Siemens SIPROTEC 4 Manual 

tion 7SJ80 V4.7 Manual E50417-G1140-C343-A8 Preface Open Source Software Table of Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Ordering Information and Accessories A Terminal Assignments B Connection Examples C Current Transformer Requirements D Default Settings and Protocol-dependent Functions E Functions, Settings, Information F Literature Glossary Index

Disclaimer of Liability This document has been subjected to rigorous technical review before being published. It is revised at regular inter- vals, 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 agree- ments. 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 Copyright © 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®, DIGSI®, SIGUARD®, SIMEAS®, and SICAM® 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.

This manual describes the functions, operation, installation, and commissioning of devices 7SJ80. In partic- ular, one will find: • Information regarding the configuration of the scope of the device and a description of the device func- tions and settings → Chapter 2; • Instructions for Installation and Commissioning → Chapter 3; • Compilation of the Technical Data → Chapter 4; • As well as a compilation of the most significant data for advanced users → Appendix. General information with regard to design, configuration, and operation of SIPROTEC 4 devices are set out in the SIPROTEC 4 System Description /1/ SIPROTEC 4 System Description. Target Audience Protection-system engineers, commissioning engineers, persons entrusted with the setting, testing and main- tenance of selective protection, automation and control equipment, and operating personnel in electrical installations and power plants. 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 3 E50417-G1140-C343-A8, Edition 12.2017

Support Our Customer Support Center provides a 24-hour service. Phone: +49 (180) 524-7000 Fax: +49 (180) 524-2471 E-Mail: [email protected] Training Courses Inquiries regarding individual training courses should be addressed to our Training Center: Siemens AG Siemens Power Academy TD Humboldtstraße 59 90459 Nürnberg Germany Phone: +49 (911) 433-7415 Fax: +49 (911) 433-7929 E-Mail: [email protected] Internet: 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. ² 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. ² 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. ² Comply with all instructions, in order to avoid moderate or minor injuries. Preface 4 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

² Comply with all instructions, in order to avoid property damage. ii 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. • Hazardous voltages may be present in equipment even after the supply voltage has been disconnected (capacitors can still be charged). • 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. 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. Preface SIPROTEC 4, 7SJ80, Manual 5 E50417-G1140-C343-A8, Edition 12.2017

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) Preface 6 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Preface SIPROTEC 4, 7SJ80, Manual 7 E50417-G1140-C343-A8, Edition 12.2017

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 soft- ware. 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 9 E50417-G1140-C343-A8, Edition 12.2017

Preface..........................................................................................................................................................3 Open Source Software..................................................................................................................................9 1 Introduction................................................................................................................................................19 1.1 Overall Operation..............................................................................................................20 1.2 Application Scope............................................................................................................. 22 1.3 Characteristics.................................................................................................................. 24 2 Functions.................................................................................................................................................... 29 2.1 General.............................................................................................................................30 2.1.1 Functional Scope.........................................................................................................30 2.1.1.1 Functional Description........................................................................................... 30 2.1.1.2 Setting Notes......................................................................................................... 30 2.1.1.3 Settings................................................................................................................. 32 2.1.2 Device, General Settings.............................................................................................. 34 2.1.2.1 Functional Description........................................................................................... 34 2.1.2.2 Setting Notes......................................................................................................... 34 2.1.2.3 Settings................................................................................................................. 35 2.1.2.4 Information List..................................................................................................... 36 2.1.3 Power System Data 1...................................................................................................37 2.1.3.1 Functional Description........................................................................................... 37 2.1.3.2 Setting Notes......................................................................................................... 38 2.1.3.3 Settings................................................................................................................. 43 2.1.3.4 Information List..................................................................................................... 46 2.1.4 Oscillographic Fault Records........................................................................................ 46 2.1.4.1 Functional Description........................................................................................... 47 2.1.4.2 Setting Notes......................................................................................................... 48 2.1.4.3 Settings................................................................................................................. 48 2.1.4.4 Information List..................................................................................................... 48 2.1.5 Settings Groups...........................................................................................................49 2.1.5.1 Functional Description........................................................................................... 49 2.1.5.2 Setting Notes......................................................................................................... 49 2.1.5.3 Settings................................................................................................................. 49 2.1.5.4 Information List..................................................................................................... 49 2.1.6 Power System Data 2...................................................................................................50 2.1.6.1 Functional Description........................................................................................... 50 2.1.6.2 Setting Notes......................................................................................................... 50 2.1.6.3 Settings................................................................................................................. 53 2.1.6.4 Information List..................................................................................................... 54 2.1.7 EN100-Module............................................................................................................ 55 2.1.7.1 Functional Description........................................................................................... 55 2.1.7.2 Setting Notes......................................................................................................... 55 2.1.7.3 Information List..................................................................................................... 55 SIPROTEC 4, 7SJ80, Manual 11 E50417-G1140-C343-A8, Edition 12.2017

