th.Overload 1.0 .. 999.9 min 100.0 min Time Constant 4204 49 ALARM 49 Th.Overload 50 .. 100 % 90 % 49 Thermal Alarm Stage 4205 I ALARM 49 Th.Overload 1A 0.10 .. 4.00 A 1.00 A 0.50 .. 20.00 A 5.00 A Current Overload Alarm Setpoint 5A 4207A K-FACTOR 49 Th.Overload 1.0 .. 10.0 1.0 Kt-FACTOR when motor stops 4208A T EMERGENCY 49 Th.Overload 10 .. 15000 sec 100 sec Emergency time 488 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 5001 FCT 59 5002 5003 C Setting Options Default Setting Comments 27/59 O/U Volt. OFF ON Alarm Only OFF 59 Overvoltage Protection 59-1 PICKUP 27/59 O/U Volt. 20 .. 260 V 110 V 59-1 Pickup 59-1 PICKUP 27/59 O/U Volt. 20 .. 150 V 110 V 59-1 Pickup 5004 59-1 DELAY 27/59 O/U Volt. 0.00 .. 100.00 sec; 0.50 sec 59-1 Time Delay 5005 59-2 PICKUP 27/59 O/U Volt. 20 .. 260 V 120 V 59-2 Pickup 5006 59-2 PICKUP 27/59 O/U Volt. 20 .. 150 V 120 V 59-2 Pickup 5007 59-2 DELAY 27/59 O/U Volt. 0.00 .. 100.00 sec; 0.50 sec 59-2 Time Delay 5015 59-1 PICKUP V2 27/59 O/U Volt. 2 .. 150 V 30 V 59-1 Pickup V2 5016 59-2 PICKUP V2 27/59 O/U Volt. 2 .. 150 V 50 V 59-2 Pickup V2 5017A 59-1 DOUT RATIO 27/59 O/U Volt. 0.90 .. 0.99 0.95 59-1 Dropout Ratio 5018A 59-2 DOUT RATIO 27/59 O/U Volt. 0.90 .. 0.99 0.95 59-2 Dropout Ratio 5019 59-1 PICKUP V1 27/59 O/U Volt. 20 .. 150 V 110 V 59-1 Pickup V1 5020 59-2 PICKUP V1 27/59 O/U Volt. 20 .. 150 V 120 V 59-2 Pickup V1 5101 FCT 27 27/59 O/U Volt. OFF ON Alarm Only OFF 27 Undervoltage Protection 5102 27-1 PICKUP 27/59 O/U Volt. 10 .. 210 V 75 V 27-1 Pickup 5103 27-1 PICKUP 27/59 O/U Volt. 10 .. 120 V 45 V 27-1 Pickup 5106 27-1 DELAY 27/59 O/U Volt. 0.00 .. 100.00 sec; 1.50 sec 27-1 Time Delay 5110 27-2 PICKUP 27/59 O/U Volt. 10 .. 210 V 70 V 27-2 Pickup 5111 27-2 PICKUP 27/59 O/U Volt. 10 .. 120 V 40 V 27-2 Pickup 5112 27-2 DELAY 27/59 O/U Volt. 0.00 .. 100.00 sec; 0.50 sec 27-2 Time Delay 5113A 27-1 DOUT RATIO 27/59 O/U Volt. 1.01 .. 3.00 1.20 27-1 Dropout Ratio 5114A 27-2 DOUT RATIO 27/59 O/U Volt. 1.01 .. 3.00 1.20 27-2 Dropout Ratio 5120A CURRENT SUPERV. 27/59 O/U Volt. OFF ON ON Current Supervision 5201 VT BROKEN WIRE Measurem.Superv ON OFF OFF VT broken wire supervision 5202 V> Measurem.Superv 1.0 .. 100.0 V 8.0 V Threshold voltage sum 5203 Vph-ph max< Measurem.Superv 1.0 .. 100.0 V 16.0 V Maximum phase to phase voltage 5204 Vph-ph min< Measurem.Superv 1.0 .. 100.0 V 16.0 V Minimum phase to phase voltage 5205 Vph-ph max-min> Measurem.Superv 10.0 .. 200.0 V 16.0 V Symmetry phase to phase voltages 5206 I min> Measurem.Superv 1A 0.04 .. 1.00 A 0.04 A Minimum line current 5A 0.20 .. 5.00 A 0.20 A 5208 T DELAY ALARM Measurem.Superv 0.00 .. 32.00 sec 1.25 sec Alarm delay time 5301 FUSE FAIL MON. Measurem.Superv OFF Solid grounded Coil.gnd./isol. OFF Fuse Fail Monitor SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 489 Functions, Settings, Information F.2 Settings Addr. Parameter Function 5302 FUSE FAIL 3Vo Measurem.Superv 5303 FUSE FAIL RESID Measurem.Superv Measurem.Superv 5308A FFM Idiff (3ph) C Setting Options Default Setting Comments 10 .. 100 V 30 V Zero Sequence Voltage 1A 0.10 .. 1.00 A 0.10 A Residual Current 5A 0.50 .. 5.00 A 0.50 A 1A 0.05 .. 1.00 A 0.10 A 5A 0.25 .. 5.00 A 0.50 A Differential Current Threshold (3phase) 5310 BLOCK PROT. Measurem.Superv NO YES YES Block protection by FFM 5401 FCT 81 O/U 81 O/U Freq. OFF ON OFF 81 Over/Under Frequency Protection 5402 Vmin 81 O/U Freq. 10 .. 150 V 65 V Minimum required voltage for operation 5402 Vmin 81 O/U Freq. 20 .. 150 V 35 V Minimum required voltage for operation 5403 81-1 PICKUP 81 O/U Freq. 40.00 .. 60.00 Hz 49.50 Hz 81-1 Pickup 5404 81-1 PICKUP 81 O/U Freq. 50.00 .. 70.00 Hz 59.50 Hz 81-1 Pickup 5405 81-1 DELAY 81 O/U Freq. 0.00 .. 100.00 sec; 60.00 sec 81-1 Time Delay 5406 81-2 PICKUP 81 O/U Freq. 40.00 .. 60.00 Hz 49.00 Hz 81-2 Pickup 5407 81-2 PICKUP 81 O/U Freq. 50.00 .. 70.00 Hz 59.00 Hz 81-2 Pickup 5408 81-2 DELAY 81 O/U Freq. 0.00 .. 100.00 sec; 30.00 sec 81-2 Time Delay 5409 81-3 PICKUP 81 O/U Freq. 40.00 .. 60.00 Hz 47.50 Hz 81-3 Pickup 5410 81-3 PICKUP 81 O/U Freq. 50.00 .. 70.00 Hz 57.50 Hz 81-3 Pickup 5411 81-3 DELAY 81 O/U Freq. 0.00 .. 100.00 sec; 3.00 sec 81-3 Time delay 5412 81-4 PICKUP 81 O/U Freq. 40.00 .. 60.00 Hz 51.00 Hz 81-4 Pickup 5413 81-4 PICKUP 81 O/U Freq. 50.00 .. 70.00 Hz 61.00 Hz 81-4 Pickup 5414 81-4 DELAY 81 O/U Freq. 0.00 .. 100.00 sec; 30.00 sec 81-4 Time delay 5415A DO differential 81 O/U Freq. 0.02 .. 1.00 Hz 0.02 Hz Dropout differential 5421 FCT 81-1 O/U 81 O/U Freq. OFF ON f> ON f< OFF 81-1 Over/Under Frequency Protection 5422 FCT 81-2 O/U 81 O/U Freq. OFF ON f> ON f< OFF 81-2 Over/Under Frequency Protection 5423 FCT 81-3 O/U 81 O/U Freq. OFF ON f> ON f< OFF 81-3 Over/Under Frequency Protection 5424 FCT 81-4 O/U 81 O/U Freq. OFF ON f> ON f< OFF 81-4 Over/Under Frequency Protection 5501 27/Q-Protection 27/Q OFF ON OFF 27 / Q dir. con. Protection 5502 I-Release 27/Q 1A 0.02 .. 0.20 A; 0 0.10 A 5A 0.10 .. 1.00 A; 0 0.50 A Current-Rel. for Trip and Reclose NO YES NO blocking with inrush 5503 490 Inrush blk 27/Q SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 5504 27/Q Direction 27/Q 5511 Q> Pickup 27/Q C Setting Options Default Setting Comments Forward Reverse Forward Direction of 27/Q 1A 1.70 .. 10000.00 VAR 8.70 VAR Reactive power threshold for pickup 5A 8.50 .. 50000.00 VAR 43.50 VAR 5512 U< Pickup 27/Q 10.00 .. 210.00 V 85.00 V Undervoltage threshold for pickup 5513 Delay Gen. CB 27/Q 0.00 .. 60.00 sec 0.50 sec Trip time delay generator CB 5514 Delay Grid CB 27/Q 0.00 .. 60.00 sec 1.50 sec Trip time delay grid CB 5521 Recl. release 27/Q OFF ON OFF Reclosure release 5522 U> Reclose 27/Q 10.00 .. 210.00 V 95.00 V Voltage threshold for reclosure rel. 5523 T Reclose 27/Q 0.00 .. 3600.00 sec 0.00 sec Reclosure Delay Time 5524 Pos. f-diff 27/Q 0.01 .. 5.00 Hz 0.05 Hz Pos. f-diff threshold for reclosure rel. 5525 Neg. f-diff 27/Q -5.00 .. -0.01 Hz -2.50 Hz Neg. f-diff threshold for reclosure rel. 5526A Incl. 27/Q Trip 27/Q NO YES NO Include 27/Q Trip for reclosure rel. 6001 S1: RE/RL P.System Data 2 -0.33 .. 7.00 1.00 S1: Zero seq. compensating factor RE/RL 6002 S1: XE/XL P.System Data 2 -0.33 .. 7.00 1.00 S1: Zero seq. compensating factor XE/XL 6003 S1: x' P.System Data 2 1A 0.0050 .. 15.0000 /mi 0.2420 /mi S1: feeder reactance per mile: x' 5A 0.0010 .. 3.0000 /mi 0.0484 /mi 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km 6004 S1: x' P.System Data 2 S1: feeder reactance per km: x' 6005 S1: Line angle P.System Data 2 10 .. 89 85 S1: Line angle 6006 S1: Line length P.System Data 2 0.1 .. 650.0 Miles 62.1 Miles S1: Line length in miles 6007 S1: Line length P.System Data 2 0.1 .. 1000.0 km 100.0 km S1: Line length in kilometer 6011 S2: RE/RL P.System Data 2 -0.33 .. 7.00 1.00 S2: Zero seq. compensating factor RE/RL 6012 S2: XE/XL P.System Data 2 -0.33 .. 7.00 1.00 S2: Zero seq. compensating factor XE/XL 6013 S2: x' P.System Data 2 1A 0.0050 .. 15.0000 /mi 0.2420 /mi S2: feeder reactance per mile: x' 5A 0.0010 .. 3.0000 /mi 0.0484 /mi SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 491 Functions, Settings, Information F.2 Settings Addr. Parameter Function C Setting Options Default Setting Comments 6014 P.System Data 2 1A 0.0050 .. 9.5000 /km 0.1500 /km S2: feeder reactance per km: x' 5A 0.0010 .. 1.9000 /km 0.0300 /km S2: x' 6015 S2: Line angle P.System Data 2 10 .. 89 85 S2: Line angle 6016 S2: Line length P.System Data 2 0.1 .. 650.0 Miles 62.1 Miles S2: Line length in miles 6017 S2: Line length P.System Data 2 0.1 .. 1000.0 km 100.0 km S2: Line length in kilometer 6021 S3: RE/RL P.System Data 2 -0.33 .. 7.00 1.00 S3: Zero seq. compensating factor RE/RL 6022 S3: XE/XL P.System Data 2 -0.33 .. 7.00 1.00 S3: Zero seq. compensating factor XE/XL 6023 S3: x' P.System Data 2 1A 0.0050 .. 15.0000 /mi 0.2420 /mi S3: feeder reactance per mile: x' 5A 0.0010 .. 3.0000 /mi 0.0484 /mi 1A 0.0050 .. 9.5000 /km 0.1500 /km 5A 0.0010 .. 1.9000 /km 0.0300 /km 6024 S3: x' P.System Data 2 S3: feeder reactance per km: x' 6025 S3: Line angle P.System Data 2 10 .. 89 85 S3: Line angle 6026 S3: Line length P.System Data 2 0.1 .. 650.0 Miles 62.1 Miles S3: Line length in miles 6027 S3: Line length P.System Data 2 0.1 .. 1000.0 km 100.0 km S3: Line length in kilometer 6101 Synchronizing SYNC function 1 ON OFF OFF Synchronizing Function 6102 SyncCB SYNC function 1 (Einstellmoglichnone keiten anwendungsabhangig) Synchronizable circuit breaker 6103 Vmin SYNC function 1 20 .. 125 V 90 V Minimum voltage limit: Vmin 6104 Vmax SYNC function 1 20 .. 140 V 110 V Maximum voltage limit: Vmax 6105 V< SYNC function 1 1 .. 60 V 5V Threshold V1, V2 without voltage 6106 V> SYNC function 1 20 .. 140 V 80 V Threshold V1, V2 with voltage 6107 SYNC V1<V2> SYNC function 1 YES NO NO ON-Command at V1< and V2> 6108 SYNC V1>V2< SYNC function 1 YES NO NO ON-Command at V1> and V2< 6109 SYNC V1<V2< SYNC function 1 YES NO NO ON-Command at V1< and V2< 6110A Direct CO SYNC function 1 YES NO NO Direct ON-Command 6111A TSUP VOLTAGE SYNC function 1 0.00 .. 60.00 sec 0.10 sec Supervision time of V1>;V2> or V1<;V2< 492 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 6112 SYNC function 1 0.01 .. 1200.00 sec; 30.00 sec Maximum duration of Synchronization 6113A 25 Synchron SYNC function 1 YES NO YES Switching at synchronous condition 6121 SYNC function 1 0.50 .. 2.00 1.00 Balancing factor V1/V2 SYNC function 1 0 .. 360 0 Angle adjustment (transformer) T-SYN. DURATION Balancing V1/V2 6122A ANGLE ADJUSTM. C Setting Options Default Setting Comments 6123 CONNECTIONof V2 SYNC function 1 A-B B-C C-A A-B Connection of V2 6125 VT Vn2, primary 0.10 .. 800.00 kV 20.00 kV VT nominal voltage V2, primary 6150 dV SYNCHK V2>V1 SYNC function 1 0.5 .. 50.0 V 5.0 V Maximum voltage difference V2>V1 6151 dV SYNCHK V2<V1 SYNC function 1 0.5 .. 50.0 V 5.0 V Maximum voltage difference V2<V1 6152 df SYNCHK f2>f1 SYNC function 1 0.01 .. 2.00 Hz 0.10 Hz Maximum frequency difference f2>f1 6153 df SYNCHK f2<f1 SYNC function 1 0.01 .. 2.00 Hz 0.10 Hz Maximum frequency difference f2<f1 6154 d SYNCHK 2>1 SYNC function 1 2 .. 80 10 Maximum angle difference alpha2>alpha1 6155 d SYNCHK 2<1 SYNC function 1 2 .. 80 10 Maximum angle difference alpha2<alpha1 7001 FCT 50BF 50BF BkrFailure OFF ON OFF 50BF Breaker Failure Protection 7004 Chk BRK CONTACT 50BF BkrFailure OFF ON OFF Check Breaker contacts 7005 TRIP-Timer 50BF BkrFailure 0.06 .. 60.00 sec; 0.25 sec TRIP-Timer 7006 50BF PICKUP 50BF BkrFailure 1A 0.05 .. 20.00 A 0.10 A 0.25 .. 100.00 A 0.50 A 50BF Pickup current threshold 7007 50BF PICKUP IE> 50BF BkrFailure 1A 0.05 .. 20.00 A 0.10 A 0.25 .. 100.00 A 0.50 A 7008 50BF-2 Delay 50BF BkrFailure 0.06 .. 60.00 sec; 0.50 sec Delay of 2nd stage for busbar trip 7101 FCT 79 79M Auto Recl. OFF ON OFF 79 Auto-Reclose Function 7103 BLOCK MC Dur. 79M Auto Recl. 0.50 .. 320.00 sec; 0 1.00 sec AR blocking duration after manual close 7105 TIME RESTRAINT 79M Auto Recl. 0.50 .. 320.00 sec 3.00 sec 79 Auto Reclosing reset time 7108 SAFETY 79 ready 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Safety Time until 79 is ready 7113 CHECK CB? 79M Auto Recl. No check Chk each cycle No check Check circuit breaker before AR? 7114 T-Start MONITOR 79M Auto Recl. 0.01 .. 320.00 sec; 0.50 sec AR start-signal monitoring time 7115 CB TIME OUT 79M Auto Recl. 0.10 .. 320.00 sec 3.00 sec Circuit Breaker (CB) Supervision Time SYNC function 1 5A 5A SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 50BF Pickup earth current threshold 493 Functions, Settings, Information F.2 Settings Addr. Parameter Function 7116 Max. DEAD EXT. 79M Auto Recl. 0.50 .. 1800.00 sec; 100.00 sec Maximum dead time extension 7117 T-ACTION 79M Auto Recl. 0.01 .. 320.00 sec; Action time 7118 T DEAD DELAY 79M Auto Recl. 0.0 .. 1800.0 sec; 1.0 sec Maximum Time Delay of Dead-Time Start 7127 DEADTIME 1: PH 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 1: Phase Fault 7128 DEADTIME 1: G 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 1: Ground Fault 7129 DEADTIME 2: PH 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 2: Phase Fault 7130 DEADTIME 2: G 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 2: Ground Fault 7131 DEADTIME 3: PH 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 3: Phase Fault 7132 DEADTIME 3: G 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 3: Ground Fault 7133 DEADTIME 4: PH 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 4: Phase Fault 7134 DEADTIME 4: G 79M Auto Recl. 0.01 .. 320.00 sec 0.50 sec Dead Time 4: Ground Fault 7135 # OF RECL. GND 79M Auto Recl. 0 .. 9 1 Number of Reclosing Cycles Ground 7136 # OF RECL. PH 79M Auto Recl. 0 .. 