ABB REQ650 Applications Manual

Issued: October 2017 Revision: A Product version: 2.2.1 © Copyright 2017 ABB. All rights reserved

permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license. This product includes software developed by the OpenSSL Project for use in the OpenSSL Toolkit. (http://www.openssl.org/) This product includes cryptographic software written/developed by: Eric Young ([email protected]) and Tim Hudson ([email protected]). Trademarks ABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or registered trademarks of their respective holders. Warranty Please inquire about the terms of warranty from your nearest ABB representative.

or product description and are not to be deemed as a statement of guaranteed properties. All persons responsible for applying the equipment addressed in this manual must satisfy themselves that each intended application is suitable and acceptable, including that any applicable safety or other operational requirements are complied with. In particular, any risks in applications where a system failure and/or product failure would create a risk for harm to property or persons (including but not limited to personal injuries or death) shall be the sole responsibility of the person or entity applying the equipment, and those so responsible are hereby requested to ensure that all measures are taken to exclude or mitigate such risks. This document has been carefully checked by ABB but deviations cannot be completely ruled out. In case any errors are detected, the reader is kindly requested to notify the manufacturer. Other than under explicit contractual commitments, in no event shall ABB be responsible or liable for any loss or damage resulting from the use of this manual or the application of the equipment.

Communities on the approximation of the laws of the Member States relating to electromagnetic compatibility (EMC Directive 2004/108/EC) and concerning electrical equipment for use within specified voltage limits (Low-voltage directive 2006/95/EC). This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60255-26 for the EMC directive, and with the product standards EN 60255-1 and EN 60255-27 for the low voltage directive. The product is designed in accordance with the international standards of the IEC 60255 series.

Section 1 Introduction.....................................................................13 This manual......................................................................................13 Intended audience............................................................................13 Product documentation.....................................................................14 Product documentation set..........................................................14 Document revision history........................................................... 15 Related documents......................................................................16 Document symbols and conventions................................................16 Symbols.......................................................................................16 Document conventions................................................................17 IEC 61850 edition 1 / edition 2 mapping...........................................18 Section 2 Application......................................................................23 General IED application....................................................................23 Back-up protection functions............................................................ 24 Control and monitoring functions......................................................25 Communication.................................................................................27 Basic IED functions.......................................................................... 29 Section 3 Configuration..................................................................31 Description of configuration REQ650............................................... 31 Introduction..................................................................................31 Description of B11..................................................................31 Section 4 Analog inputs..................................................................33 Introduction.......................................................................................33 Setting guidelines............................................................................. 33 Setting of the phase reference channel.......................................34 Example................................................................................. 34 Setting of current channels..........................................................34 Example 1.............................................................................. 34 Example 2.............................................................................. 35 Example 3.............................................................................. 36 Examples on how to connect, configure and set CT inputs for most commonly used CT connections....................39 Example on how to connect a star connected three- phase CT set to the IED.........................................................40 Example how to connect delta connected three-phase CT set to the IED....................................................................44 Example how to connect single-phase CT to the IED............ 47 Table of contents Breaker protection REQ650 2.2 IEC 1 Application manual

rated primary current and minimum pickup of a protection IED.. 49 Setting of voltage channels......................................................... 49 Example................................................................................. 49 Examples how to connect, configure and set VT inputs for most commonly used VT connections.............................. 50 Examples on how to connect a three phase-to-earth connected VT to the IED........................................................ 51 Example on how to connect a phase-to-phase connected VT to the IED........................................................ 53 Example on how to connect an open delta VT to the IED for high impedance earthed or unearthed networks...............55 Example how to connect the open delta VT to the IED for low impedance earthed or solidly earthed power systems....................................................................... 58 Section 5 Local HMI....................................................................... 61 Display..............................................................................................62 LEDs.................................................................................................64 Keypad............................................................................................. 65 Local HMI functionality..................................................................... 67 Protection and alarm indication................................................... 67 Parameter management .............................................................68 Front communication...................................................................69 Section 6 Current protection...........................................................71 Instantaneous phase overcurrent protection PHPIOC .................... 71 Identification................................................................................ 71 Application...................................................................................71 Setting guidelines........................................................................ 72 Meshed network without parallel line..................................... 72 Meshed network with parallel line.......................................... 74 Directional phase overcurrent protection, four steps OC4PTOC......76 Identification................................................................................ 76 Application...................................................................................76 Setting guidelines........................................................................ 77 Settings for each step.............................................................79 Setting example......................................................................82 Instantaneous residual overcurrent protection EFPIOC .................. 87 Identification................................................................................ 87 Application...................................................................................87 Setting guidelines........................................................................ 87 Directional residual overcurrent protection, four steps EF4PTOC ...90 Identification................................................................................ 90 Setting guidelines........................................................................ 90 Table of contents 2 Breaker protection REQ650 2.2 IEC Application manual