2.2.1 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 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 Table of Contents 12 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Measurement Supervision......................................................................................... 154 2.11.1.1 General................................................................................................................154 2.11.1.2 Hardware Monitoring .......................................................................................... 154 2.11.1.3 Software Monitoring ........................................................................................... 156 2.11.1.4 Monitoring of the Transformer Circuits................................................................. 157 2.11.1.5 Measurement Voltage Failure Detection............................................................... 158 2.11.1.6 Broken Wire Monitoring of Voltage Transformer Circuits....................................... 162 2.11.1.7 Setting Notes....................................................................................................... 163 2.11.1.8 Settings............................................................................................................... 164 2.11.1.9 Information List................................................................................................... 165 2.11.2 Trip Circuit Supervision 74TC..................................................................................... 166 2.11.2.1 Functional Description......................................................................................... 166 2.11.2.2 Setting Notes....................................................................................................... 169 2.11.2.3 Settings............................................................................................................... 169 2.11.2.4 Information List................................................................................................... 170 2.11.3 Malfunction Responses of the Monitoring Functions.................................................. 170 2.11.3.1 Description.......................................................................................................... 170 2.12 Ground Fault Protection 64, 67N(s), 50N(s), 51N(s).........................................................172 2.12.1 Ground Fault Detection for cos-ϕ / sin-ϕ Measurement (Standard Method)..................172 2.12.2 Ground Fault Detection for V0/I0-ϕ Measurement.......................................................178 2.12.3 Extended Ground Fault Protection EPTR/TNP.............................................................. 182 2.12.3.1 General Information.............................................................................................182 2.12.3.2 Ground-Fault Protection EPTR - B.......................................................................... 183 2.12.3.3 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 Table of Contents SIPROTEC 4, 7SJ80, Manual 13 E50417-G1140-C343-A8, Edition 12.2017

2.13 Intermittent Ground Fault Protection...............................................................................198 2.13.1 Functional Description...............................................................................................198 2.13.2 Setting Notes.............................................................................................................201 2.13.3 Settings.....................................................................................................................202 2.13.4 Information List.........................................................................................................203 2.14 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 Information List.........................................................................................................241 2.18 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 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 Table of Contents 14 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

2.22.1 Pickup Logic of the Entire Device................................................................................275 2.22.2 Tripping Logic of the Entire Device.............................................................................275 2.22.3 Setting Notes.............................................................................................................276 2.23 Auxiliary Functions..........................................................................................................277 2.23.1 Message Processing...................................................................................................277 2.23.1.1 LED Displays and Binary Outputs (Output Relays)..................................................277 2.23.1.2 Information on the Integrated Display (LCD) or Personal Computer....................... 277 2.23.1.3 Information to a Control Center............................................................................279 2.23.2 Statistics....................................................................................................................279 2.23.2.1 Functional Description......................................................................................... 279 2.23.2.2 Circuit Breaker Maintenance.................................................................................280 2.23.2.3 Setting Notes....................................................................................................... 286 2.23.2.4 Information List................................................................................................... 288 2.23.3 Measurement............................................................................................................288 2.23.3.1 Display of Measured Values..................................................................................289 2.23.3.2 Transfer of Measured Values................................................................................ 290 2.23.3.3 Information List................................................................................................... 291 2.23.4 Average Measurements............................................................................................. 292 2.23.4.1 Functional Description......................................................................................... 292 2.23.4.2 Setting Notes....................................................................................................... 292 2.23.4.3 Settings............................................................................................................... 293 2.23.4.4 Information List................................................................................................... 293 2.23.5 Min/Max Measurement Setup.................................................................................... 293 2.23.5.1 Functional Description......................................................................................... 293 2.23.5.2 Setting Notes....................................................................................................... 293 2.23.5.3 Settings............................................................................................................... 294 2.23.5.4 Information List................................................................................................... 294 2.23.6 Set Points for Measured Values.................................................................................. 295 2.23.6.1 Setting Notes....................................................................................................... 296 2.23.7 Set Points for Statistic................................................................................................ 296 2.23.7.1 Functional Description......................................................................................... 296 2.23.7.2 Setting Notes....................................................................................................... 296 2.23.7.3 Information List................................................................................................... 296 2.23.8 Energy Metering........................................................................................................296 2.23.8.1 Functional Description......................................................................................... 297 2.23.8.2 Setting Notes....................................................................................................... 297 2.23.8.3 Settings............................................................................................................... 297 2.23.8.4 Information List................................................................................................... 297 2.23.9 Commissioning Aids.................................................................................................. 297 2.23.9.1 Functional Description......................................................................................... 298 2.24 Breaker Control...............................................................................................................299 2.24.1 Control Device...........................................................................................................299 2.24.1.1 Functional Description......................................................................................... 299 2.24.1.2 Information List................................................................................................... 300 Table of Contents SIPROTEC 4, 7SJ80, Manual 15 E50417-G1140-C343-A8, Edition 12.2017