9 1 Number of Reclosing Cycles Phase 7137 Cmd.via control 79M Auto Recl. (Einstellmoglichnone keiten anwendungsabhangig) Close command via control device 7138 Internal SYNC 79M Auto Recl. (Einstellmoglichnone keiten anwendungsabhangig) Internal 25 synchronisation 7139 External SYNC 79M Auto Recl. YES NO NO External 25 synchronisation 7140 ZONE SEQ.COORD. 79M Auto Recl. OFF ON OFF ZSC - Zone sequence coordination 7150 50-1 79M Auto Recl. No influence Starts 79 Stops 79 No influence 50-1 7151 50N-1 79M Auto Recl. No influence Starts 79 Stops 79 No influence 50N-1 7152 50-2 79M Auto Recl. No influence Starts 79 Stops 79 No influence 50-2 7153 50N-2 79M Auto Recl. No influence Starts 79 Stops 79 No influence 50N-2 7154 51 79M Auto Recl. No influence Starts 79 Stops 79 No influence 51 7155 51N 79M Auto Recl. No influence Starts 79 Stops 79 No influence 51N 494 C Setting Options Default Setting sec Comments SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 7156 67-1 7157 Setting Options Default Setting Comments 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67-1 67N-1 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67N-1 7158 67-2 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67-2 7159 67N-2 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67N-2 7160 67 TOC 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67 TOC 7161 67N TOC 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67N TOC 7162 sens Ground Flt 79M Auto Recl. No influence Starts 79 Stops 79 No influence (Sensitive) Ground Fault 7163 46 79M Auto Recl. No influence Starts 79 Stops 79 No influence 46 7164 BINARY INPUT 79M Auto Recl. No influence Starts 79 Stops 79 No influence Binary Input 7165 3Pol.PICKUP BLK 79M Auto Recl. YES NO NO 3 Pole Pickup blocks 79 7166 50-3 79M Auto Recl. No influence Starts 79 Stops 79 No influence 50-3 7167 50N-3 79M Auto Recl. No influence Starts 79 Stops 79 No influence 50N-3 7168 67-3 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67-3 7169 67N-3 79M Auto Recl. No influence Starts 79 Stops 79 No influence 67N-3 7200 bef.1.Cy:50-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50-1 7201 bef.1.Cy:50N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50N-1 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 C 495 Functions, Settings, Information F.2 Settings Addr. Parameter Function 7202 bef.1.Cy:50-2 7203 Setting Options Default Setting Comments 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50-2 bef.1.Cy:50N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50N-2 7204 bef.1.Cy:51 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 51 7205 bef.1.Cy:51N 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 51N 7206 bef.1.Cy:67-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67-1 7207 bef.1.Cy:67N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67N-1 7208 bef.1.Cy:67-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67-2 7209 bef.1.Cy:67N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67N-2 7210 bef.1.Cy:67 TOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67 TOC 7211 bef.1.Cy:67NTOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67N TOC 7212 bef.2.Cy:50-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50-1 7213 bef.2.Cy:50N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50N-1 7214 bef.2.Cy:50-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50-2 7215 bef.2.Cy:50N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50N-2 7216 bef.2.Cy:51 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 51 7217 bef.2.Cy:51N 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 51N 496 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 7218 bef.2.Cy:67-1 7219 Setting Options Default Setting Comments 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67-1 bef.2.Cy:67N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67N-1 7220 bef.2.Cy:67-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67-2 7221 bef.2.Cy:67N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67N-2 7222 bef.2.Cy:67 TOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67 TOC 7223 bef.2.Cy:67NTOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67N TOC 7224 bef.3.Cy:50-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50-1 7225 bef.3.Cy:50N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50N-1 7226 bef.3.Cy:50-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50-2 7227 bef.3.Cy:50N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50N-2 7228 bef.3.Cy:51 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 51 7229 bef.3.Cy:51N 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 51N 7230 bef.3.Cy:67-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67-1 7231 bef.3.Cy:67N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67N-1 7232 bef.3.Cy:67-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67-2 7233 bef.3.Cy:67N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67N-2 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 C 497 Functions, Settings, Information F.2 Settings Addr. Parameter Function 7234 bef.3.Cy:67 TOC 7235 Setting Options Default Setting Comments 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67 TOC bef.3.Cy:67NTOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67N TOC 7236 bef.4.Cy:50-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50-1 7237 bef.4.Cy:50N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50N-1 7238 bef.4.Cy:50-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50-2 7239 bef.4.Cy:50N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50N-2 7240 bef.4.Cy:51 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 51 7241 bef.4.Cy:51N 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 51N 7242 bef.4.Cy:67-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67-1 7243 bef.4.Cy:67N-1 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N-1 7244 bef.4.Cy:67-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67-2 7245 bef.4.Cy:67N-2 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N-2 7246 bef.4.Cy:67 TOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67 TOC 7247 bef.4.Cy:67NTOC 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N TOC 7248 bef.1.Cy:50-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50-3 7249 bef.1.Cy:50N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 50N-3 498 C SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.2 Settings Addr. Parameter Function 7250 bef.2.Cy:50-3 7251 Setting Options Default Setting Comments 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50-3 bef.2.Cy:50N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 50N-3 7252 bef.3.Cy:50-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50-3 7253 bef.3.Cy:50N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 50N-3 7254 bef.4.Cy:50-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50-3 7255 bef.4.Cy:50N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 50N-3 7256 bef.1.Cy:67-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: 67-3 7257 bef.1.Cy:67N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 1. Cycle: IE>>> directional 7258 bef.2.Cy:67-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: 67-3 7259 bef.2.Cy:67N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 2. Cycle: IE>>> directional 7260 bef.3.Cy:67-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: 67-3 7261 bef.3.Cy:67N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 3. Cycle: IE>>> directional 7262 bef.4.Cy:67-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67-3 7263 bef.4.Cy:67N-3 79M Auto Recl. Set value T=T instant. T=0 blocked T= Set value T=T before 4. Cycle: 67N-3 8001 START Fault Locator Pickup TRIP Pickup Start fault locator with 8101 MEASURE. SUPERV Measurem.Superv OFF ON ON Measurement Supervision 8102 BALANCE V-LIMIT 10 .. 100 V 50 V Voltage Threshold for Balance Monitoring Measurem.Superv SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 C 499 Functions, Settings, Information F.2 Settings Addr. Parameter Function 8103 BAL. FACTOR V Measurem.Superv 8104 BALANCE I LIMIT Measurem.Superv C Setting Options Default Setting Comments 0.58 .. 0.90 0.75 Balance Factor for Voltage Monitor 1A 0.10 .. 1.00 A 0.50 A 5A 0.50 .. 5.00 A 2.50 A Current Threshold for Balance Monitoring 0.10 .. 0.90 0.50 Balance Factor for Current Monitor 1A 0.05 .. 2.00 A; 0.10 A 5A Summated Current Monitoring Threshold 8105 BAL. FACTOR I Measurem.Superv 8106 I THRESHOLD Measurem.Superv 0.25 .. 10.00 A; 0.50 A 8107 I FACTOR Measurem.Superv 0.00 .. 0.95 0.10 Summated Current Monitoring Factor 8109 FAST i MONIT Measurem.Superv OFF ON ON Fast Summated Current Monitoring 8110A T BAL. V LIMIT Measurem.Superv 0 .. 100 sec 5 sec T Balance Factor for Voltage Monitor 8111A T BAL. I LIMIT Measurem.Superv 0 .. 100 sec 5 sec T Current Balance Monitor 8201 FCT 74TC 74TC TripCirc. ON OFF ON 74TC TRIP Circuit Supervision 8202 Alarm Delay 74TC TripCirc. 1 .. 30 sec 2 sec Delay Time for alarm 8301 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.,10 Subs 5 Min., 5 Subs 60 Min., 1 Sub Demand Calculation Intervals 8302 DMD Sync.Time Demand meter On The Hour 15 After Hour 30 After Hour 45 After Hour On The Hour Demand Synchronization Time 8311 MinMax cycRESET Min/Max meter NO YES YES Automatic Cyclic Reset Function 8312 MiMa RESET TIME Min/Max meter 0 .. 1439 min 0 min MinMax Reset Timer 8313 MiMa RESETCYCLE Min/Max meter 1 .. 365 Days 7 Days MinMax Reset Cycle Period 8314 MinMaxRES.START Min/Max meter 1 .. 365 Days 1 Days MinMax Start Reset Cycle in 8315 MeterResolution Energy Standard Factor 10 Factor 100 Standard Meter resolution 500 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.3 Information List F.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 Device, General SP On * Of f * LED BI - Reset LED (Reset LED) Device, General IntS On * P * LED BO 16 0 19 1 No - Stop data transmission (DataStop) Device, General IntS On * P Of f * LED BO 16 0 20 1 Yes - Test mode (Test mode) Device, General IntS On * P Of f * LED BO 16 0 21 1 Yes - Feeder GROUNDED (Feeder gnd) Device, General IntS * P * * LED BO - Breaker OPENED (Brk OPENED) Device, General IntS * P * * LED BO - Hardware Test Mode (HWTestMod) Device, General IntS On * P Of f * LED BO - Clock Synchronization (SynchClock) Device, General IntS * P_E v * - Disturbance CFC (Distur.CFC) Device, General OUT On * Of f LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression >Back Light on (>Light on) Relay Binary Input - * 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. 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>: BO 501 Type information number Data Unit General Interrogation IntS On * P Of f m LED BO - Setting Group A is active (P-GrpA act) Change Group IntS On * P Of f * LED BO 16 0 23 1 Yes - Setting Group B is active (P-GrpB act) Change Group IntS On * P Of f * LED BO 16 0 24 1 Yes - Setting Group C is active (P-GrpC act) Change Group IntS On * P Of f * LED BO 16 0 25 1 Yes - Setting Group D is active (P-GrpD act) Change Group IntS On * P Of f * LED BO 16 0 26 1 Yes - Controlmode REMOTE (ModeREMOTE) Cntrl Authority IntS On * P Of f LED BO - Control Authority (Cntrl Auth) Cntrl Authority IntS On * P Of f LED BO 10 1 85 1 Yes - Controlmode LOCAL (ModeLOCAL) Cntrl Authority IntS On * P Of f LED BO 10 1 86 1 Yes - 52 Breaker (52Breaker) Control Device CF_ On D12 Of f LED BO 24 0 16 0 20 - 52 Breaker (52Breaker) 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 - Ground Switch (GndSwit.) Control Device CF_ On D2 Of f 24 0 16 4 20 - Ground Switch (GndSwit.) Control Device DP On Of f CB 24 0 16 4 1 - >CB ready Spring is charged (>CB ready) Process Data SP * On Of f BI LED On Of f BO BI LED BO BI * * LED Chatter Suppression Osc. Fault Rec. Relay Fault Recording Start (FltRecSta) Function Key LED - 502 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 F.3 Information List BI BO Yes Yes Yes CB SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Typ Log Buffers e of Info rma tion Trip (Fault) Log ON/OFF Marked in Oscill. Record LED Binary Input Relay Chatter Suppression information number Data Unit General Interrogation - >Door closed (>DoorClose) Process Data SP * * * LED BI BO CB - >Cabinet door open (>Door open) Process Data SP On * Of f * LED BI BO CB 10 1 1 1 Yes - >CB waiting for Spring charged (>CB wait) Process Data SP On * Of f * LED BI BO CB 10 1 2 1 Yes - >No Voltage (Fuse blown) Process (>No Volt.) Data SP On * Of f * LED BI BO CB 16 0 38 1 Yes - >Error Motor Voltage (>Err Mot V) Process Data SP On * Of f * LED BI BO CB 24 0 18 1 1 Yes - >Error Control Voltage (>ErrCntrlV) 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 Minimum and Maximum counter (ResMinMax) Min/Max meter IntS O P_E N v - Reset meter (Meter res) Energy IntS O P_E N v - Error Systeminterface (SysIntErr.) Protocol IntS On * P Of f * LED BO - DCP identify (DCP ident) Protocol IntS * P * LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Configurable in Matrix IEC 60870-5-103 Type Function Function Key Description Ground Fault Log ON/OFF No. Event Log ON/OFF Functions, Settings, Information F.3 Information List BI * 503 Functions, Settings, Information F.3 Information List Threshold Value 1 (ThreshVal1) Thresh.Switch IntS On P Of f 1 No Function configured (Not configured) Device, General SP * * 2 Function Not Available (Non Existent) Device, General SP * * 3 >Synchronize Internal Real Time Clock (>Time Synch) Device, General SP_ * Ev * 4 >Trigger Waveform Capture (>Trig.Wave.Cap.) Osc. Fault Rec. SP * * 5 >Reset LED (>Reset LED) Device, General SP * 7 >Setting Group Select Bit 0 (>Set Group Bit0) Change Group SP 8 >Setting Group Select Bit 1 (>Set Group Bit1) Change Group SP 009.01 Failure EN100 Modul 00 (Failure Modul) Yes m LED BI BO 13 5 49 1 Yes * * LED BI BO 13 5 50 1 Yes * * * LED BI BO 13 5 51 1 Yes * * * LED BI BO 13 5 52 1 Yes 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 FK BO TO NL IN E CB Function Key Chatter Suppression 1 LED Relay 48 Binary Input 13 5 Marked in Oscill. Record BO Ground Fault Log ON/OFF BI Trip (Fault) Log ON/OFF LED Event Log ON/OFF General Interrogation - Configurable in Matrix IEC 60870-5-103 Data Unit Typ Log Buffers e of Info rma tion information number Function Type Description LED No. 15 >Test mode (>Test mode) Device, General SP * * * LED BI BO 13 5 53 1 Yes 16 >Stop data transmission (>DataStop) SP * * * LED BI BO 13 5 54 1 Yes 51 Device is Operational and Device, Protecting (Device OK) General OUT On * Of f * LED BO 13 5 81 1 Yes 52 At Least 1 Protection Funct. is Active (ProtActive) Device, General IntS On * P Of f * LED BO 16 0 18 1 Yes 55 Reset Device (Reset Device) Device, General OUT On * * 16 0 4 1 No 56 Initial Start of Device (Initial Start) Device, General OUT On * * 16 0 5 1 No 504 Device, General LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 LED Configurable in Matrix IEC 60870-5-103 67 Resume (Resume) Device, General OUT On * * LED BO 68 Clock Synchronization Error (Clock SyncError) Device, General OUT On * Of f * LED BO 69 Daylight Saving Time (DayLightSavTime) Device, General OUT On * Of f * LED BO 70 Setting calculation is running (Settings Calc.) Device, General OUT On * Of f * LED BO 71 Settings Check (Settings Check) Device, General OUT * * * LED BO 72 Level-2 change (Level-2 change) Device, General OUT On * Of f * LED BO 73 Local setting change (Local change) Device, General OUT * * 110 Event lost (Event Lost) Device, General OUT On * _Ev LED 113 Flag Lost (Flag Lost) Device, General OUT On * m 125 Chatter ON (Chatter ON) Device, General OUT On * Of f 126 Protection ON/OFF (via system port) (ProtON/ OFF) P.System Data 2 127 79 ON/OFF (via system port) (79 ON/OFF) 140 13 0 1 No LED BO 13 5 13 6 1 Yes * LED BO 13 5 14 5 1 Yes IntS On * P Of f * LED BO 79M Auto Recl. IntS On * P Of f * LED BO Error with a summary alarm (Error Sum Alarm) Device, General OUT On * Of f * LED BO 16 0 47 1 Yes 160 Alarm Summary Event (Alarm Sum Event) Device, General OUT On * Of f * LED BO 16 0 46 1 Yes 161 Failure: General Current Supervision (Fail I Superv.) MeasOUT On * urem.Super Of v f * LED BO 16 0 32 1 Yes 162 Failure: Current Summation (Failure I) MeasOUT On * urem.Super Of v f * LED BO 13 5 18 2 1 Yes SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression 13 5 Relay BO * Function Key Yes Binary Input 1 Ground Fault Log ON/OFF 22 Trip (Fault) Log ON/OFF 16 0 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 F.3 Information List 505 Type information number Data Unit General Interrogation * LED BO 13 5 18 3 1 Yes 167 Failure: Voltage Balance (Fail V balance) MeasOUT On * urem.Super Of v f * LED BO 13 5 18 6 1 Yes 169 VT Fuse Failure (alarm >10s) (VT FuseFail>10s) MeasOUT On * urem.Super Of v f * LED BO 13 5 18 8 1 Yes 170 VT Fuse Failure (alarm instantaneous) (VT FuseFail) MeasOUT On * urem.Super Of v f * LED BO 170.00 >25-group 1 activate 01 (>25-1 act) SYNC function 1 SP On Of f * LED BI 170.00 >25 Synchronization 43 request (>25 Sync requ.) SYNC function 1 SP On Of f * LED BI 170.00 25 Sync. Release of 49 CLOSE Command (25 CloseRelease) SYNC function 1 OUT On Of f * LED BO 41 20 1 1 Yes 170.00 25 Synchronization Error 50 (25 Sync. Error) SYNC function 1 OUT On Of f * LED BO 41 20 2 1 Yes 170.00 25-group 1 is BLOCKED 51 (25-1 BLOCK) SYNC function 1 OUT On Of f * LED BO 41 20 4 1 Yes 170.20 25 Sync. Measuring 07 request of Control (25 Measu. req.) SYNC function 1 SP On Of f * LED 170.20 >BLOCK 25-group 1 (>BLK SYNC func08 25-1) tion 1 SP On Of f * LED BI 170.20 >25 Direct Command 09 output (>25direct CO) SYNC function 1 SP On Of f * LED BI 170.20 >25 Start of synchroniza- SYNC func11 tion (>25 Start) tion 1 SP On Of f * LED BI 170.20 >25 Stop of synchroniza12 tion (>25 Stop) SP On Of f * LED BI 506 Chatter Suppression MeasOUT On * urem.Super Of v f Relay Failure: Current Balance (Fail I balance) Function Key 163 SYNC function 1 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation SP On Of f * LED BI 170.20 >25 Switch to V1< and 14 V2> (>25 V1<V2>) SYNC function 1 SP On Of f * LED BI 170.20 >25 Switch to V1< and 15 V2< (>25 V1<V2<) SYNC function 1 SP On Of f * LED BI 170.20 >25 Switch to Sync (>25 16 synchr.) SYNC function 1 SP On Of f * LED BI 170.20 25-group 1: measure22 ment in progress (25-1 meas.) SYNC function 1 OUT On Of f * LED BO 41 20 3 1 Yes 170.20 25 Monitoring time 25 exceeded (25 MonTimeExc) SYNC function 1 OUT On Of f * LED BO 41 20 5 1 Yes 170.20 25 Synchronization condi- SYNC func26 tions okay (25 Synchron) tion 1 OUT On Of f * LED BO 41 20 6 1 Yes 170.20 25 Condition V1>V2< 27 fulfilled (25 V1> V2<) SYNC function 1 OUT On Of f * LED BO 170.20 25 Condition V1<V2> 28 fulfilled (25 V1< V2>) SYNC function 1 OUT On Of f * LED BO 170.20 25 Condition V1<V2< 29 fulfilled (25 V1< V2<) SYNC function 1 OUT On Of f * LED BO 170.20 25 Voltage difference 30 (Vdiff) okay (25 Vdiff ok) SYNC function 1 OUT On Of f * LED BO 41 20 7 1 Yes 170.20 25 Frequency difference 31 (fdiff) okay (25 fdiff ok) SYNC function 1 OUT On Of f * LED BO 41 20 8 1 Yes 170.20 25 Angle difference SYNC func32 (alphadiff) okay (25 diff tion 1 ok) OUT On Of f * LED BO 41 20 9 1 Yes 170.20 25 Frequency f1 > fmax 33 permissible (25 f1>>) OUT On Of f * LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression Binary Input SYNC function 1 Relay LED 170.20 >25 Switch to V1> and 13 V2< (>25 V1>V2<) SYNC function 1 Configurable in Matrix IEC 60870-5-103 Function Key Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Description Trip (Fault) Log ON/OFF No. Event Log ON/OFF Function Marked in Oscill. Record Functions, Settings, Information F.3 Information List 507 SYNC function 1 OUT On Of f * LED BO 170.20 25 Frequency f2 < fmin 36 permissible (25 f2<<) SYNC function 1 OUT On Of f * LED BO 170.20 25 Voltage V1 > Vmax 37 permissible (25 V1>>) SYNC function 1 OUT On Of f * LED BO 170.20 25 Voltage V1 < Vmin 38 permissible (25 V1<<) SYNC function 1 OUT On Of f * LED BO 170.20 25 Voltage V2 > Vmax 39 permissible (25 V2>>) SYNC function 1 OUT On Of f * LED BO 170.20 25 Voltage V2 < Vmin 40 permissible (25 V2<<) SYNC function 1 OUT On Of f * LED BO 170.20 25 Vdiff too large 90 (V2>V1) (25 V2>V1) SYNC function 1 OUT On Of f * LED BO 170.20 25 Vdiff too large 91 (V2<V1) (25 V2<V1) SYNC function 1 OUT On Of f * LED BO 170.20 25 fdiff too large (f2>f1) 92 (25 f2>f1) SYNC function 1 OUT On Of f * LED BO 170.20 25 fdiff too large (f2<f1) 93 (25 f2<f1) SYNC function 1 OUT On Of f * LED BO 170.20 25 alphadiff too large 94 (a2>a1) (25 2>1) SYNC function 1 OUT On Of f * LED BO 170.20 25 alphadiff too large 95 (a2<a1) (25 2<1) SYNC function 1 OUT On Of f * LED BO 170.20 25 Multiple selection of SYNC func96 func-groups (25 FG-Error) tion 1 OUT On Of f LED BO General Interrogation 170.20 25 Frequency f2 > fmax 35 permissible (25 f2>>) Data Unit BO information number LED Type * Chatter Suppression OUT On Of f Relay SYNC function 1 Function Key LED 170.20 25 Frequency f1 < fmin 34 permissible (25 f1<<) 508 Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion Ground Fault Log ON/OFF Description Trip (Fault) Log ON/OFF No. Event Log ON/OFF Function Marked in Oscill. Record Functions, Settings, Information F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.3 Information List 170.21 Sync-group 1 is switched 01 OFF (25-1 OFF) SYNC function 1 OUT On Of f 170.21 >BLOCK 25 CLOSE 02 command (>BLK 25 CLOSE) SYNC function 1 SP 41 36 1 Yes On Of f * LED 170.21 25 CLOSE command is SYNC func03 BLOCKED (25 CLOSE BLK) tion 1 OUT On Of f * LED BO 41 37 1 Yes Chatter Suppression BO Relay LED Function Key * Binary Input BO Marked in Oscill. Record LED Ground Fault Log ON/OFF General Interrogation OUT On Of f Data Unit SYNC function 1 information number 170.20 25 Setting error (25 Set97 Error) Configurable in Matrix IEC 60870-5-103 Type Typ Log Buffers e of Info rma tion LED Function Trip (Fault) Log ON/OFF Description Event Log ON/OFF No. BI 171 Failure: Phase Sequence (Fail Ph. Seq.) MeasOUT On * urem.Super Of v f * LED BO 16 0 35 1 Yes 175 Failure: Phase Sequence Current (Fail Ph. Seq. I) MeasOUT On * urem.Super Of v f * LED BO 13 5 19 1 1 Yes 176 Failure: Phase Sequence Voltage (Fail Ph. Seq. V) MeasOUT On * urem.Super Of v f * LED BO 13 5 19 2 1 Yes 177 Failure: Battery empty (Fail Battery) Device, General OUT On * Of f * LED BO 178 I/O-Board Error (I/O-Board Device, error) General OUT On * Of f * LED BO 181 Error: A/D converter (Error Device, A/D-conv.) General OUT On * Of f * LED BO 191 Error: Offset (Error Offset) Device, General OUT On * Of f * LED BO 193 Alarm: NO calibration data available (Alarm NO calibr) Device, General OUT On * Of f * LED BO 194 Error: Neutral CT different Device, from MLFB (Error General neutralCT) OUT On * Of f 197 Measurement Supervision MeasOUT On * is switched OFF (MeasSup urem.Super Of OFF) v f * LED BO 13 5 19 7 1 Yes 203 Waveform data deleted (Wave. deleted) LED BO 13 5 20 3 1 No Osc. Fault Rec. SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 OUT On * _Ev 509 233 LPCT ground Current Transf. mismatching (CT gnd mismatch) Device, General OUT On Of f * LED BO 234.21 27, 59 blocked via opera- 27/59 O/U 00 tion (27, 59 blk) Volt. IntS On * P Of f * LED BO 235.21 >BLOCK Function $00 10 (>BLOCK $00) Flx SP On On Of Off f * * LED BI FK BO TO NL IN E 235.21 >Function $00 instanta11 neous TRIP (>$00 instant.) Flx SP On On Of Off f * * LED BI FK BO TO NL IN E 235.21 >Function $00 Direct TRIP Flx 12 (>$00 Dir.TRIP) SP On On Of Off f * * LED BI FK BO TO NL IN E 235.21 >Function $00 BLOCK 13 TRIP Time Delay (>$00 BLK.TDly) Flx SP On On Of Off f * * LED BI FK BO TO NL IN E 235.21 >Function $00 BLOCK 14 TRIP (>$00 BLK.TRIP) Flx SP On On Of Off f * * LED BI FK BO TO NL IN E 235.21 >Function $00 BLOCK 15 TRIP Phase A (>$00 BL.TripA) Flx SP On On Of Off f * * LED BI FK BO TO NL IN E 235.21 >Function $00 BLOCK 16 TRIP Phase B (>$00 BL.TripB) Flx SP On On Of Off f * * LED BI FK BO TO NL IN E General Interrogation BO Data Unit LED information number * Type OUT On Of f Chatter Suppression Device, General Relay LPCT phase Current Transf. mismatching (CT ph mismatch) Function Key LED 232 510 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.3 Information List OUT On On Of Off f * * LED BO 235.21 Function $00 is switched 19 OFF ($00 OFF) Flx OUT On * Of f * * LED BO 235.21 Function $00 is ACTIVE 20 ($00 ACTIVE) Flx OUT On * Of f * * LED BO 235.21 Function $00 picked up 21 ($00 picked up) Flx OUT On On Of Off f * * LED BO 235.21 Function $00 Pickup 22 Phase A ($00 pickup A) Flx OUT On On Of Off f * * LED BO 235.21 Function $00 Pickup 23 Phase B ($00 pickup B) Flx OUT On On Of Off f * * LED BO 235.21 Function $00 Pickup 24 Phase C ($00 pickup C) Flx OUT On On Of Off f * * LED BO 235.21 Function $00 TRIP Delay Flx 25 Time Out ($00 Time Out) OUT On On Of Off f * * LED BO 235.21 Function $00 TRIP ($00 26 TRIP) Flx OUT On On Of f * * LED BO 235.21 Function $00 has invalid 28 settings ($00 inval.set) Flx OUT On On Of Off f * * LED BO 236.21 BLOCK Flexible Function 27 (BLK. Flex.Fct.) Device, General IntS On * P Of f * * LED BO 253 Failure VT circuit: broken wire (VT brk. wire) MeasOUT On * urem.Super Of v f * LED BO 255 Failure VT circuit (Fail VT circuit) MeasOUT On * urem.Super Of v f * LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 General Interrogation 235.21 Function $00 is BLOCKED Flx 18 ($00 BLOCKED) Data Unit FK BO TO NL IN E information number BI Type LED Relay * Trip (Fault) Log ON/OFF * Event Log ON/OFF On On Of Off f 235.21 >Function $00 BLOCK 17 TRIP Phase C (>$00 BL.TripC) Chatter Suppression SP Function Key Flx Configurable in Matrix IEC 60870-5-103 Binary Input Typ Log Buffers e of Info rma tion LED Function Marked in Oscill. Record Description Ground Fault Log ON/OFF No. 511 Configurable in Matrix IEC 60870-5-103 256 Failure VT circuit: 1 pole broken wire (VT b.w. 1 pole) MeasOUT On * urem.Super Of v f * LED BO 257 Failure VT circuit: 2 pole broken wire (VT b.w. 2 pole) MeasOUT On * urem.Super Of v f * LED BO 258 Failure VT circuit: 3 pole broken wire (VT b.w. 3 pole) MeasOUT On * urem.Super Of v f * LED BO 272 Set Point Operating Hours SetPoint(Sta OUT On * (SP. Op Hours>) t) Of f * LED BO 301 Power System fault (Pow.Sys.Flt.) Device, General 302 Fault Event (Fault Event) 303 23 1 2 Yes Device, General OUT * 13 5 23 2 2 Yes sensitive Ground fault (sens Gnd flt) Device, General OUT 320 Warn: Limit of Memory Data exceeded (Warn Mem. Data) Device, General OUT On * Of f * LED BO 321 Warn: Limit of Memory Parameter exceeded (Warn Mem. Para.) Device, General OUT On * Of f * LED BO 322 Warn: Limit of Memory Operation exceeded (Warn Mem. Oper.) Device, General OUT On * Of f * LED BO 323 Warn: Limit of Memory New exceeded (Warn Mem. New) Device, General OUT On * Of f * LED BO 335 >GOOSE-Stop (>GOOSEStop) Device, General SP On Of f * LED BI FK BO TO NL IN E 356 >Manual close signal (>Manual Close) P.System Data 2 SP * * * LED BI BO 15 0 6 1 Yes 395 >I MIN/MAX Buffer Reset (>I MinMax Reset) Min/Max meter SP On * * LED BI BO 396 >I1 MIN/MAX Buffer Reset Min/Max (>I1 MiMaReset) meter SP On * * LED BI BO 512 On Chatter Suppression 13 5 Relay OUT On On Of Off f Function Key Yes Binary Input 1 Ground Fault Log ON/OFF 22 9 Trip (Fault) Log ON/OFF 13 5 Event Log ON/OFF 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 F.3 Information List ON OF F SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 LED BI BO 398 >Vphph MIN/MAX Buffer Reset (>VphphMiMaRes) Min/Max meter SP On * * LED BI BO 399 >V1 MIN/MAX Buffer Reset (>V1 MiMa Reset) Min/Max meter SP On * * LED BI BO 400 >P MIN/MAX Buffer Reset Min/Max (>P MiMa Reset) meter SP On * * LED BI BO 401 >S MIN/MAX Buffer Reset Min/Max (>S MiMa Reset) meter SP On * * LED BI BO 402 >Q MIN/MAX Buffer Reset Min/Max (>Q MiMa Reset) meter SP On * * LED BI BO 403 >Idmd MIN/MAX Buffer Min/Max Reset (>Idmd MiMaReset) meter SP On * * LED BI BO 404 >Pdmd MIN/MAX Buffer Reset (>Pdmd MiMaReset) Min/Max meter SP On * * LED BI BO 405 >Qdmd MIN/MAX Buffer Reset (>Qdmd MiMaReset) Min/Max meter SP On * * LED BI BO 406 >Sdmd MIN/MAX Buffer Reset (>Sdmd MiMaReset) Min/Max meter SP On * * LED BI BO 407 >Frq. MIN/MAX Buffer Reset (>Frq MiMa Reset) Min/Max meter SP On * * LED BI BO 408 >Power Factor MIN/MAX Min/Max Buffer Reset (>PF MiMaR- meter eset) SP On * * LED BI BO 409 >BLOCK Op Counter (>BLOCK Op Count) Statistics SP On Of f * LED BI BO 412 >Theta MIN/MAX Buffer Reset (> MiMa Reset) Min/Max meter SP On * * LED BI BO 466.40 Trip via control command P.System 10 (Cmd Trip) Data 2 IntS On On P Of f * LED BO 501 Relay PICKUP (Relay PICKUP) P.System Data 2 OUT m LED BO 502 Relay Drop Out (Relay Drop Out) Device, General SP * * 510 General CLOSE of relay (Relay CLOSE) Device, General SP * * SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 ON General Interrogation * Data Unit On * information number SP Type >V MIN/MAX Buffer Reset Min/Max (>V MiMaReset) meter Chatter Suppression 397 Relay Binary Input 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 F.3 Information List 15 0 15 1 2 Yes 513 Functions, Settings, Information F.3 Information List P.System Data 2 OUT ON 533 Primary fault current Ia (Ia P.System =) Data 2 VI 534 Primary fault current Ib (Ib =) P.System Data 2 535 m LED 17 7 4 No VI ON OFF 15 0 17 8 4 No Primary fault current Ic (Ic P.System =) Data 2 VI ON OFF 15 0 17 9 4 No 545 Time from Pickup to drop Device, out (PU Time) General VI 546 Time from Pickup to TRIP (TRIP Time) Device, General VI 561 Manual close signal detected (Man.Clos.Detect) P.System Data 2 OUT On * Of f 916 Increment of active energy (Wp=) Energy - 917 Increment of reactive energy (Wq=) Energy - 1020 Counter of operating hours (Op.Hours=) Statistics VI 1021 Accumulation of interrupted current Ph A ( Ia =) Statistics VI 1022 Accumulation of interrupted current Ph B ( Ib =) Statistics VI 1023 Accumulation of interrupted current Ph C ( Ic =) Statistics VI 1106 >Start Fault Locator (>Start Flt. Loc) Fault Locator SP 15 1 6 1 Yes 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 15 1 15 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 514 On * * LED * LED BO Chatter Suppression 15 0 Relay ON OFF Function Key Yes Binary Input 2 Ground Fault Log ON/OFF 16 1 Trip (Fault) Log ON/OFF 15 0 Event Log ON/OFF General Interrogation Relay GENERAL TRIP command (Relay TRIP) Data Unit 511 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 BI BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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 AG (FL Fault Loop AG) Locator OUT * On * LED BO 1124 Fault Locator Loop BG (FL Fault Loop BG) Locator OUT * On * LED BO 1125 Fault Locator Loop CG (FL Fault Loop CG) Locator OUT * On * LED BO 1126 Fault Locator Loop AB (FL Fault Loop AB) Locator OUT * On * LED BO 1127 Fault Locator Loop BC (FL Fault Loop BC) Locator OUT * On * LED BO 1128 Fault Locator Loop CA (FL Fault Loop CA) Locator OUT * On * LED BO 1132 Fault location invalid (Flt.Loc.invalid) Fault Locator OUT * On * LED BO 1201 >BLOCK 64 (>BLOCK 64) Sens. Gnd Fault SP On * Of f * LED BI BO 15 1 10 1 1 Yes 1202 >BLOCK 50Ns-2 (>BLOCK Sens. Gnd 50Ns-2) Fault SP On * Of f * LED BI BO 15 1 10 2 1 Yes 1203 >BLOCK 50Ns-1 (>BLOCK Sens. Gnd 50Ns-1) Fault SP On * Of f * LED BI BO 15 1 10 3 1 Yes 1204 >BLOCK 51Ns (>BLOCK 51Ns) Sens. Gnd Fault SP On * Of f * LED BI BO 15 1 10 4 1 Yes 1207 >BLOCK 50Ns/67Ns (>BLK Sens. Gnd 50Ns/67Ns) Fault SP On * Of f * LED BI BO 15 1 10 7 1 Yes 1211 50Ns/67Ns is OFF (50Ns/ 67Ns OFF) Sens. Gnd Fault OUT On * Of f * LED BO 15 1 11 1 1 Yes 1212 50Ns/67Ns is ACTIVE (50Ns/67Ns ACT) Sens. Gnd Fault OUT On * Of f * LED BO 15 1 11 2 1 Yes 1215 64 displacement voltage pick up (64 Pickup) Sens. Gnd Fault OUT * On Off * LED BO 15 1 11 5 2 Yes 1217 64 displacement voltage element TRIP (64 TRIP) Sens. Gnd Fault OUT * On m LED BO 15 1 11 7 2 Yes Chatter Suppression ON OFF Relay VI Function Key Fault Locator Binary Input Flt Locator: Distance [%] to fault (d[%] =) LED 1120 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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 F.3 Information List 515 Type information number Data Unit General Interrogation OUT * On Off * LED BO 15 1 12 1 2 Yes 1223 50Ns-2 TRIP (50Ns-2 TRIP) Sens. Gnd Fault OUT * On m LED BO 15 1 12 3 2 Yes 1224 50Ns-1 Pickup (50Ns-1 Pickup) Sens. Gnd Fault OUT * On Off * LED BO 15 1 12 4 2 Yes 1226 50Ns-1 TRIP (50Ns-1 TRIP) Sens. Gnd Fault OUT * On m LED BO 15 1 12 6 2 Yes 1227 51Ns picked up (51Ns Pickup) Sens. Gnd Fault OUT * On Off * LED BO 15 1 12 7 2 Yes 1229 51Ns TRIP (51Ns TRIP) Sens. Gnd Fault OUT * On m LED BO 15 1 12 9 2 Yes 1230 Sensitive ground fault Sens. Gnd detection BLOCKED (Sens. Fault Gnd block) OUT On On Of Off f * LED BO 15 1 13 0 1 Yes 1264 Corr. Resistive Earth current (IEEa =) Sens. Gnd Fault VI ON OF F 1265 Corr. Reactive Earth current (IEEr =) Sens. Gnd Fault VI ON OF F 1266 Earth current, absolute Value (IEE =) Sens. Gnd Fault VI ON OF F 1267 Displacement Voltage VGND, 3Vo (VGND, 3Vo) Sens. Gnd Fault VI ON OF F 1271 Sensitive Ground fault Sens. Gnd pick up (Sens.Gnd Pickup) Fault OUT * LED BO 15 1 17 1 1 Yes 1272 Sensitive Ground fault picked up in Ph A (Sens. Gnd Ph A) Sens. Gnd Fault OUT On On Of f On * Off LED BO 16 0 48 1 Yes 1273 Sensitive Ground fault picked up in Ph B (Sens. Gnd Ph B) Sens. Gnd Fault OUT On On Of f On * Off LED BO 16 0 49 1 Yes 1274 Sensitive Ground fault picked up in Ph C (Sens. Gnd Ph C) Sens. Gnd Fault OUT On On Of f On * Off LED BO 16 0 50 1 Yes 1276 Sensitive Gnd fault in forward direction (SensGnd Forward) Sens. Gnd Fault OUT On On Of f On * Off LED BO 16 0 51 1 Yes 1277 Sensitive Gnd fault in reverse direction (SensGnd Reverse) Sens. Gnd Fault OUT On On Of f On * Off LED BO 16 0 52 1 Yes * Chatter Suppression Sens. Gnd Fault Relay 50Ns-2 Pickup (50Ns-2 Pickup) Function Key LED 1221 516 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.3 Information List Sensitive Gnd fault direction undefined (SensGnd undef.) Sens. Gnd Fault OUT On On Of f 1403 >BLOCK 50BF (>BLOCK 50BF) 50BF BkrFai- SP lure 1404 >50BF Activate 3I0> threshold (>50BFactiv. 3I0>) 16 6 10 3 1 Yes LED BI BO * LED BI BO 16 6 10 4 1 Yes 50BF BkrFai- OUT On * lure Of f * LED BO 16 6 15 1 1 Yes 50BF is BLOCKED (50BF BLOCK) 50BF BkrFai- OUT On On lure Of Off f * LED BO 16 6 15 2 1 Yes 1453 50BF is ACTIVE (50BF ACTIVE) 50BF BkrFai- OUT On * lure Of f * LED BO 16 6 15 3 1 Yes 1456 50BF (internal) PICKUP (50BF int Pickup) 50BF BkrFai- OUT * lure On Off * LED BO 16 6 15 6 2 Yes 1457 50BF (external) PICKUP (50BF ext Pickup) 50BF BkrFai- OUT * lure On Off * LED BO 16 6 15 7 2 Yes 1471 50BF TRIP (50BF TRIP) 50BF BkrFai- OUT * lure On m LED BO 16 0 85 2 No 1480 50BF (internal) TRIP (50BF int TRIP) 50BF BkrFai- OUT * lure On * LED BO 16 6 18 0 2 Yes 1481 50BF (external) TRIP (50BF ext TRIP) 50BF BkrFai- OUT * lure On * LED BO 16 6 18 1 2 Yes 1494 50BF TRIP 2 (50BF TRIP 2) 50BF BkrFai- OUT * lure On * LED BO 1503 >BLOCK 49 Overload Protection (>BLOCK 49 O/L) 49 Th.Over- SP load * * * LED BI BO 16 7 3 1 Yes 1507 >Emergency start of motors (>EmergencyStart) 49 Th.Over- SP load On * Of f * LED BI BO 16 7 7 1 Yes 1511 49 Overload Protection is 49 Th.Over- OUT On * OFF (49 O / L OFF) load Of f * LED BO 16 7 11 1 Yes * LED 50BF BkrFai- SP lure On * Of f * 1431 >50BF initiated externally 50BF BkrFai- SP (>50BF ext SRC) lure On * Of f 1451 50BF is switched OFF (50BF OFF) 1452 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression BO On * Of f Relay BI LED Function Key Yes On * Off Binary Input 1 Marked in Oscill. Record 17 8 Ground Fault Log ON/OFF 15 1 Trip (Fault) Log ON/OFF BO Event Log ON/OFF General Interrogation 1278 Configurable in Matrix IEC 60870-5-103 Data Unit Typ Log Buffers e of Info rma tion information number Function Type Description LED No. 517 Type information number Data Unit General Interrogation LED BO 16 7 12 1 Yes 1513 49 Overload Protection is 49 Th.Over- OUT On * ACTIVE (49 O/L ACTIVE) load Of f * LED BO 16 7 13 1 Yes 1515 49 Overload Current Alarm (I alarm) (49 O/L I Alarm) 49 Th.Over- OUT On * load Of f * LED BO 16 7 15 1 Yes 1516 49 Overload Alarm! Near Thermal Trip (49 O/L Alarm) 49 Th.Over- OUT On * load Of f * LED BO 16 7 16 1 Yes 1517 49 Winding Overload (49 49 Th.Over- OUT On * Winding O/L) load Of f * LED BO 16 7 17 1 Yes 1521 49 Thermal Overload TRIP 49 Th.Over- OUT * (49 Th O/L TRIP) load m LED BO 16 7 21 2 Yes 1580 >49 Reset of Thermal 49 Th.Over- SP Overload Image (>RES 49 load Image) On * Of f * LED 1581 49 Thermal Overload Image reset (49 Image res.) 49 Th.Over- OUT On * load Of f * LED 1704 >BLOCK 50/51 (>BLK 50/51) 50/51 Overcur. SP * * * LED BI BO 1714 >BLOCK 50N/51N (>BLK 50N/51N) 50/51 Overcur. SP * * * LED BI BO 1718 >BLOCK 50-3 (>BLOCK 50-3) 50/51 Overcur. SP * * * LED BI BO 60 14 4 1 Yes 1719 >BLOCK 50N-3 (>BLOCK 50N-3) 50/51 Overcur. SP * * * LED BI BO 60 14 5 1 Yes 1721 >BLOCK 50-2 (>BLOCK 50-2) 50/51 Overcur. SP * * * LED BI BO 60 1 1 Yes 1722 >BLOCK 50-1 (>BLOCK 50-1) 50/51 Overcur. SP * * * LED BI BO 60 2 1 Yes 1723 >BLOCK 51 (>BLOCK 51) 50/51 Overcur. SP * * * LED BI BO 60 3 1 Yes 1724 >BLOCK 50N-2 (>BLOCK 50N-2) 50/51 Overcur. SP * * * LED BI BO 60 4 1 Yes 1725 >BLOCK 50N-1 (>BLOCK 50N-1) 50/51 Overcur. SP * * * LED BI BO 60 5 1 Yes 1726 >BLOCK 51N (>BLOCK 51N) 50/51 Overcur. SP * * * LED BI BO 60 6 1 Yes 518 BI Chatter Suppression * Relay 49 Overload Protection is 49 Th.Over- OUT On On BLOCKED (49 O/L BLOCK) load Of Off f Function Key 1512 On 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 F.3 Information List BO BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 LED Binary Input Configurable in Matrix IEC 60870-5-103 1730 >BLOCK Cold-Load-Pickup ColdLoad(>BLOCK CLP) Pickup SP * * * LED BI BO 1731 >BLOCK Cold-Load-Pickup ColdLoadstop timer (>BLK CLP Pickup stpTim) SP On * Of f * LED BI BO 1732 >ACTIVATE Cold-LoadPickup (>ACTIVATE CLP) ColdLoadPickup SP On * Of f * LED BI BO 1751 50/51 O/C switched OFF (50/51 PH OFF) 50/51 Overcur. OUT On * Of f * LED 1752 50/51 O/C is BLOCKED (50/51 PH BLK) 50/51 Overcur. OUT On On Of Off f * 1753 50/51 O/C is ACTIVE (50/51 PH ACT) 50/51 Overcur. OUT On * Of f 1756 50N/51N is OFF (50N/51N 50/51 OFF) Overcur. 