2.24.2.1 Functional Description......................................................................................... 300 2.24.3 Command Sequence..................................................................................................300 2.24.3.1 Functional Description......................................................................................... 301 2.24.4 Interlocking...............................................................................................................301 2.24.4.1 Functional Description......................................................................................... 301 2.24.5 Command Logging.................................................................................................... 308 2.24.5.1 Functional Description......................................................................................... 308 2.25 Notes on Device Operation..............................................................................................309 2.25.1 Different operation....................................................................................................309 3 Mounting and Commissioning................................................................................................................. 311 3.1 Mounting and Connections............................................................................................. 312 3.1.1 Configuration Information......................................................................................... 312 3.1.2 Hardware Modifications.............................................................................................315 3.1.2.1 Disassembly.........................................................................................................315 3.1.2.2 Connections of the Current Terminals...................................................................318 3.1.2.3 Connections of the Voltage Terminals...................................................................319 3.1.2.4 Interface Modules................................................................................................ 320 3.1.2.5 Reassembly..........................................................................................................322 3.1.3 Installation................................................................................................................ 323 3.1.3.1 General................................................................................................................323 3.1.3.2 Panel Flush Mounting...........................................................................................324 3.1.3.3 Cubicle Mounting.................................................................................................325 3.1.3.4 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 ΙE..............................................................................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 4 Technical Data.......................................................................................................................................... 353 4.1 General Device Data........................................................................................................354 4.1.1 Analog Inputs............................................................................................................354 4.1.2 Auxiliary voltage........................................................................................................354 Table of Contents 16 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 A Ordering Information and Accessories.....................................................................................................425 A.1 Ordering Information 7SJ80 ........................................................................................... 426 A.2 Accessories..................................................................................................................... 431 B Terminal Assignments..............................................................................................................................433 B.1 7SJ80 — Housing for panel flush mounting and cubicle installation and for panel surface mounting ...........................................................................................................434 C Connection Examples............................................................................................................................... 441 C.1 Connection Examples for Current and Voltage Transformers............................................442 Table of Contents SIPROTEC 4, 7SJ80, Manual 17 E50417-G1140-C343-A8, Edition 12.2017

D Current Transformer Requirements......................................................................................................... 455 D.1 Accuracy limiting factors................................................................................................. 456 D.2 Class conversion............................................................................................................. 457 D.3 Cable core balance current transformer........................................................................... 458 E 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 F 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 Table of Contents 18 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

presented in their application, characteristics, and scope of functions. 1.1 Overall Operation 20 1.2 Application Scope 22 1.3 Characteristics 24 1 SIPROTEC 4, 7SJ80, Manual 19 E50417-G1140-C343-A8, Edition 12.2017

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 (ΙN) may be used for measuring the ground fault current ΙN (current transformer neutral point) or for a separate ground current transformer (for sensitive ground fault detection ΙNs 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 measured- value processing with regard to bandwidth and processing speed. The analog-to-digital (AD) transformer group consists of an analog-to-digital converter and memory compo- nents for the transmission of data to the microcomputer. 1.1 Introduction 1.1 Overall Operation 20 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

tion 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 parame- ters. 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 trans- mission 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. Introduction 1.1 Overall Operation SIPROTEC 4, 7SJ80, Manual 21 E50417-G1140-C343-A8, Edition 12.2017

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 posi- tions 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 (direc- tional 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 switch- gear via operator buttons, port B, binary inputs and - using a PC and the DIGSI software - via the front inter- face. 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 pass- word 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. Meas- urement quantities and values that are calculated can be displayed locally and communicated via the serial interfaces. Device messages can be assigned to a number of LEDs on the front cover (allocatable), can be externally processed via output contacts (allocatable), linked with user-definable logic functions and/or issued via serial interfaces. 1.2 Introduction 1.2 Application Scope 22 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 meas- ured 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 60870-5- 103 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. Introduction 1.2 Application Scope SIPROTEC 4, 7SJ80, Manual 23 E50417-G1140-C343-A8, Edition 12.2017

• Complete digital processing and control of measured values, from the sampling of the analog input quan- tities 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 trans- former, 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 • Easy device operation through an integrated operator panel or by means of a connected personal computer running DIGSI • Continuous calculation and display of measured and metered values on the front of the device • 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 informa- tion as well as instantaneous values for fault recording for a maximum time range of 20 s • 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 • 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 ΙN or summation current 3Ι0 • Two-phase operation of the overcurrent protection (ΙA, ΙC) is possible • For inverse-time overcurrent protection, selection from various characteristics of different standards possible • Blocking is possible, e.g. for reverse interlocking with any element • 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 • 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 1.3 Introduction 1.3 Characteristics 24 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

• 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 summa- tion 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 recog- nized • 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 • Suitable as differential protection that includes the neutral point current on transformer side, generator side or motor side or for a grounded reactor set • As tank leakage protection against abnormal leakage currents between transformer tanks and ground. 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 • Separate two-element overvoltage detection of the largest voltages applied or detection of the positive or negative sequence component of the voltages • Settable dropout ratio for all elements of the undervoltage and overvoltage protection. 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. Introduction 1.3 Characteristics SIPROTEC 4, 7SJ80, Manual 25 E50417-G1140-C343-A8, Edition 12.2017

• 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 • Monitoring of the current transformer and voltage transformer secondary circuits using sum and symmetry supervision with optional protection function blocking • Trip circuit monitoring possible • 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 • 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(Ι0, V0), wattmetric ground fault direction determi- nation • Any element can be set as directional or non-directional — forward sensing directional, or reverse sensing directional • Optionally applicable as additional ground fault protection. Intermittent Ground Fault Protection • Detects and accumulates intermittent ground faults • Tripping after configurable total time. Directional intermittent ground fault protection • Detects intermittent ground faults • Direction determination • Tripping after settable number of intermittent re-ignitions Introduction 1.3 Characteristics 26 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

• Single-shot or multi-shot • 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 • Separate programs for phase 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 • Synchronous reconnection is possible . 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 ΔV, the phase angle difference Δϕ and the frequency differ- ence Δf • Alternatively, check of the de-energized state before reclosing • 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 • Measurement also possible via transformer without external intermediate matching transformer • Measuring voltages optionally phase–to–phase or phase–to–ground. Phase Rotation • Selectable ABC or ACB by setting (static) or binary input (dynamic). Introduction 1.3 Characteristics SIPROTEC 4, 7SJ80, Manual 27 E50417-G1140-C343-A8, Edition 12.2017