1757 50N/51N is BLOCKED (50N/51N BLK) 1758 Yes BO 60 21 1 Yes LED BO 60 22 1 Yes * LED BO 60 23 1 Yes OUT On * Of f * LED BO 60 26 1 Yes 50/51 Overcur. OUT On On Of Off f * LED BO 60 27 1 Yes 50N/51N is ACTIVE (50N/51N ACT) 50/51 Overcur. OUT On * Of f * LED BO 60 28 1 Yes 1761 50(N)/51(N) O/C PICKUP (50(N)/51(N) PU) 50/51 Overcur. OUT * On Off m LED BO 16 0 84 2 Yes 1762 50/51 Phase A picked up (50/51 Ph A PU) 50/51 Overcur. OUT * On Off m LED BO 16 0 64 2 Yes 1763 50/51 Phase B picked up (50/51 Ph B PU) 50/51 Overcur. OUT * On Off m LED BO 16 0 65 2 Yes 1764 50/51 Phase C picked up (50/51 Ph C PU) 50/51 Overcur. OUT * On Off m LED BO 16 0 66 2 Yes 1765 50N/51N picked up (50N/ 50/51 51NPickedup) Overcur. OUT * On Off m LED BO 16 0 67 2 Yes 1767 50-3 picked up (50-3 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 14 6 2 Yes 1768 50N-3 picked up (50N-3 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 14 7 2 Yes 1769 50-3 TRIP (50-3 TRIP) 50/51 Overcur. OUT * On * LED BO 60 14 8 2 Yes 1770 50N-3 TRIP (50N-3 TRIP) 50/51 Overcur. OUT * On * LED BO 60 14 9 2 Yes SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression 1 Relay 24 3 Function Key 60 Ground Fault Log ON/OFF General Interrogation Marked in Oscill. Record Typ Log Buffers e of Info rma tion Data Unit Trip (Fault) Log ON/OFF Function information number Description Type No. Event Log ON/OFF Functions, Settings, Information F.3 Information List 519 Type information number Data Unit General Interrogation OUT * * * LED BO 60 16 7 2 Yes 1788 50N-3 TimeOut (50N-3 TimeOut) 50/51 Overcur. OUT * * * LED BO 60 16 8 2 Yes 1791 50(N)/51(N) TRIP (50(N)/ 51(N)TRIP) 50/51 Overcur. OUT * On m LED BO 16 0 68 2 No 1800 50-2 picked up (50-2 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 75 2 Yes 1804 50-2 Time Out (50-2 TimeOut) 50/51 Overcur. OUT * * * LED BO 60 49 2 Yes 1805 50-2 TRIP (50-2 TRIP) 50/51 Overcur. OUT * On m LED BO 16 0 91 2 No 1810 50-1 picked up (50-1 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 76 2 Yes 1814 50-1 Time Out (50-1 TimeOut) 50/51 Overcur. OUT * * * LED BO 60 53 2 Yes 1815 50-1 TRIP (50-1 TRIP) 50/51 Overcur. OUT * On m LED BO 16 0 90 2 No 1820 51 picked up (51 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 77 2 Yes 1824 51 Time Out (51 Time Out) 50/51 Overcur. OUT * * * LED BO 60 57 2 Yes 1825 51 TRIP (51 TRIP) 50/51 Overcur. OUT * On m LED BO 60 58 2 Yes 1831 50N-2 picked up (50N-2 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 59 2 Yes 1832 50N-2 Time Out (50N-2 TimeOut) 50/51 Overcur. OUT * * * LED BO 60 60 2 Yes 1833 50N-2 TRIP (50N-2 TRIP) 50/51 Overcur. OUT * On m LED BO 16 0 93 2 No 1834 50N-1 picked up (50N-1 picked up) 50/51 Overcur. OUT * On Off * LED BO 60 62 2 Yes 1835 50N-1 Time Out (50N-1 TimeOut) 50/51 Overcur. OUT * * * LED BO 60 63 2 Yes 1836 50N-1 TRIP (50N-1 TRIP) 50/51 Overcur. OUT * On m LED BO 16 0 92 2 No 1837 51N picked up (51N picked up) 50/51 Overcur. OUT * On Off * LED BO 60 64 2 Yes 1838 51N Time Out (51N TimeOut) 50/51 Overcur. OUT * * * LED BO 60 65 2 Yes 1839 51N TRIP (51N TRIP) 50/51 Overcur. OUT * On m LED BO 60 66 2 Yes Chatter Suppression 50/51 Overcur. Relay 50-3 TimeOut (50-3 TimeOut) Function Key LED 1787 520 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation OUT * On Off * LED BO 60 10 1 2 Yes 1841 Phase B inrush detection (PhB InrushDet) 50/51 Overcur. OUT * On Off * LED BO 60 10 2 2 Yes 1842 Phase C inrush detection (PhC InrushDet) 50/51 Overcur. OUT * On Off * LED BO 60 10 3 2 Yes 1843 Cross blk: PhX blocked PhY (INRUSH X-BLK) 50/51 Overcur. OUT * On Off * LED BO 60 10 4 2 Yes 1851 50-1 BLOCKED (50-1 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 10 5 1 Yes 1852 50-2 BLOCKED (50-2 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 10 6 1 Yes 1853 50N-1 BLOCKED (50N-1 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 10 7 1 Yes 1854 50N-2 BLOCKED (50N-2 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 10 8 1 Yes 1855 51 BLOCKED (51 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 10 9 1 Yes 1856 51N BLOCKED (51N BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 11 0 1 Yes 1866 51 Disk emulation Pickup 50/51 (51 Disk Pickup) Overcur. OUT * * * LED BO 1867 51N Disk emulation picked up (51N Disk Pickup) 50/51 Overcur. OUT * * * LED BO 1994 Cold-Load-Pickup switched OFF (CLP OFF) ColdLoadPickup OUT On * Of f * LED BO 60 24 4 1 Yes 1995 Cold-Load-Pickup is ColdLoadBLOCKED (CLP BLOCKED) Pickup OUT On On Of Off f * LED BO 60 24 5 1 Yes 1996 Cold-Load-Pickup is RUNNING (CLP running) ColdLoadPickup OUT On * Of f * LED BO 60 24 6 1 Yes 1997 Dynamic settings are ColdLoadACTIVE (Dyn set. ACTIVE) Pickup OUT On * Of f * LED BO 60 24 7 1 Yes Chatter Suppression 50/51 Overcur. Relay Phase A inrush detection (PhA InrushDet) Function Key LED 1840 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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 F.3 Information List 521 Type information number Data Unit General Interrogation OUT * On * LED 2604 >BLOCK 67/67-TOC (>BLK 67 Direct. 67/67-TOC) O/C SP * * LED 2605 67N-3 is BLOCKED (67N-3 67 Direct. BLOCKED) O/C OUT On On Of Off f * LED BO 2606 67-3 is BLOCKED (67-3 BLOCKED) 67 Direct. O/C OUT On On Of Off f * LED BO 2614 >BLOCK 67N/67N-TOC (>BLK 67N/67NTOC) 67 Direct. O/C SP * * * LED BI BO 2615 >BLOCK 67-2 (>BLOCK 67-2) 67 Direct. O/C SP * * * LED BI BO 63 73 1 Yes 2616 >BLOCK 67N-2 (>BLOCK 67N-2) 67 Direct. O/C SP * * * LED BI BO 63 74 1 Yes 2617 >BLOCK 67-3 (>BLOCK 67-3) 67 Direct. O/C SP * * * LED BI BO 2618 >BLOCK 67N-3 (>BLOCK 67N-3) 67 Direct. O/C SP * * * LED BI BO 2621 >BLOCK 67-1 (>BLOCK 67-1) 67 Direct. O/C SP * * * LED BI BO 63 1 1 Yes 2622 >BLOCK 67-TOC (>BLOCK 67 Direct. 67-TOC) O/C SP * * * LED BI BO 63 2 1 Yes 2623 >BLOCK 67N-1 (>BLOCK 67N-1) 67 Direct. O/C SP * * * LED BI BO 63 3 1 Yes 2624 >BLOCK 67N-TOC (>BLOCK 67N-TOC) 67 Direct. O/C SP * * * LED BI BO 63 4 1 Yes 2628 Phase A forward (Phase A 67 Direct. forward) O/C OUT On * * LED BO 63 81 1 Yes 2629 Phase B forward (Phase B 67 Direct. forward) O/C OUT On * * LED BO 63 82 1 Yes 2630 Phase C forward (Phase C 67 Direct. forward) O/C OUT On * * LED BO 63 83 1 Yes 2632 Phase A reverse (Phase A reverse) 67 Direct. O/C OUT On * * LED BO 63 84 1 Yes 2633 Phase B reverse (Phase B reverse) 67 Direct. O/C OUT On * * LED BO 63 85 1 Yes 2634 Phase C reverse (Phase C reverse) 67 Direct. O/C OUT On * * LED BO 63 86 1 Yes 2635 Ground forward (Ground forward) 67 Direct. O/C OUT On * * LED BO 63 87 1 Yes 522 Chatter Suppression 67 Direct. O/C Relay 67N-3 TRIP (67N-3 TRIP) Function Key LED 2603 * 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 F.3 Information List BO BI BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation OUT On * * LED BO 63 88 1 Yes 2637 67-1 is BLOCKED (67-1 BLOCKED) 67 Direct. O/C OUT On On Of Off f * LED BO 63 91 1 Yes 2642 67-2 picked up (67-2 picked up) 67 Direct. O/C OUT * On Off * LED BO 63 67 2 Yes 2646 67N-2 picked up (67N-2 picked up) 67 Direct. O/C OUT * On Off * LED BO 63 62 2 Yes 2647 67-2 Time Out (67-2 Time 67 Direct. Out) O/C OUT * * * LED BO 63 71 2 Yes 2648 67N-2 Time Out (67N-2 Time Out) 67 Direct. O/C OUT * * * LED BO 63 63 2 Yes 2649 67-2 TRIP (67-2 TRIP) 67 Direct. O/C OUT * On m LED BO 63 72 2 Yes 2651 67/67-TOC switched OFF (67/67-TOC OFF) 67 Direct. O/C OUT On * Of f * LED BO 63 10 1 Yes 2652 67/67-TOC is BLOCKED (67 BLOCKED) 67 Direct. O/C OUT On On Of Off f * LED BO 63 11 1 Yes 2653 67/67-TOC is ACTIVE (67 ACTIVE) 67 Direct. O/C OUT On * Of f * LED BO 63 12 1 Yes 2655 67-2 is BLOCKED (67-2 BLOCKED) 67 Direct. O/C OUT On On Of Off f * LED BO 63 92 1 Yes 2656 67N/67N-TOC switched OFF (67N OFF) 67 Direct. O/C OUT On * Of f * LED BO 63 13 1 Yes 2657 67N/67N-TOC is BLOCKED 67 Direct. (67N BLOCKED) O/C OUT On On Of Off f * LED BO 63 14 1 Yes 2658 67N/67N-TOC is ACTIVE (67N ACTIVE) OUT On * Of f * LED BO 63 15 1 Yes 2659 67N-1 is BLOCKED (67N-1 67 Direct. BLOCKED) O/C OUT On On Of Off f * LED BO 63 93 1 Yes 2660 67-1 picked up (67-1 picked up) 67 Direct. O/C OUT * On Off * LED BO 63 20 2 Yes 2664 67-1 Time Out (67-1 Time 67 Direct. Out) O/C OUT * * * LED BO 63 24 2 Yes SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression 67 Direct. O/C Relay Ground reverse (Ground reverse) Function Key LED 2636 67 Direct. O/C 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 F.3 Information List 523 Functions, Settings, Information F.3 Information List 67 Direct. O/C OUT * 2668 2 Yes 67N-2 is BLOCKED (67N-2 67 Direct. BLOCKED) O/C OUT On On Of Off f * LED BO 63 94 1 Yes 2669 67-TOC is BLOCKED (67TOC BLOCKED) 67 Direct. O/C OUT On On Of Off f * LED BO 63 95 1 Yes 2670 67-TOC picked up (67TOC pickedup) 67 Direct. O/C OUT * On Off * LED BO 63 30 2 Yes 2674 67-TOC Time Out (67TOC Time Out) 67 Direct. O/C OUT * * * LED BO 63 34 2 Yes 2675 67-TOC TRIP (67-TOC TRIP) 67 Direct. O/C OUT * On m LED BO 63 35 2 Yes 2676 67-TOC disk emulation is ACTIVE (67-TOC DiskPU) 67 Direct. O/C OUT * * * LED BO 2677 67N-TOC is BLOCKED (67N-TOC BLOCKED) 67 Direct. O/C OUT On On Of Off f * LED BO 63 96 1 Yes 2678 67-3 TRIP (67-3 TRIP) 67 Direct. O/C OUT * On * LED BO 2679 67N-2 TRIP (67N-2 TRIP) 67 Direct. O/C OUT * On m LED BO 63 64 2 Yes 2681 67N-1 picked up (67N-1 picked up) 67 Direct. O/C OUT * On Off * LED BO 63 41 2 Yes 2682 67N-1 Time Out (67N-1 Time Out) 67 Direct. O/C OUT * * * LED BO 63 42 2 Yes 2683 67N-1 TRIP (67N-1 TRIP) 67 Direct. O/C OUT * On m LED BO 63 43 2 Yes 2684 67N-TOC picked up (67N- 67 Direct. TOCPickedup) O/C OUT * On Off * LED BO 63 44 2 Yes 2685 67N-TOC Time Out (67N- 67 Direct. TOC TimeOut) O/C OUT * * * LED BO 63 45 2 Yes 2686 67N-TOC TRIP (67N-TOC TRIP) 67 Direct. O/C OUT * On m LED BO 63 46 2 Yes 2687 67N-TOC disk emulation is ACTIVE (67N-TOC Disk PU) 67 Direct. O/C OUT * * * LED BO 2691 67/67N picked up (67/67N pickedup) 67 Direct. O/C OUT * On Off m LED BO 63 50 2 Yes 2692 67/67-TOC Phase A picked up (67 A picked up) 67 Direct. O/C OUT * On Off * LED BO 63 51 2 Yes 524 Chatter Suppression 25 Relay 63 Function Key BO Binary Input LED Ground Fault Log ON/OFF m Trip (Fault) Log ON/OFF On Event Log ON/OFF General Interrogation 67-1 TRIP (67-1 TRIP) Data Unit 2665 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, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation On Off * LED BO 63 52 2 Yes 2694 67/67-TOC Phase C picked 67 Direct. up (67 C picked up) O/C OUT * On Off * LED BO 63 53 2 Yes 2695 67N/67N-TOC picked up (67N picked up) 67 Direct. O/C OUT * On Off * LED BO 63 54 2 Yes 2696 67/67N TRIP (67/67N TRIP) 67 Direct. O/C OUT * On m LED BO 63 55 2 Yes 2697 67-3 picked up (67-3 picked up) 67 Direct. O/C OUT * On Off * LED BO 2698 67N-3 picked up (67N-3 picked up) 67 Direct. O/C OUT * On Off * LED BO 2699 67-3 Time Out (67-3 Time 67 Direct. Out) O/C OUT * * * LED BO 2700 67N-3 Time Out (67N-3 Time Out) 67 Direct. O/C OUT * * * LED BO 2701 >79 ON (>79 ON) 79M Auto Recl. SP On * Of f * LED BI BO 40 1 1 Yes 2702 >79 OFF (>79 OFF) 79M Auto Recl. SP On * Of f * LED BI BO 40 2 1 Yes 2703 >BLOCK 79 (>BLOCK 79) 79M Auto Recl. SP On * Of f * LED BI BO 40 3 1 Yes 2711 >79 External start of internal A/R (>79 Start) 79M Auto Recl. SP * On Off * LED BI BO 2715 >Start 79 Ground program (>Start 79 Gnd) 79M Auto Recl. SP * On * LED BI BO 40 15 2 Yes 2716 >Start 79 Phase program (>Start 79 Ph) 79M Auto Recl. SP * On * LED BI BO 40 16 2 Yes 2720 >Enable 50/67-(N)-2 P.System (override 79 blk) (>Enable Data 2 ANSI#-2) SP On * Of f * LED BI BO 40 20 1 Yes 2722 >Switch zone sequence coordination ON (>ZSC ON) 79M Auto Recl. SP On * Of f * LED BI BO 2723 >Switch zone sequence coordination OFF (>ZSC OFF) 79M Auto Recl. SP On * Of f * LED BI BO 2730 >Circuit breaker READY 79M Auto for reclosing (>CB Ready) Recl. SP On * Of f * LED BI BO 40 30 1 Yes Chatter Suppression OUT * Relay 67/67-TOC Phase B picked 67 Direct. up (67 B picked up) O/C Function Key 2693 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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 F.3 Information List 525 Functions, Settings, Information F.3 Information List SP 2753 79: Max. Dead Time Start 79M Auto Delay expired (79 DT Recl. delay ex.) 2754 >79: Dead Time Start Delay (>79 DT St.Delay) 2781 LED 79M Auto Recl. SP On * Of f * LED 79 Auto recloser is switched OFF (79 OFF) 79M Auto Recl. OUT On * * LED BO 40 81 1 Yes 2782 79 Auto recloser is switched ON (79 ON) 79M Auto Recl. IntS On * P Of f * LED BO 16 0 16 1 Yes 2784 79 Auto recloser is NOT ready (79 is NOT ready) 79M Auto Recl. OUT On * Of f * LED BO 16 0 13 0 1 Yes 2785 79 - Auto-reclose is 79M Auto dynamically BLOCKED (79 Recl. DynBlock) OUT On On Of f * LED BO 40 85 1 Yes 2788 79: CB ready monitoring window expired (79 TCBreadyExp) 79M Auto Recl. OUT On * * LED BO 2801 79 - in progress (79 in progress) 79M Auto Recl. OUT * * LED BO 40 10 1 2 Yes 2808 79: CB open with no trip (79 BLK: CB open) 79M Auto Recl. OUT On * Of f * LED BO 2809 79: Start-signal moni79M Auto toring time expired (79 T- Recl. Start Exp) OUT On * * LED BO 2810 79: Maximum dead time expired (79 TdeadMax Exp) 79M Auto Recl. OUT On * * LED BO 2823 79: no starter configured (79 no starter) 79M Auto Recl. OUT On * Of f * LED BO 2824 79: no cycle configured (79 no cycle) 79M Auto Recl. OUT On * Of f * LED BO 2827 79: blocking due to trip (79 BLK by trip) 79M Auto Recl. OUT On * * LED BO 526 On Chatter Suppression * Relay OUT On * On Function Key BI * Ground Fault Log ON/OFF LED Trip (Fault) Log ON/OFF * Event Log ON/OFF General Interrogation 79M Auto Recl. Data Unit >79: Sync. release from ext. sync.