• several independent subfunctions have been implemented(ΣΙ-procedure, ΣΙx-procedure, 2P-procedure and Ι2t-procedure) • Acquisition and conditioning of measured values for all subfunctions operates phase-selective using one procedure-specific threshold per subfunction. 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 • 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 oper- ating software) • Feedback of switching states via the switch auxiliary contacts • Plausibility monitoring of the circuit breaker position and check of interlocking conditions. Introduction 1.3 Characteristics 28 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 2 SIPROTEC 4, 7SJ80, Manual 29 E50417-G1140-C343-A8, Edition 12.2017

face 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 Descrip- tion /1/ SIPROTEC 4 System Description. 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 require- ments. Individual functions can be enabled or disabled during the configuration procedure. The interaction of functions may also be modified. 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. ii 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. 2.1 2.1.1 2.1.1.1 2.1.1.2 Functions 2.1 General 30 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 charac- teristic of the sensitive ground fault detection. You can select between cos φ / sin φ and V0/I0 φ mea. as the measurement procedure. The cos φ / sin φ procedure (via residual wattmetric current detection) is set by default. If the measuring method cos φ / sin φ 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 φ 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. Irre- spective of this, the basic functionality of the summation current formation (ΣΙ 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 ΣIx-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 Ι2t 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)”. Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 31 E50417-G1140-C343-A8, Edition 12.2017

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 φ / sin φ V0/I0 φ mea. cos φ / sin φ (sens.) Ground fault dir. character- istic 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 2.1.1.3 Functions 2.1 General 32 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

tion 154 81 O/U Disabled Enabled Disabled 81 Over/Underfrequency Protec- tion 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 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 33 E50417-G1140-C343-A8, Edition 12.2017

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. 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"). 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 sponta- neous 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] (Prim) IP-Addresses 0 to 3, NTP primary 2.1.2 2.1.2.1 2.1.2.2 Functions 2.1 General 34 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

(Sec) IP-Addresses 0 to 3, NTP secondary Address 668 Client activ client for primary and secondary addresses switched on or off. Address 669 Daylight Set 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 Address 676 S2W month to 679 S2W hour month, week (of the month), day of the week, hour of switching to winter time 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. 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.annun- ciations 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 2.1.2.3 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 35 E50417-G1140-C343-A8, Edition 12.2017

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 Information List No. Information Type of Informa- tion 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 2.1.2.4 Functions 2.1 General 36 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Power System Data 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 quan- tity polarities and their physical connections, breaker properties (where applicable) etc. There are also certain 2.1.3 2.1.3.1 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 37 E50417-G1140-C343-A8, Edition 12.2017

toring function. The following section discusses these parameters. 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 pre- setting 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 rota- tion 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 ΙN or ΙNS. [polung-stromwandler-020313-kn, 1, en_US] Figure 2-2 Polarity of current transformers Current Connection Ι4 (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 (Ι4). This corresponds to the Holmgreen connection, (see connection example in C Connection Examples). In this case, parameter 280 Holmgr. for Σi 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). 2.1.3.2 Functions 2.1 General 38 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 ΙA and ΙC must be connected to the first current input (terminals F1, F2) and to the third (terminals F5, F6) The ground current ΙN or ΙNs 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 ΙN2 (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 ΙN2 to the second current input (terminals F3, F4). The settings only differ in the calculation of ΙB. In the case of A,G2,C,G; G2->B, the phase current ΙB is determined from the phase currents ΙA and ΙC and from the measured ground current ΙN or ΙNs at the fourth current input. In the case of A,G2,C,G; G2->B, the phase current ΙB is determined from the phase currents ΙA and ΙC and from the measured ground current ΙN2 at the second current input. This setting is only possible for devices with sensitive ground current transformer. Therefore, the current ΙN2 at the second current input is referred to ΙN in the flexible protection functions and in the operational measured values. The sensitive ground current at the fourth current input is referred to ΙNs. 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. Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 39 E50417-G1140-C343-A8, Edition 12.2017

51N) x Directional time overcurrent protection ground 67N (Section 2.3 Directional Overcurrent Protec- tion 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 ΙN ΙNs Track in disturbance record ΙN ΙNs Important! The function “Directional Time Overcurrent Protection Ground 67N” may only be enabled if the ground current of the protected line is measured via ΙN2. This is not the case in the example shown in Figure 2-3. Here, the ground current of the protected line is measured via ΙN. The function must be deacti- vated. A connection in which the function can be enabled is illustrated in the Appendix C Connection Exam- ples Figure C-11 The settings for address 251 are only possible with DIGSI at Display Additional Settings- The Appendix provides some connection examples at C Connection Examples. ii 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 trans- former. 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. Functions 2.1 General 40 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

Connection type Functions Directional definite time/ inverse time overcurrent protection phase Directional definite- time/ inver- setime over- current protection ground Sensitive ground fault protection 50Ns, 51Ns, 67Ns Synchroni- zation Fault locator QU protec- tion Direc- tional intermit- tent ground fault Fuse failure monitor 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 ΙN 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. Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 41 E50417-G1140-C343-A8, Edition 12.2017

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 ΙN2 at address 238. secondary ampere rating must conform with the phase current transformer. To calculated the phase current ΙB correctly, the primary rated current of the ground current transformer, which is used to calculate ΙB (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 secon- dary 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 protec- tion 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 exces- sive 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 crite- rion, 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). Functions 2.1 General 42 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 inter- action 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 ΙB 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. ii NOTE If parameter 213 VT Connect. 3ph is set to Vph-g, VSyn, the voltage measured by voltage trans- former 1 is always used for voltage protection. Then parameters 614 and 615 are not available. ii NOTE 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 C Setting Options Default Setting Comments 201 CT Starpoint towards Line towards Busbar towards Line CT Starpoint 2.1.3.3 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 43 E50417-G1140-C343-A8, Edition 12.2017

20.00 kV Rated Primary Voltage 203 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. A B C A C B A B C 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 Closed Breaker Min. Current Threshold 5A 0.20 .. 5.00 A 0.20 A 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, three- phase 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 Functions 2.1 General 44 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Ix- Method 265 Cmd.via control (Setting options depend on configuration) none 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 Σi NO YES NO Holmgreen-conn. (for fast sum-i-monit.) Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 45 E50417-G1140-C343-A8, Edition 12.2017

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 Information List No. Information Type of Informa- tion Comments 5145 >Reverse Rot. SP >Reverse Phase Rotation 5147 Rotation ABC OUT Phase rotation ABC 5148 Rotation ACB OUT Phase rotation ACB Oscillographic Fault Records The Multifunctional Protection with Control 7SJ80 is equipped with a fault record memory. The instantaneous values of the measured values 2.1.3.4 2.1.4 Functions 2.1 General 46 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

(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 auto- matically 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. 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 Vph-g, 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 yes ven yes yes vSYN yes yes vx yes ii NOTE The signals used for the binary tracks can be allocated in DIGSI. ii NOTE 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 ΙN2 measured with the second current trans- former is indicated under track ΙN. The ground current detected by the fourth current transformer is indi- cated under track ΙNs. 2.1.4.1 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 47 E50417-G1140-C343-A8, Edition 12.2017

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 func- tion 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). 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 Information List No. Information Type of Informa- tion 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 2.1.4.2 2.1.4.3 2.1.4.4 Functions 2.1 General 48 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

Applications • 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. 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. Settings Addr. Parameter Setting Options Default Setting Comments 302 CHANGE Group A Group B Group C Group D Binary Input Protocol Group A Change to Another Setting Group Information List No. Information Type of Informa- tion Comments - P-GrpA act IntSP Setting Group A is active - P-GrpB act IntSP Setting Group B is active - P-GrpC act IntSP Setting Group C is active - P-GrpD act IntSP Setting Group D is active 7 >Set Group Bit0 SP >Setting Group Select Bit 0 8 >Set Group Bit1 SP >Setting Group Select Bit 1 2.1.5 2.1.5.1 2.1.5.2 2.1.5.3 2.1.5.4 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 49 E50417-G1140-C343-A8, Edition 12.2017

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. Setting Notes Definition of Nominal Rated Values At addresses 1101 FullScaleVolt. and 1102 FullScaleCurr., the primary reference voltage (phaseto- phase) 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: R0/s = 0.88 Ω/km (1.42 Ω/mile) Zero sequence resistance X0/s = 1.26 Ω/km (2.03 Ω/mile) Zero sequence reactance R1/s = 0.24 Ω/km (0.39 Ω/mile) Positive sequence resistance 2.1.6 2.1.6.1 2.1.6.2 Functions 2.1 General 50 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 func- tion. 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 Ω/mile if set to distance unit Miles (address 215, see Section 2.1.3.2 Setting Notes under "Distance Unit") or in Ω/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 addi- tional data on the voltage transformers will be used: Current Transformers 500 A/5 A Voltage Transformers 20 kV/0.1 kV The secondary reactance per unit length is calculated as follows: [xsekund-beispiel-260602-kn, 1, en_US] Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 51 E50417-G1140-C343-A8, Edition 12.2017

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 secon- dary values. Calculation Example:: 110 kV free line 150 mm2 with the following data: R'1 = 0.19 Ω/km (0.31 Ω/mile) X'1 = 0.42 Ω/km (0.69 Ω/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. Functions 2.1 General 52 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

The directional values (power, power factor, work and related min., max., mean and setpoint values), calcu- lated 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. Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secon- dary nominal current of the current transformer. Addr. Parameter C Setting Options Default Setting Comments 1101 FullScaleVolt. 0.10 .. 800.00 kV 20.00 kV Measurem:FullScale- Voltage(Equipm.rating) 1102 FullScaleCurr. 10 .. 50000 A 400 A Measurem:FullScaleCur- rent(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 Ω/mi 0.2420 Ω/mi feeder reactance per mile: x' 5A 0.0010 .. 3.0000 Ω/mi 0.0484 Ω/mi 1106 x' 1A 0.0050 .. 9.5000 Ω/km 0.1500 Ω/km feeder reactance per km: x' 5A 0.0010 .. 1.9000 Ω/km 0.0300 Ω/km 1107 I MOTOR START 1A 0.40 .. 10.00 A 2.50 A Motor Start Current (Block 49, Start 48) 5A 2.00 .. 50.00 A 12.50 A 1108 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. compen- sating factor RE/RL 6002 S1: XE/XL -0.33 .. 7.00 1.00 S1: Zero seq. compen- sating factor XE/XL 6003 S1: x' 1A 0.0050 .. 15.0000 Ω/mi 0.2420 Ω/mi S1: feeder reactance per mile: x' 5A 0.0010 .. 3.0000 Ω/mi 0.0484 Ω/mi 6004 S1: x' 1A 0.0050 .. 9.5000 Ω/km 0.1500 Ω/km S1: feeder reactance per km: x' 5A 0.0010 .. 1.9000 Ω/km 0.0300 Ω/km 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. compen- sating factor RE/RL 6012 S2: XE/XL -0.33 .. 7.00 1.00 S2: Zero seq. compen- sating factor XE/XL 6013 S2: x' 1A 0.0050 .. 15.0000 Ω/mi 0.2420 Ω/mi S2: feeder reactance per mile: x' 5A 0.0010 .. 3.0000 Ω/mi 0.0484 Ω/mi 2.1.6.3 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 53 E50417-G1140-C343-A8, Edition 12.2017