-check (>Sync.release) information number 2731 Configurable in Matrix IEC 60870-5-103 Type Typ Log Buffers e of Info rma tion Binary Input Function LED Description Marked in Oscill. Record No. BO BO BI BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation * LED BO 2829 79: action time expired before trip (79 Tact expired) 79M Auto Recl. OUT On * * LED BO 2830 79: max. no. of cycles exceeded (79 Max. No. Cyc) 79M Auto Recl. OUT On * * LED BO 2844 79 1st cycle running (79 1stCyc. run.) 79M Auto Recl. OUT * On * LED BO 2845 79 2nd cycle running (79 79M Auto 2ndCyc. run.) Recl. OUT * On * LED BO 2846 79 3rd cycle running (79 3rdCyc. run.) 79M Auto Recl. OUT * On * LED BO 2847 79 4th or higher cycle 79M Auto running (79 4thCyc. run.) Recl. OUT * On * LED BO 2851 79 - Close command (79 Close) 79M Auto Recl. OUT * On m LED BO 16 0 12 8 2 No 2862 79 - cycle successful (79 Successful) 79M Auto Recl. OUT On On * LED BO 40 16 2 1 Yes 2863 79 - Lockout (79 Lockout) 79M Auto Recl. OUT On On * LED BO 40 16 3 2 Yes 2865 79: Synchro-check request (79 Sync.Request) 79M Auto Recl. OUT * On * LED BO 2878 79-A/R single phase 79M Auto reclosing sequence (79 L- Recl. N Sequence) OUT * On * LED BO 40 18 0 2 Yes 2879 79-A/R multi-phase 79M Auto reclosing sequence (79 L- Recl. L Sequence) OUT * On * LED BO 40 18 1 2 Yes 2883 Zone Sequencing is active 79M Auto (ZSC active) Recl. OUT On On Of f * LED BO 2884 Zone sequence coordina- 79M Auto tion switched ON (ZSC Recl. ON) OUT On * * LED BO 2885 Zone sequence coordina- 79M Auto tion switched OFF (ZSC Recl. OFF) OUT On * * LED BO 2889 79 1st cycle zone exten- 79M Auto sion release (79 1.CycZo- Recl. neRel) OUT * * LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Chatter Suppression OUT On * Relay 79: blocking due to 379M Auto phase pickup (79 BLK:3ph Recl. p.u.) Function Key 2828 * 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 F.3 Information List 527 2890 79 2nd cycle zone exten- 79M Auto sion release (79 2.CycZo- Recl. neRel) OUT * * * LED BO 2891 79 3rd cycle zone exten- 79M Auto sion release (79 3.CycZo- Recl. neRel) OUT * * * LED BO 2892 79 4th cycle zone exten- 79M Auto sion release (79 4.CycZo- Recl. neRel) OUT * * * LED BO 2896 No. of 1st AR-cycle CLOSE Statistics commands,3pole (79 #Close1./3p=) VI 2898 No. of higher AR-cycle Statistics CLOSE commands,3p (79 #Close2./3p=) VI 2899 79: Close request to Control Function (79 CloseRequest) 79M Auto Recl. OUT * On * LED BO 4601 >52-a contact (OPEN, if bkr is open) (>52-a) P.System Data 2 SP On * Of f * LED BI BO 4602 >52-b contact (OPEN, if bkr is closed) (>52-b) P.System Data 2 SP On * Of f * LED BI BO 5143 >BLOCK 46 (>BLOCK 46) 46 Negative SP Seq * * * LED BI BO 5145 >Reverse Phase Rotation (>Reverse Rot.) P.System Data 1 On * Of f * LED BI BO 5147 Phase rotation ABC (Rota- P.System tion ABC) Data 1 OUT On * Of f * LED 5148 Phase rotation ACB (Rota- P.System tion ACB) Data 1 OUT On * Of f * 5151 46 switched OFF (46 OFF) 46 Negative OUT On * Seq Of f 5152 46 is BLOCKED (46 BLOCKED) 5153 46 is ACTIVE (46 ACTIVE) 12 8 1 Yes LED BO 70 12 9 1 Yes * LED BO 70 13 1 1 Yes 46 Negative OUT On On Seq Of Off f * LED BO 70 13 2 1 Yes 46 Negative OUT On * Seq Of f * LED BO 70 13 3 1 Yes Chatter Suppression 70 Relay BO SP Function Key Yes Binary Input 1 Ground Fault Log ON/OFF 12 6 Trip (Fault) Log ON/OFF 70 Event Log ON/OFF 528 Configurable in Matrix IEC 60870-5-103 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation On Off * LED BO 70 13 8 2 Yes 5165 46-1 picked up (46-1 picked up) 46 Negative OUT * Seq On Off * LED BO 70 15 0 2 Yes 5166 46-TOC picked up (46TOC pickedup) 46 Negative OUT * Seq On Off * LED BO 70 14 1 2 Yes 5170 46 TRIP (46 TRIP) 46 Negative OUT * Seq On m LED BO 70 14 9 2 Yes 5171 46 Disk emulation picked 46 Negative OUT * up (46 Dsk pickedup) Seq * * LED BO 5203 >BLOCK 81O/U (>BLOCK 81O/U) 81 O/U Freq. SP On * Of f * LED BI BO 70 17 6 1 Yes 5206 >BLOCK 81-1 (>BLOCK 81-1) 81 O/U Freq. SP On * Of f * LED BI BO 70 17 7 1 Yes 5207 >BLOCK 81-2 (>BLOCK 81-2) 81 O/U Freq. SP On * Of f * LED BI BO 70 17 8 1 Yes 5208 >BLOCK 81-3 (>BLOCK 81-3) 81 O/U Freq. SP On * Of f * LED BI BO 70 17 9 1 Yes 5209 >BLOCK 81-4 (>BLOCK 81-4) 81 O/U Freq. SP On * Of f * LED BI BO 70 18 0 1 Yes 5211 81 OFF (81 OFF) 81 O/U Freq. OUT On * Of f * LED BO 70 18 1 1 Yes 5212 81 BLOCKED (81 BLOCKED) 81 O/U Freq. OUT On On Of Off f * LED BO 70 18 2 1 Yes 5213 81 ACTIVE (81 ACTIVE) 81 O/U Freq. OUT On * Of f * LED BO 70 18 3 1 Yes 5214 81 Under Voltage Block (81 Under V Blk) 81 O/U Freq. OUT On On Of Off f * LED BO 70 18 4 1 Yes 5232 81-1 picked up (81-1 picked up) 81 O/U Freq. OUT * On Off * LED BO 70 23 0 2 Yes 5233 81-2 picked up (81-2 picked up) 81 O/U Freq. OUT * On Off * LED BO 70 23 1 2 Yes 5234 81-3 picked up (81-3 picked up) 81 O/U Freq. OUT * On Off * LED BO 70 23 2 2 Yes Chatter Suppression 46 Negative OUT * Seq Relay 46-2 picked up (46-2 picked up) Function Key 5159 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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 F.3 Information List 529 Type information number Data Unit General Interrogation OUT * On Off * LED BO 70 23 3 2 Yes 5236 81-1 TRIP (81-1 TRIP) 81 O/U Freq. OUT * On m LED BO 70 23 4 2 Yes 5237 81-2 TRIP (81-2 TRIP) 81 O/U Freq. OUT * On m LED BO 70 23 5 2 Yes 5238 81-3 TRIP (81-3 TRIP) 81 O/U Freq. OUT * On m LED BO 70 23 6 2 Yes 5239 81-4 TRIP (81-4 TRIP) 81 O/U Freq. OUT * On m LED BO 70 23 7 2 Yes 5951 >BLOCK 50 1Ph (>BLK 50 50 1Ph 1Ph) SP * * * LED BI BO 5952 >BLOCK 50 1Ph-1 (>BLK 50 1Ph-1) 50 1Ph SP * * * LED BI BO 5953 >BLOCK 50 1Ph-2 (>BLK 50 1Ph-2) 50 1Ph SP * * * LED BI BO 5961 50 1Ph is OFF (50 1Ph OFF) 50 1Ph OUT On * Of f * LED BO 5962 50 1Ph is BLOCKED (50 1Ph BLOCKED) 50 1Ph OUT On On Of Off f * LED BO 5963 50 1Ph is ACTIVE (50 1Ph 50 1Ph ACTIVE) OUT On * Of f * LED BO 5966 50 1Ph-1 is BLOCKED (50 50 1Ph 1Ph-1 BLK) OUT On On Of Off f * LED BO 5967 50 1Ph-2 is BLOCKED (50 50 1Ph 1Ph-2 BLK) OUT On On Of Off f * LED BO 5971 50 1Ph picked up (50 1Ph 50 1Ph Pickup) OUT * On Off * LED BO 5972 50 1Ph TRIP (50 1Ph TRIP) 50 1Ph OUT * On * LED BO 5974 50 1Ph-1 picked up (50 1Ph-1 PU) 50 1Ph OUT * On Off * LED BO 5975 50 1Ph-1 TRIP (50 1Ph-1 TRIP) 50 1Ph OUT * On * LED BO 5977 50 1Ph-2 picked up (50 1Ph-2 PU) 50 1Ph OUT * On Off * LED BO 5979 50 1Ph-2 TRIP (50 1Ph-2 TRIP) 50 1Ph OUT * On * LED BO Chatter Suppression 81 O/U Freq. Relay 81-4 picked up (81-4 picked up) Function Key LED 5235 530 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Trip (Fault) Log ON/OFF Marked in Oscill. Record LED Binary Input Configurable in Matrix IEC 60870-5-103 5980 50 1Ph: I at pick up (50 1Ph I:) 50 1Ph VI * On Off 6401 >QV-Protection Blocked (>27/Q Block) 27/Q SP * * * LED BI 6411 27/Q -Protection off (27/Q 27/Q OFF) OUT On * Of f * 6412 27/Q -Protection blocked (27/Q block) 27/Q OUT On On Of Off f 6413 27/Q -Protection active (27/Q ACT) 27/Q 6421 1 Yes LED BO 74 21 1 1 Yes * LED BO 74 21 2 1 Yes OUT On * Of f * LED BO 74 21 3 1 Yes 27/Q -Protection Gen TRIP 27/Q (27/Q Gen TRIP) OUT * On Off * LED BO 74 22 1 2 Yes 6422 27/Q -Protection Grid TRIP 27/Q (27/Q Grid TRIP) OUT * On Off * LED BO 74 22 2 2 Yes 6423 27/Q-Protection PICKUP (27/Q PICKUP) 27/Q OUT * On Off * LED BO 74 22 3 2 No 6424 Reclosure release (Reclosure rel.) 27/Q OUT * On Off * LED BO 74 22 4 2 Yes 6425 27/Q pickup blocked by Inrush (27/Q blk.b.Inr.) 27/Q OUT On On Of Off f * LED BO 74 22 5 2 Yes 6503 >BLOCK 27 undervoltage 27/59 O/U protection (>BLOCK 27) Volt. SP * * * LED BI BO 74 3 1 Yes 6505 >27-Switch current super- 27/59 O/U vision ON (>27 I Volt. SUPRVSN) SP On * Of f * LED BI BO 74 5 1 Yes 6506 >BLOCK 27-1 Undervoltage protection (>BLOCK 27-1) 27/59 O/U Volt. SP On * Of f * LED BI BO 74 6 1 Yes 6508 >BLOCK 27-2 Undervoltage protection (>BLOCK 27-2) 27/59 O/U Volt. SP On * Of f * LED BI BO 74 8 1 Yes 6509 >Failure: Feeder VT (>FAIL:FEEDER VT) MeasSP urem.Super v On * Of f * LED BI BO 74 9 1 Yes 6510 >Failure: Busbar VT (>FAIL: BUS VT) MeasSP urem.Super v On * Of f * LED BI BO 74 10 1 Yes 6513 >BLOCK 59 overvoltage protection (>BLOCK 59) 27/59 O/U Volt. * * LED BI BO 74 13 1 Yes SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 SP * Chatter Suppression 20 1 Relay 74 Function Key BO 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 F.3 Information List 531 Type information number Data Unit General Interrogation OUT On * Of f * LED BO 74 30 1 Yes 6531 27 Undervoltage protection is BLOCKED (27 BLOCKED) 27/59 O/U Volt. OUT On On Of Off f * LED BO 74 31 1 Yes 6532 27 Undervoltage protection is ACTIVE (27 ACTIVE) 27/59 O/U Volt. OUT On * Of f * LED BO 74 32 1 Yes 6533 27-1 Undervoltage picked 27/59 O/U up (27-1 picked up) Volt. OUT * On Off * LED BO 74 33 2 Yes 6534 27-1 Undervoltage PICKUP w/curr. superv (27-1 PU CS) 27/59 O/U Volt. OUT * On Off * LED BO 74 34 2 Yes 6537 27-2 Undervoltage picked 27/59 O/U up (27-2 picked up) Volt. OUT * On Off * LED BO 74 37 2 Yes 6538 27-2 Undervoltage PICKUP w/curr. superv (27-2 PU CS) 27/59 O/U Volt. OUT * On Off * LED BO 74 38 2 Yes 6539 27-1 Undervoltage TRIP (27-1 TRIP) 27/59 O/U Volt. OUT * On m LED BO 74 39 2 Yes 6540 27-2 Undervoltage TRIP (27-2 TRIP) 27/59 O/U Volt. OUT * On * LED BO 74 40 2 Yes 6565 59-Overvoltage protection switched OFF (59 OFF) 27/59 O/U Volt. OUT On * Of f * LED BO 74 65 1 Yes 6566 59-Overvoltage protection is BLOCKED (59 BLOCKED) 27/59 O/U Volt. OUT On On Of Off f * LED BO 74 66 1 Yes 6567 59-Overvoltage protection is ACTIVE (59 ACTIVE) 27/59 O/U Volt. OUT On * Of f * LED BO 74 67 1 Yes 6568 59-1 Overvoltage V> picked up (59-1 picked up) 27/59 O/U Volt. OUT * On Off * LED BO 74 68 2 Yes 6570 59-1 Overvoltage V> TRIP 27/59 O/U (59-1 TRIP) Volt. OUT * On m LED BO 74 70 2 Yes 6571 59-2 Overvoltage V>> picked up (59-2 picked up) 27/59 O/U Volt. OUT * On Off * LED BO 6573 59-2 Overvoltage V>> TRIP (59-2 TRIP) 27/59 O/U Volt. OUT * On * LED BO 6851 >BLOCK 74TC (>BLOCK 74TC) 74TC TripCirc. SP * * LED 532 BI Chatter Suppression 27/59 O/U Volt. Relay 27 Undervoltage protection switched OFF (27 OFF) Function Key LED 6530 * 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 F.3 Information List BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation SP On * Of f * LED BI BO 17 0 51 1 Yes 6853 >74TC Trip circuit superv.: 74TC Tripbkr relay (>74TC brk rel.) Circ. SP On * Of f * LED BI BO 17 0 52 1 Yes 6861 74TC Trip circuit supervision OFF (74TC OFF) 74TC TripCirc. OUT On * Of f * LED BO 17 0 53 1 Yes 6862 74TC Trip circuit supervision is BLOCKED (74TC BLOCKED) 74TC TripCirc. OUT On On Of Off f * LED BO 15 3 16 1 Yes 6863 74TC Trip circuit supervision is ACTIVE (74TC ACTIVE) 74TC TripCirc. OUT On * Of f * LED BO 15 3 17 1 Yes 6864 74TC blocked. Bin. input is not set (74TC ProgFail) 74TC TripCirc. OUT On * Of f * LED BO 17 0 54 1 Yes 6865 74TC Failure Trip Circuit (74TC Trip cir.) 74TC TripCirc. OUT On * Of f * LED BO 17 0 55 1 Yes 6903 >block interm. E/F prot. (>IEF block) Intermit. EF SP * * LED BO 15 2 1 1 Yes 6921 Interm. E/F prot. is switched off (IEF OFF) Intermit. EF OUT On * Of f * LED BO 15 2 10 1 Yes 6922 Interm. E/F prot. is blocked (IEF blocked) Intermit. EF OUT On On Of Off f * LED BO 15 2 11 1 Yes 6923 Interm. E/F prot. is active (IEF enabled) Intermit. EF OUT On * Of f * LED BO 15 2 12 1 Yes 6924 Interm. E/F detection stage Iie> (IIE Fault det) Intermit. EF OUT * * * LED BO 6925 Interm. E/F stab detection Intermit. EF OUT * (IIE stab.Flt) * * LED BO 6926 Interm.E/F det.stage Iie> f.Flt. ev.Prot (IIE Flt.det FE) Intermit. EF OUT * On * 15 2 13 2 No 6927 Interm. E/F detected (Intermitt.EF) Intermit. EF OUT * On Off * LED BO 15 2 14 2 Yes 6928 Counter of det. times elapsed (IEF Tsum exp.) Intermit. EF OUT * On * LED BO 15 2 15 2 No SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 BI Chatter Suppression >74TC Trip circuit superv.: 74TC Triptrip relay (>74TC trip rel.) Circ. Relay Binary Input 6852 * 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 F.3 Information List 533 Type information number Data Unit General Interrogation Intermit. EF OUT * On Off * LED BO 15 2 16 2 Yes 6930 Interm. E/F: trip (IEF Trip) Intermit. EF OUT * On * LED BO 15 2 17 2 No 6931 Max RMS current value of Intermit. EF VI fault = (Iie/In=) ON OFF * 15 2 18 4 No 6932 No. of detections by stage Intermit. EF VI Iie>= (Nos.IIE=) ON OFF * 15 2 19 4 No 6951 >Block directional interm. Dir. Interm. SP E/F prot. (>dIEF block) EF 6961 On * Of f * * LED Dir. Interm. E/F prot. is switched off (dIEF OFF) Dir. Interm. OUT On * EF Of f * * LED 6962 Dir. Interm. E/F prot. is blocked (dIEF blocked) Dir. Interm. OUT On * EF Of f * * LED BI BO 6963 Dir. Interm. E/F prot. is active (dIEF active) Dir. Interm. OUT On * EF Of f * * LED BI BO 6972 dIEF: pick up (dIEF pick up) Dir. Interm. OUT * EF On Off On * Off LED BO 6973 dIEF: Trip (dIEF TRIP) Dir. Interm. OUT * EF On On * Off LED BO 6974 dIEF: No. of detected forward pulses = (No.forward=) Dir. Interm. VI EF * On Off On Off 6975 dIEF: No. of detected reverse pulses = (No.reverse=) Dir. Interm. VI EF * On Off On Off 6976 dIEF: No. of detected undefined pulses = (No.undef.=) Dir. Interm. VI EF * On Off On Off 6979 dIEF: Alarm (dIEF ALARM) Dir. Interm. OUT * EF On Off On * Off LED BO 7551 50-1 InRush picked up (50-1 InRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 80 2 Yes 7552 50N-1 InRush picked up (50N-1 InRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 81 2 Yes 7553 51 InRush picked up (51 InRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 82 2 Yes 7554 51N InRush picked up (51N InRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 83 2 Yes 534 BI Chatter Suppression Interm. E/F: reset time running (IEF Tres run.) Relay 6929 Function Key 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 F.3 Information List BO BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Type information number Data Unit General Interrogation OUT On * Of f * LED BO 60 92 1 Yes 7557 InRush BLOCKED (InRush BLK) 50/51 Overcur. OUT On On Of Off f * LED BO 60 93 1 Yes 7558 InRush Ground detected (InRush Gnd Det) 50/51 Overcur. OUT * On Off * LED BO 60 94 2 Yes 7559 67-1 InRush picked up (67-1 InRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 84 2 Yes 7560 67N-1 InRush picked up (67N-1 InRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 85 2 Yes 7561 67-TOC InRush picked up 50/51 (67-TOC InRushPU) Overcur. OUT * On Off * LED BO 60 86 2 Yes 7562 67N-TOC InRush picked up (67N-TOCInRushPU) 50/51 Overcur. OUT * On Off * LED BO 60 87 2 Yes 7563 >BLOCK InRush (>BLOCK InRush) 50/51 Overcur. SP * * LED 7564 Ground InRush picked up 50/51 (Gnd InRush PU) Overcur. OUT * On Off * LED BO 60 88 2 Yes 7565 Phase A InRush picked up 50/51 (Ia InRush PU) Overcur. OUT * On Off * LED BO 60 89 2 Yes 7566 Phase B InRush picked up 50/51 (Ib InRush PU) Overcur. OUT * On Off * LED BO 60 90 2 Yes 7567 Phase C InRush picked up 50/51 (Ic InRush PU) Overcur. OUT * On Off * LED BO 60 91 2 Yes 10034 50-3 BLOCKED (50-3 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 16 9 1 Yes 10035 50N-3 BLOCKED (50N-3 BLOCKED) 50/51 Overcur. OUT On On Of Off f * LED BO 60 17 0 1 Yes 10080 Error Extension I/O (Error Ext I/O) Device, General OUT On * Of f * LED BO 10081 Error Ethernet (Error Ethernet) Device, General OUT On * Of f * LED BO 10082 Error Current Terminal (Error Terminal) Device, General OUT On * Of f * LED BO 10083 Error Basic I/O (Error Basic Device, I/O) General OUT On * Of f * LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 BI Chatter Suppression 50/51 Overcur. Relay InRush OFF (InRush OFF) Function Key LED 7556 * 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 F.3 Information List BO 535 Functions, Settings, Information F.3 Information List 16002 Sum Current Exponentia- Statistics tion Ph B to Ir^x (I^x B=) VI 16003 Sum Current Exponentia- Statistics tion Ph C to Ir^x (I^x C=) VI 16005 Threshold Sum Curr. Exponent. exceeded (Threshold I^x>) 16006 Residual Endurance Phase Statistics A (Resid.Endu. A=) VI 16007 Residual Endurance Phase Statistics B (Resid.Endu. B=) VI 16008 Residual Endurance Phase Statistics C (Resid.Endu. C=) VI 16010 Dropped below Threshold SetPoint(Sta OUT On * CB Res.Endurance t) Of (Thresh.R.Endu.<) f 16011 Number of mechanical Trips Phase A (mechan.TRIP A=) Statistics VI 16012 Number of mechanical Trips Phase B (mechan.TRIP B=) Statistics VI 16013 Number of mechanical Trips Phase C (mechan.TRIP C=) Statistics VI 16014 Sum Squared Current Integral Phase A (I^2t A=) Statistics VI 16015 Sum Squared Current Integral Phase B (I^2t B=) Statistics VI 16016 Sum Squared Current Integral Phase C (I^2t C=) Statistics VI 16018 Threshold Sum Squa. Curr. Int. exceeded (Thresh. I^2t>) 16019 >52 Breaker Wear Start Criteria (>52 Wear start) SetPoint(Sta OUT On * t) Of f * LED BO P.System Data 2 * LED 536 SP On * Of f BI Relay BO Function Key LED Binary Input * Ground Fault Log ON/OFF BO Trip (Fault) Log ON/OFF LED Event Log ON/OFF * SetPoint(Sta OUT On * t) Of f General Interrogation VI Data Unit Sum Current Exponentia- Statistics tion Ph A to Ir^x (I^x A=) information number 16001 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. BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 52 Breaker Wear Logic blk P.System Ir-CB>=Isc-CB (52WL.blk I Data 2 PErr) OUT On * Of f * LED BO 16028 52 Breaker W.Log.blk SwCyc.Isc>=SwCyc.Ir (52WL.blk n PErr) P.System Data 2 OUT On * Of f * LED BO 16029 Sens.gnd.flt. 51Ns BLOCKED Setting Error (51Ns BLK PaErr) Sens. Gnd Fault OUT On * Of f * LED BO 16030 Angle between 3Vo and INsens. ((3Vo,INs) =) Sens. Gnd Fault VI 18901 >BLOCK Earth fault E Flt(ext) (extend) (>BLK E Flt(ext)) SP On * Of f * LED BI BO 18902 >BLOCK EPTR (>BLOCK EPTR) E Flt(ext) SP On * Of f * LED BI BO 18903 >BLOCK Transformer Neutral (TNP) (>BLOCK TNP) E Flt(ext) SP On * Of f * LED BI BO 18904 Earth fault (extend) is OFF (E Flt(ext) OFF) E Flt(ext) OUT On * Of f * LED BI BO 18905 Earth fault (extend) is ACTIVE (E Flt(ext) ACT) E Flt(ext) OUT On * Of f * LED BI BO 18906 EPTR is OFF (EPTR OFF) E Flt(ext) OUT On * Of f * LED BO 18907 EPTR is ACTIVE (EPTR ACT) E Flt(ext) OUT On * Of f * LED BO 18908 Transformer Neutral(TNP) E Flt(ext) is OFF (TNP OFF) OUT On * Of f * LED BO 18909 Transformer Neutral(TNP) E Flt(ext) is ACTIVE (TNP ACT) OUT On * Of f * LED BO 18910 EPTR picked up (EPTR picked up) OUT * * LED BO SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 General Interrogation 16027 Data Unit BO information number LED Type * Chatter Suppression OUT On * Of f Relay 52 Wear blocked by Time P.System Setting Failure (52 Data 2 WearSet.fail) Function Key 16020 E Flt(ext) 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 F.3 Information List ON OF F On Off 537 BO LED BO 18913 Transformer Neutral (TNP) TRIP (TNP TRIP) E Flt(ext) OUT * On m LED BO 18914 Earth fault (extend) picked up (E Flt(ext) PU) E Flt(ext) OUT * On Off m LED BO 18915 Earth fault (extend) TRIP (E Flt(ext) Trip) E Flt(ext) OUT * On m LED BO 18916 Earth fault (extend) is BLOCKED (E Flt(ext) BLK) E Flt(ext) OUT On On Of Off f * LED BO 18917 EPTR is BLOCKED (EPTR BLOCKED) E Flt(ext) OUT On On Of Off f * * LED BO 18918 Transformer Neutral(TNP) E Flt(ext) is BLOCKED (TNP BLOCKED) OUT On On Of Off f * * LED BO 18919 Earth fault (extend) BLOCK Setting Error (EF BLK PaErr) OUT On * 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 * 31008 Q8 operationcounter= (Q8 OpCnt=) Control Device VI * 538 * General Interrogation LED * Data Unit m On Off information number On OUT * Type OUT * E Flt(ext) Chatter Suppression E Flt(ext) Transformer Neutral (TNP) picked up (TNP picked up) Relay EPTR TRIP (EPTR TRIP) 18912 Function Key LED 18911 E Flt(ext) 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 F.3 Information List SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.4 Group Alarms F.4 Group Alarms No. Description Function No. Description 140 Error Sum Alarm 177 178 10080 10081 10082 10083 191 193 Fail Battery I/O-Board error Error Ext I/O Error Ethernet Error Terminal Error Basic I/O Error Offset Alarm NO calibr 160 Alarm Sum Event 162 163 167 175 176 I Failure I Fail I balance Fail V balance Fail Ph. Seq. I Fail Ph. Seq. V 161 Fail I Superv. 162 163 I Failure I Fail I balance 171 Fail Ph. Seq. 175 176 Fail Ph. Seq. I Fail Ph. Seq. V 501 Relay PICKUP 1517 5159 5165 5166 5971 5974 5977 1761 2691 1224 1221 1215 6423 49 Winding O/L 46-2 picked up 46-1 picked up 46-TOC pickedup 50 1Ph Pickup 50 1Ph-1 PU 50 1Ph-2 PU 50(N)/51(N) PU 67/67N pickedup 50Ns-1 Pickup 50Ns-2 Pickup 64 Pickup 27/Q PICKUP SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 539 Functions, Settings, Information F.4 Group Alarms No. Description Function No. Description 511 Relay TRIP 235.2126 1217 1223 1226 1229 5236 5237 5238 5239 6930 6973 5170 6539 6540 6570 6573 1471 1494 5972 1521 1791 2696 $00 TRIP 64 TRIP 50Ns-2 TRIP 50Ns-1 TRIP 51Ns TRIP 81-1 TRIP 81-2 TRIP 81-3 TRIP 81-4 TRIP IEF Trip dIEF TRIP 46 TRIP 27-1 TRIP 27-2 TRIP 59-1 TRIP 59-2 TRIP 50BF TRIP 50BF TRIP 2 50 1Ph TRIP 49 Th O/L TRIP 50(N)/51(N)TRIP 67/67N TRIP 540 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.5 Measured Values Function Compatibility Data Unit Position CFC IEC 60870-5-103 Configurable in Matrix - Number of TRIPs= (#of TRIPs=) Statistics - - - - - CFC - Operating hours greater than (OpHour>) SetPoint(Stat) - - - - - CFC 170.20 V1 = (V1 =) 50 SYNC function 130 1 1 No 9 1 CFC 170.20 f1 = (f1 =) 51 SYNC function 130 1 1 No 9 4 CFC 170.20 V2 = (V2 =) 52 SYNC function 130 1 1 No 9 3 CFC 170.20 f2 = (f2 =) 53 SYNC function 130 1 1 No 9 7 CFC 170.20 dV = (dV =) 54 SYNC function 130 1 1 No 9 2 CFC 170.20 df = (df =) 55 SYNC function 130 1 1 No 9 5 CFC 170.20 dalpha = (d =) 56 SYNC function 130 1 1 No 9 6 CFC 601 Ia (Ia =) Measurement 134 157 No 9 1 CFC 602 Ib (Ib =) Measurement 160 145 Yes 3 1 CFC 134 157 No 9 2 603 Ic (Ic =) Measurement 134 157 No 9 3 604 In (In =) Measurement 134 157 No 9 4 CFC 605 I1 (positive sequence) (I1 =) Measurement - - - - - CFC 606 I2 (negative sequence) (I2 =) Measurement - - - - - CFC 621 Va (Va =) Measurement 134 157 No 9 6 CFC 622 Vb (Vb =) Measurement 134 157 No 9 7 CFC 623 Vc (Vc =) Measurement 134 157 No 9 8 CFC 624 Va-b (Va-b=) Measurement 160 145 Yes 3 2 CFC 134 157 No 9 9 625 Vb-c (Vb-c=) Measurement 134 157 No 9 10 CFC 626 Vc-a (Vc-a=) Measurement 134 157 No 9 11 CFC 627 VN (VN =) Measurement 134 118 No 9 1 CFC 629 V1 (positive sequence) (V1 =) Measurement - - - - - CFC 630 V2 (negative sequence) (V2 =) Measurement - - - - - CFC 632 Vsync (synchronism) (Vsync =) Measurement - - - - - CFC 641 P (active power) (P =) Measurement 134 157 No 9 12 CFC 642 Q (reactive power) (Q =) Measurement 134 157 No 9 13 CFC 644 Frequency (Freq=) Measurement 134 157 No 9 5 CFC 645 S (apparent power) (S =) Measurement - - - - - CFC SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Default Display Description Control Display No. information number Measured Values Type F.5 CFC 541 Function information number Compatibility Data Unit Position CFC 680 Angle Va-Ia (Phi A =) Measurement - - - - - CFC 681 Angle Vb-Ib (Phi B =) Measurement - - - - - CFC 682 Angle Vc-Ic (Phi C =) Measurement - - - - - CFC 701 Resistive ground current in isol systems (INs Real) Measurement 134 157 No 9 15 CFC 702 Reactive ground current in isol systems (INs Reac) Measurement 134 157 No 9 16 CFC 807 Thermal Overload (/trip =) Measurement - - - - - CFC 830 INs Senstive Ground Fault Current Measurement (INs =) 134 158 No 9 1 CFC 831 3Io (zero sequence) (3Io =) Measurement - - - - - CFC 832 Vo (zero sequence) (Vo =) Measurement 134 118 No 9 2 CFC 833 I1 (positive sequence) Demand (I1 Demand meter dmd=) - - - - - 834 Active Power Demand (P dmd =) Demand meter - - - - - - 835 Reactive Power Demand (Q dmd =) Demand meter - - - - - - 836 Apparent Power Demand (S dmd =) Demand meter - - - - - - 837 I A Demand Minimum (IAdmdMin) Min/Max meter - - - - - - 838 I A Demand Maximum (IAdmdMax) Min/Max meter - - - - - - 839 I B Demand Minimum (IBdmdMin) Min/Max meter - - - - - - 840 I B