0.1500 Ω/km S2: feeder reactance per km: x' 5A 0.0010 .. 1.9000 Ω/km 0.0300 Ω/km 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. compen- sating factor RE/RL 6022 S3: XE/XL -0.33 .. 7.00 1.00 S3: Zero seq. compen- sating factor XE/XL 6023 S3: x' 1A 0.0050 .. 15.0000 Ω/mi 0.2420 Ω/mi S3: feeder reactance per mile: x' 5A 0.0010 .. 3.0000 Ω/mi 0.0484 Ω/mi 6024 S3: x' 1A 0.0050 .. 9.5000 Ω/km 0.1500 Ω/km S3: feeder reactance per km: x' 5A 0.0010 .. 1.9000 Ω/km 0.0300 Ω/km 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 Information List No. Information Type of Informa- tion 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 2.1.6.4 Functions 2.1 General 54 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 heteroge- neous 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. 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 allo- cated 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. Information List No. Information Type of Informa- tion Comments 009.0100 Failure Modul IntSP Failure EN100 Modul 009.0101 Fail Ch1 IntSP Failure EN100 Link Channel 1 (Ch1) 009.0102 Fail Ch2 IntSP Failure EN100 Link Channel 2 (Ch2) 2.1.7 2.1.7.1 2.1.7.2 2.1.7.3 Functions 2.1 General SIPROTEC 4, 7SJ80, Manual 55 E50417-G1140-C343-A8, Edition 12.2017

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 • 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 ΙN or with the quantities 3Ι0 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. Informa- tion 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 3Ι0. 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 Interconnection to other functions Overcurrent Protection Elements 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 • • • 2.2 2.2.1 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 56 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

Pickup Inrush Restraint 51N • • • • 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 ΙNom. If the measurement of the instanta- neous 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 func- tion 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. 2.2.2 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 57 E50417-G1140-C343-A8, Edition 12.2017

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. Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 58 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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. 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 Funda- mental, 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 disa- bled. 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 func- tion 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 2.2.3 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 59 E50417-G1140-C343-A8, Edition 12.2017

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 deacti- vated 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. Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 60 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 initi- ated 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. Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 61 E50417-G1140-C343-A8, Edition 12.2017

Figure 2-9 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 "Definite- time Overcurrent Elements 50-1, 50N-1 "). A voltage restraint can optionally be set (see Section “Inverse Time Overcurrent Protection (Voltage- controlled / 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. 2.2.4 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 62 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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. Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 63 E50417-G1140-C343-A8, Edition 12.2017

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-energiza- tion. 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 conven- tional electromechanical overcurrent relays located towards the source. Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 64 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Ι the Ι/ 51 PICKUP ratio is increased and the tripping time is reduced. Compared with the standard curves repre- sented 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 ΙA VA – VB ΙB VB – VC ΙC VC – VA In order to avoid an unwanted operation in case of a voltage transformer fault, a function blocking is imple- mented via a binary input controlled by the voltage transformer protection breaker as well as via the device- internal measuring voltage failure detection ("Fuse Failure Monitor"). The following two figures show the logic diagrams for the inverse time overcurrent protection with under- voltage consideration. 2.2.5 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 65 E50417-G1140-C343-A8, Edition 12.2017

Figure 2-13 Logic diagram of the voltage-controlled inverse time overcurrent protection Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 66 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

Figure 2-14 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. 2.2.6 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 67 E50417-G1140-C343-A8, Edition 12.2017

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 meas- ured currents, false device pickup due to inrush is still a potential problem since, depending on the trans- former 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 overcur- rent 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 * ΙNom,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 permis- sible 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 cross- blocking. 2.2.7 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 68 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

Figure 2-15 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. 2.2.8 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 69 E50417-G1140-C343-A8, Edition 12.2017

Internal indication Figure Output indication FNo. 50-3 A PU 50-2 A PU 50-1 A PU 51 A PU Figure 2-4 Figure 2-6 Figure 2-10 50/51 Ph A PU 1762 50-3 B PU 50-2 B PU 50-1 B PU 51 B PU Figure 2-4 Figure 2-6 Figure 2-10 50/51 Ph B PU 1763 50-3 C PU 50-2 C PU 50-1 C PU 51 C PU Figure 2-4 Figure 2-6 Figure 2-10 50/51 Ph C PU 1764 50N-3 PU 50N-2 PU 50N-1 PU 51N PU Figure 2-5 Figure 2-8 Figure 2-11 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 1837 (All pickups) 50(N)/51(N) PU 1761 In the trip signals, the element which initiated the tripping is also indicated. 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 opera- tional 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 suffi- cient 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, ΙB is not used for threshold compar- ison. 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. 2.2.9 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 70 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

On the other hand, if inrush with cross blocking is activated on A or C, B will also be blocked. 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. actu- ated 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 protec- tion 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 2.2.10 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 71 E50417-G1140-C343-A8, Edition 12.2017

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 unconsid- ered. • 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 2.2.11 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 72 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 ZT = 10 % Primary nominal voltage VNom1 = 110 kV Secondary nominal voltage VNom2 = 20 kV Vector groups Dy 5 Neutral point Grounded Fault power on 110 kV-side 1 GVA Based on the data above, the following fault currents are calculated: Three-Phase High Voltage Side Fault Current at 110 kV = 5250 A Three-Phase Low Voltage Side Fault Current at 20 kV = 3928 A On the High Voltage Side Flowing at 110 kV = 714 A The nominal current of the transformer is: ΙNomT, 110 = 84 A (High Voltage Side) ΙNomT, 20 = 462 A (Low Voltage Side) Current Transformer (High Voltage Side) 100 A/1 A Current Transformer (Low Voltage Side) 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 /ΙNom = 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 protec- tion: 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, Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 73 E50417-G1140-C343-A8, Edition 12.2017

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 func- tions (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 Defi- nite 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 oper- ates 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. Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 74 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

will be signaled. If the 51 element is not required at all, address 112 Charac. Phase should be set to Defi- nite 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 oper- ating 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 coordi- nation 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 Ι2f/Ιf 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 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 75 E50417-G1140-C343-A8, Edition 12.2017

spondingly, address 1313 MANUAL CLOSE is considered for the ground path address. Thus, the user deter- mines 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 Example for the generation of a manual close signal using the internal control function ii 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 trip- ping 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 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 76 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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). 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 C Setting Options Default Setting Comments 1201 FCT 50/51 ON OFF ON 50, 51 Phase Time Overcur- rent 1202 50-2 PICKUP 1A 0.10 .. 35.00 A; ∞ 4.00 A 50-2 Pickup 5A 0.50 .. 175.00 A; ∞ 20.00 A 1203 50-2 DELAY 0.00 .. 60.00 sec; ∞ 0.00 sec 50-2 Time Delay 1204 50-1 PICKUP 1A 0.10 .. 35.00 A; ∞ 1.00 A 50-1 Pickup 5A 0.50 .. 175.00 A; ∞ 5.00 A 1205 50-1 DELAY 0.00 .. 60.00 sec; ∞ 0.50 sec 50-1 Time Delay 1207 51 PICKUP 1A 0.10 .. 4.00 A 1.00 A 51 Pickup 5A 0.50 .. 20.00 A 5.00 A 1208 51 TIME DIAL 0.05 .. 3.20 sec; ∞ 0.50 sec 51 Time Dial 1209 51 TIME DIAL 0.50 .. 15.00 ; ∞ 5.00 51 Time Dial 1210 51 Drop-out 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 2.2.12 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 77 E50417-G1140-C343-A8, Edition 12.2017

∞ 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 0.00 .. 60.00 sec; ∞ 0.10 sec 50N-2 Time Delay 1304 50N-1 PICKUP 1A 0.05 .. 35.00 A; ∞ 0.20 A 50N-1 Pickup 5A 0.25 .. 175.00 A; ∞ 1.00 A 1305 50N-1 DELAY 0.00 .. 60.00 sec; ∞ 0.50 sec 50N-1 Time Delay 1307 51N PICKUP 1A 0.05 .. 4.00 A 0.20 A 51N Pickup 5A 0.25 .. 20.00 A 1.00 A 1308 51N TIME DIAL 0.05 .. 3.20 sec; ∞ 0.20 sec 51N Time Dial 1309 51N TIME DIAL 0.50 .. 15.00 ; ∞ 5.00 51N Time Dial 1310 51N 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 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 78 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 1A 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 0.00 .. 180.00 sec 0.00 sec Cross Block Time 2205 I Max 1A 0.30 .. 25.00 A 7.50 A Maximum Current for Inrush Restraint 5A 1.50 .. 125.00 A 37.50 A Information List No. Information Type of Informa- tion 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 2.2.13 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 79 E50417-G1140-C343-A8, Edition 12.2017

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 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N 80 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Functions 2.2 Overcurrent Protection 50, 51, 50N, 51N SIPROTEC 4, 7SJ80, Manual 81 E50417-G1140-C343-A8, Edition 12.2017

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 • 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 Overcurrent protection for parallel transformers 2.3 2.3.1 Functions 2.3 Directional Overcurrent Protection 67, 67N 82 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 Protec- tion Elements Connection to Auto- matic Reclosing Manual CLOSE Dynamic Cold Load Pickup Inrush Restraint 67-1 • • • • 67-2 • • • 67-3 • • • 67-TOC • • • • 67N-1 • • • • 67N-2 • • • Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 83 E50417-G1140-C343-A8, Edition 12.2017

matic Reclosing Manual CLOSE Dynamic Cold Load Pickup Inrush Restraint 67N-3 • • • 67N-TOC • • • • 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 direc- tion 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 avail- able separately for each element. The dropout value is approximately 95% of the pickup value for currents > 0.3 ΙNom. 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 func- tion 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 immedi- ately. 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, trip- ping 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. 2.3.2 Functions 2.3 Directional Overcurrent Protection 67, 67N 84 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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. 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 2.3.3 Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 85 E50417-G1140-C343-A8, Edition 12.2017