Demand Maximum (IBdmdMax) Min/Max meter - - - - - - 841 I C Demand Minimum (ICdmdMin) Min/Max meter - - - - - - 842 I C Demand Maximum (ICdmdMax) Min/Max meter - - - - - - 843 I1 (positive sequence) Demand Minimum (I1dmdMin) Min/Max meter - - - - - - 844 I1 (positive sequence) Demand Maximum (I1dmdMax) Min/Max meter - - - - - - 845 Active Power Demand Minimum (PdMin=) Min/Max meter - - - - - - 846 Active Power Demand Maximum (PdMax=) Min/Max meter - - - - - - 847 Reactive Power Minimum (QdMin=) Min/Max meter - - - - - - 848 Reactive Power Maximum (QdMax=) Min/Max meter - - - - - - 849 Apparent Power Minimum (SdMin=) Min/Max meter - - - - - - 542 IEC 60870-5-103 Configurable in Matrix Default Display Description Control Display No. Type Functions, Settings, Information F.5 Measured Values SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Compatibility Data Unit Position CFC IEC 60870-5-103 850 Apparent Power Maximum (SdMax=) Min/Max meter - - - - - - 851 Ia Min (Ia Min=) Min/Max meter - - - - - - 852 Ia Max (Ia Max=) Min/Max meter - - - - - - 853 Ib Min (Ib Min=) Min/Max meter - - - - - - 854 Ib Max (Ib Max=) Min/Max meter - - - - - - 855 Ic Min (Ic Min=) Min/Max meter - - - - - - 856 Ic Max (Ic Max=) Min/Max meter - - - - - - 857 I1 (positive sequence) Minimum (I1 Min=) Min/Max meter - - - - - - 858 I1 (positive sequence) Maximum (I1 Max=) Min/Max meter - - - - - - 859 Va-n Min (Va-nMin=) Min/Max meter - - - - - - 860 Va-n Max (Va-nMax=) Min/Max meter - - - - - - 861 Vb-n Min (Vb-nMin=) Min/Max meter - - - - - - 862 Vb-n Max (Vb-nMax=) Min/Max meter - - - - - - 863 Vc-n Min (Vc-nMin=) Min/Max meter - - - - - - 864 Vc-n Max (Vc-nMax=) Min/Max meter - - - - - - 865 Va-b Min (Va-bMin=) Min/Max meter - - - - - - 867 Va-b Max (Va-bMax=) Min/Max meter - - - - - - 868 Vb-c Min (Vb-cMin=) Min/Max meter - - - - - - 869 Vb-c Max (Vb-cMax=) Min/Max meter - - - - - - 870 Vc-a Min (Vc-aMin=) Min/Max meter - - - - - - 871 Vc-a Max (Vc-aMax=) Min/Max meter - - - - - - 872 V neutral Min (Vn Min =) Min/Max meter - - - - - - 873 V neutral Max (Vn Max =) Min/Max meter - - - - - - 874 V1 (positive sequence) Voltage Minimum (V1 Min =) Min/Max meter - - - - - - 875 V1 (positive sequence) Voltage Maximum (V1 Max =) Min/Max meter - - - - - - 876 Active Power Minimum (Pmin=) Min/Max meter - - - - - - 877 Active Power Maximum (Pmax=) Min/Max meter - - - - - - 878 Reactive Power Minimum (Qmin=) Min/Max meter - - - - - - 879 Reactive Power Maximum (Qmax=) Min/Max meter - - - - - - 880 Apparent Power Minimum (Smin=) Min/Max meter - - - - - - 881 Apparent Power Maximum (Smax=) Min/Max meter - - - - - - 882 Frequency Minimum (fmin=) Min/Max meter - - - - - - 883 Frequency Maximum (fmax=) Min/Max meter - - - - - - SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Configurable in Matrix Default Display Function Control Display Description Type No. information number Functions, Settings, Information F.5 Measured Values 543 Data Unit Position CFC IEC 60870-5-103 884 Power Factor Maximum (PF Max=) Min/Max meter - - - - - - 885 Power Factor Minimum (PF Min=) Min/Max meter - - - - - - 888 Pulsed Energy Wp (active) (Wp(puls)) Energy 133 55 No 205 - CFC 889 Pulsed Energy Wq (reactive) (Wq(puls)) Energy 133 56 No 205 - CFC 901 Power Factor (PF =) Measurement 134 157 No 9 14 CFC 924 Wp Forward (WpForward) Energy 133 51 No 205 - CFC 925 Wq Forward (WqForward) Energy 133 52 No 205 - CFC 928 Wp Reverse (WpReverse) Energy 133 53 No 205 - CFC 929 Wq Reverse (WqReverse) Energy 133 54 No 205 - CFC 963 I A demand (Ia dmd=) Demand meter - - - - - CFC 964 I B demand (Ib dmd=) Demand meter - - - - - CFC 965 I C demand (Ic dmd=) Demand meter - - - - - CFC 1058 Overload Meter Max (/ TrpMax=) Min/Max meter - - - - - CFC 1059 Overload Meter Min (/TrpMin=) Min/Max meter - - - - - CFC 16004 Threshold Sum Current Exponentiation (I^x>) SetPoint(Stat) - - - - - CFC 16009 Lower Threshold of CB Residual Endurance (Resid.Endu. <) SetPoint(Stat) - - - - - CFC 16017 Threshold Sum Squared Current Integral (I^2t>) SetPoint(Stat) - - - - - CFC 16031 Angle between 3Vo and INsens. ((3Vo,INs) =) Measurement - - - - - CFC 18473 Va-b RMS(10 minute RMS value) (Va-b RMS=) Measurement - - - - - CFC 18474 Vb-c RMS(10 minute RMS value) (Vb-c RMS=) Measurement - - - - - CFC 18475 Vc-a RMS(10 minute RMS value) (Vc-a RMS=) Measurement - - - - - CFC 30701 Pa (active power, phase A) (Pa =) Measurement - - - - - CFC 30702 Pb (active power, phase B) (Pb =) Measurement - - - - - CFC 30703 Pc (active power, phase C) (Pc =) Measurement - - - - - CFC 30704 Qa (reactive power, phase A) (Qa =) Measurement - - - - - CFC 30705 Qb (reactive power, phase B) (Qb =) Measurement - - - - - CFC 30706 Qc (reactive power, phase C) (Qc =) Measurement - - - - - CFC 30707 Power Factor, phase A (PFa =) Measurement - - - - - CFC 30708 Power Factor, phase B (PFb =) Measurement - - - - - CFC 544 Configurable in Matrix Default Display Compatibility Function Control Display Description Type No. information number Functions, Settings, Information F.5 Measured Values SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Functions, Settings, Information F.5 Measured Values Voltage VX (VX =) Measurement - - - - - CFC 30801 Voltage phase-neutral (Vph-n =) Measurement - - - - - CFC - - - - CFC Default Display 30800 - Control Display Measurement CFC Power Factor, phase C (PFc =) Position Configurable in Matrix Data Unit 30709 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 IEC 60870-5-103 Compatibility Function information number Description Type No. 545 546 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Literature /1/ SIPROTEC 4 System Description E50417-H1176-C151-B6 /2/ SIPROTEC DIGSI, Start UP E50417-G1176-C152-A3 /3/ DIGSI CFC, Manual E50417-H1176-C098-B2 /4/ SIPROTEC SIGRA 4, Manual E50417-H1176-C070-A7 /5/ Additional description for the protection of explosion-protected motors of protection type increased safety "e" C53000-B1174-C170 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 547 548 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 549 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 550 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 551 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. 552 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 553 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 554 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 555 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. 556 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 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, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 557 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. 558 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Index 1,2,3 ... 406 67, 67N -Blocking via FFM 89 A Action Time 212 Alternating Voltage 355 Analog Inputs 354 ATEX100 148 Automatic Reclosing 209, 403 Auxiliary voltage 354 B Binary Inputs 355 Binary Outputs 355 Block diagram 434 Blocking Time 213 Breaker Failure Protection 235 Breaker Failure Protection 50BF 405 Broken Wire Monitoring 162 Buffer Battery 154 Busbar protection 115, 120 Circuit Breaker Monitoring 215 Circuit Breaker Status Detection 215 Climatic Stress Tests 360 Clock 419 Commissioning Aids 419 Communication Interfaces 356 Constructive Design 361 Controlling Protection Elements 216 Cross Blocking 68 CTs knee-point voltage 113 Current Criterion 123 Current Inputs 354 Current sum monitoring. 154 Current Symmetry Monitoring 157 Current transformers 118 D Dead Time Start Delay 212 Definite-time Overcurrent Protection 363 Determination of Direction 90 Direct Voltage 354 Direction Check with Load Current 344 Directional intermittent ground fault protection 204, 402 Directional Overcurrent Protection 82, 88, 376 Dynamic Blocking 214 Dynamic Cold Load Pickup 106, 379 C Change Setting Group 312 Changing Setting Groups 49 Checking the System Connections 330 Checking: Breaker Failure Protection 340 Checking: Direction 344 Checking: Phase Rotation 342 Checking: Polarity at Current Input I 347 Checking: Status of Binary Inputs and Outputs 338 Checking: Switching the Configured Operating Devices 350 Checking: User-Defined Functions 342 Checking: Voltage Transformer Miniature Circuit Breaker (VT mcb) 343 Circuit Breaker Maintenance 419 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 E Earth fault 120 Electrical Tests 358 EMC Tests for Immunity (Type Tests) 359 EMC Tests for Noise Emission (Type Test) 359 EN100-Module Interface Selection 55 Energy Counter 418 F Fault Location Determination 232 559 Index Fault Locator 232, 404 double ground faults 232 Fault Logging 418 Fault Messages Seting notes 34 Fault Recording 418 Fault Records 47 Fiber-optic Cables 330 Final Preparation of the Device 352 Frequency protection 138 Frequency Protection 81 O/U 390 Function Blocks 411 G General Device Pickup 275 General Tripping 275 Ground fault 114, 114 measurements cos 175 Ground Fault Check 347 Ground fault detection Direction determination for cos-/ sin- 189 Logic with cos-/ sin- 175 Ground Fault Detection Current Elements with cos-/ sin- 173 Current Elements with U0/I0- 179 Determination of Direction with cos-/ sin- 173 Logic with U0/I0 180 Trip delay with U0/I0 190 Tripping Area with U0/I0- 179 voltage element with cos-/ sin- 172 Voltage Element with U0/I0- 178 Ground Fault Detection (Sensitive/Insensitive) 395 H Hardware Monitoring 154 High-impedance Protection 116 Srensitivity 118 Stability 117 Hours Meter "CB open" 279 Humidity 361 I Inrush Restraint 68, 90, 378 Insulation Test 358 Interlocked 302 Intermittent Ground Fault Protection 198, 401 Inverse Time Overcurrent 62 Inverse-time Overcurrent Protection 365 560 L Limits CFC blocks 412 Limits User-defined Functions 412 Line sections 232, 233 Local Measured Value Monitoring 418 Long-Term Mean Values 417 M Malfunction Responses 170 Mechanical Tests 360 Mesurement Monitoring 154 Min./Max. Memory 417 Monitoring of the Circuit Breaker Auxiliary Contacts 237 Monitoring of the Current Flow 236 N Negative Sequence Protection 132 Negative Sequence Protection (definite-time characteristic) 383 Negative Sequence Protection (inverse-time characteristics) 384 Non-Interlocked Switching 302 O Offset Monitoring 156 Operating Hours Counter 419 Operational Measured Values 416 Ordering Information 426 Output Relays Binary Outputs 355 Overcurrent Protection 56 1-phase 380 pickup value 116, 120 Rated data of a CT 116 time delay 120 trip time delay 116 Overcurrent Protection 1-phase Current Elements 380 Overcurrent Protection Ground Current Frequency 380 Overcurrent Protection Single-phase Frequency 380 Overfrequency 138 Overload Protection 147 Overvoltage Protection 59 123 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 Index P Phase Rotation 274 Phase Sequence Monitoring 158 Pickup Logic 275 Polarity Check for Current Input I 347 Port A 356 Port B 356 Triggering Oscillographic Recording 351 Trip Circuit Supervision 166, 419 Trip tests with circuit breaker 350 Trip/Close Tests for the Configured Operating Devices 350 Tripping Logic 275 Two-phase Overcurrent Protection 70 U R Reclosing Programs 212 Regulations 358 Reverse Interlocking 71 Rush stabilisation 90 S Saved Number of Trips 419 Schalthoheit 305 Schaltmodus 306 Selection of Default Display Start page 34 Sensitive Ground Fault Protection 172 Service Conditions 361 Setting Group Change 312 Setting Group Change Option of the Functional Settings 420 Setting Groups Changing 49 Software Monitoring 156 Standard Interlocking 302 Static Blocking 213 Switchgear Control 299 Switching Device Control 421 Synchrocheck 25 409 Uberstromzeitschutz einphasig Dropout Ratios 380 Underfrequency 138 Undervoltage Consideration 65 Undervoltage Protection 27 124 Undervoltage-controlled reactive power protection (27/ Q) 391 User Interface 356 User-defined Functions (CFC) 411 V Vibration and Shock Stress during Steady-State Operation 360 Vibration and Shock Stress during Transport 360 voltage controlled 65 Voltage Inputs 354 Voltage limit 115 Voltage Protection 381 voltage restraint 65 Voltage supply 354 Voltage Symmetry monitoring 157 W Watchdog 156 T Tank leakage protection 115 Tank Leakage Protection 120 sensitivity 120 time delay 120 Temperatures 360 Terminal Assignments 434 Terminating the Trip Signal 275 Test fault record 350 Testing: System Interface 333 Thermal Overload Protection 393 Thermal Replica 147 Time Allocation 418 Time synchronization 419 Transformer Saturation voltage 114 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017 561 562 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017