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 ΙNom. 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 func- tion 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 configu- rable 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. Functions 2.3 Directional Overcurrent Protection 67, 67N 86 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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. Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 87 E50417-G1140-C343-A8, Edition 12.2017

Figure 2-23 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 overcur- rent element time delay elapses. For ground current element 67N-TOC PICKUP, the characteristic may be selected independently of the char- acteristic 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 instantane- ously 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-energiza- tion. 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 conven- tional 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 direc- tional inverse time overcurrent protection of the phase currents. 2.3.4 Functions 2.3 Directional Overcurrent Protection 67, 67N 88 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

Figure 2-24 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. 2.3.5 Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 89 E50417-G1140-C343-A8, Edition 12.2017

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 thresh- olds 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. 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). 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 phase- tophase voltage are used as reference voltage. The unfaulted voltage also allows for a correct direction deter- mination even if the fault voltage has collapsed entirely (short-line fault). In phase-to-ground voltage connec- tions, 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 ΙN 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. 2.3.6 2.3.7 2.3.8 Functions 2.3 Directional Overcurrent Protection 67, 67N 90 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 determina- tion 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 nega- tive- 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-to- ground 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 determi- nation 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. Table 2-6 Measured Values for the Determination of Fault Direction Pickup Measuring element A B C ground Current Voltage Current Voltage Current Voltage Current Voltage A ΙA VB - VC — — — — — — B — — ΙB VC - VA — — — — C — — — — ΙC VA - VB — — N — — — — — — ΙN VN 1) A, N VB - VC — — — — ΙN VN 1) B, N — — ΙB VC - VA — — ΙN VN 1) C, N — — — — ΙC VA - VB ΙN VN 1) Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 91 E50417-G1140-C343-A8, Edition 12.2017

ΙB VC - VA — — — — B, C — — ΙB VC - VA ΙC VA - VB — — AC ΙA VB - VC — — ΙC VA - VB — — A, B, N ΙA VB - VC ΙB VC - VA — — ΙN VN 1) B, C, N — — ΙB VC - VA ΙC VA - VB ΙN VN 1) A, C, N ΙA VB - VC — — ΙC VA - VB ΙN VN 1) A, B, C ΙA VB - VC ΙB VC - VA ΙC VA - VB — — A, B, C, N ΙA VB - VC ΙB VC - VA ΙC VA - VB ΙN 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 ΙscA follows the fault voltage by fault angle ϕsc. 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 Functions 2.3 Directional Overcurrent Protection 67, 67N 92 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 -3Ι0 is phase offset by 180° to the fault current ΙscA and follows the fault voltage 3V0 by fault angle ϕsc. 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 -Ι0 (or ΙN) 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 nega- tive sequence values based on a single-phase ground fault in phase A. As reference voltage, the negative Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 93 E50417-G1140-C343-A8, Edition 12.2017

the fault current is displayed. The fault current -3Ι2 is in phase opposition to the fault current ΙscA and follows the voltage 3V2 by the fault angle ϕsc. The reference voltage is rotated through the setting value 1619 ROTA- TION 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 -3Ι2 is in this area, the device detects forward direction. Reverse Interlocking for Double End Fed Lines Application Example The directionality feature of the directional overcurrent protection enables the user to perform reverse inter- locking 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 avail- able 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 direc- tion (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 auxil- iary voltage loop to the relay located at the opposite end of the line. 2.3.9 Functions 2.3 Directional Overcurrent Protection 67, 67N 94 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 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 over- current 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. 2.3.10 Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 95 E50417-G1140-C343-A8, Edition 12.2017

or the quantities 3I0 calculated from the three phase currents. Devices featuring a sensitive ground current input generally use the calculated quantity 3Ι0. 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 direc- tional 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 phase- ground- faults is vertical on the short-circuit voltage. For this reason, the resulting setting of the angle of rota- tion is (see also Section 2.3.8 Determination of Direction): Ref. volt. angle of rotation = 90 - φsc Phase directional element (phase- to-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 = -φsc Directional ground element (phase- to-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 - φsc -15° Phase directional element (phase- to-phase fault) Functions 2.3 Directional Overcurrent Protection 67, 67N 96 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

2) With the assumption that these are cable lines Directional Orientation Directional overcurrent protection normally operates in the direction of the protected object (line, trans- former, 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. • 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. ii 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 Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 97 E50417-G1140-C343-A8, Edition 12.2017

the latter is to be selected in case of danger that the zero voltage be too small due to unfavourable zero impe- dance or that a parallel line influences the zero system. ii 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/Ι2. 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 condi- tion 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 indica- tion. Directional Overcurrent Element 67-1 (phases) The pickup value of the 67-1 element (67-1 PICKUP) address1504 should be set above the maximum antici- pated 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 selec- tivity. 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"). Functions 2.3 Directional Overcurrent Protection 67, 67N 98 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017

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 oper- ates 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. Functions 2.3 Directional Overcurrent Protection 67, 67N SIPROTEC 4, 7SJ80, Manual 99 E50417-G1140-C343-A8, Edition 12.2017

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 Defi- nite 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 instan- taneous 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 config- ured 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 Example for the generation of a manual close signal using the internal control function Functions 2.3 Directional Overcurrent Protection 67, 67N 100 SIPROTEC 4, 7SJ80, Manual E50417-G1140-C343-A8, Edition 12.2017