2nd harmonic restrain.............................................................92 Parallel transformer inrush current logic.................................93 Switch onto fault logic.............................................................94 Settings for each step (x = 1, 2, 3 and 4)............................... 94 Four step directional negative phase sequence overcurrent protection NS4PTOC .......................................................................97 Identification................................................................................ 97 Application...................................................................................97 Setting guidelines........................................................................ 99 Settings for each step ............................................................99 Common settings for all steps.............................................. 102 Thermal overload protection, one time constant, Celsius/ Fahrenheit LCPTTR/LFPTTR.........................................................103 Identification.............................................................................. 104 Application.................................................................................104 Setting guideline........................................................................104 Breaker failure protection CCRBRF............................................... 105 Identification.............................................................................. 106 Application.................................................................................106 Setting guidelines...................................................................... 106 Stub protection STBPTOC ............................................................ 110 Identification.............................................................................. 110 Application.................................................................................110 Setting guidelines...................................................................... 111 Broken conductor check BRCPTOC ............................................. 112 Identification.............................................................................. 112 Application.................................................................................112 Setting guidelines...................................................................... 112 Section 7 Voltage protection........................................................ 113 Two step undervoltage protection UV2PTUV ................................113 Identification.............................................................................. 113 Application.................................................................................113 Setting guidelines...................................................................... 114 Equipment protection, such as for motors and generators...114 Disconnected equipment detection...................................... 114 Power supply quality ........................................................... 114 Voltage instability mitigation.................................................114 Backup protection for power system faults...........................114 Settings for two step undervoltage protection...................... 115 Two step overvoltage protection OV2PTOV ..................................116 Identification.............................................................................. 116 Application.................................................................................117 Table of contents Breaker protection REQ650 2.2 IEC 3 Application manual

Equipment protection, such as for motors, generators, reactors and transformers.................................................... 118 Equipment protection, capacitors......................................... 118 Power supply quality............................................................ 118 High impedance earthed systems........................................ 118 The following settings can be done for the two step overvoltage protection..........................................................118 Two step residual overvoltage protection ROV2PTOV ................. 121 Identification.............................................................................. 121 Application.................................................................................121 Setting guidelines...................................................................... 121 Equipment protection, such as for motors, generators, reactors and transformersEquipment protection for transformers......................................................................... 122 Equipment protection, capacitors......................................... 122 Power supply quality............................................................ 122 High impedance earthed systems........................................ 122 Direct earthed system.......................................................... 123 Settings for two step residual overvoltage protection...........124 Loss of voltage check LOVPTUV .................................................. 126 Identification.............................................................................. 126 Application.................................................................................126 Setting guidelines...................................................................... 126 Advanced users settings...................................................... 126 Section 8 Secondary system supervision.....................................127 Current circuit supervision CCSSPVC............................................127 Identification.............................................................................. 127 Application.................................................................................127 Setting guidelines...................................................................... 127 Fuse failure supervision FUFSPVC................................................128 Identification.............................................................................. 128 Application.................................................................................128 Setting guidelines...................................................................... 129 General.................................................................................129 Setting of common parameters............................................ 129 Negative sequence based....................................................130 Zero sequence based...........................................................131 Delta U and delta I ...............................................................131 Dead line detection...............................................................132 Section 9 Control..........................................................................133 Synchrocheck, energizing check, and synchronizing SESRSYN...133 Table of contents 4 Breaker protection REQ650 2.2 IEC Application manual

Application examples.................................................................139 Single circuit breaker with single busbar.............................. 140 Single circuit breaker with double busbar, external voltage selection...................................................................141 Single circuit breaker with double busbar, internal voltage selection...................................................................141 Setting guidelines...................................................................... 142 Autorecloser for 1 phase, 2 phase and/or 3 phase operation SMBRREC .....................................................................................147 Identification.............................................................................. 147 Application.................................................................................147 Auto reclosing operation Off and On....................................151 Start auto reclosing and conditions for start of a reclosing cycle......................................................................151 Start auto reclosing from circuit breaker open information...152 Blocking of the auto recloser................................................152 Control of the auto reclosing dead time for shot 1................152 Long trip signal.....................................................................153 Maximum number of reclosing shots....................................153 ARMode = 3ph, (normal setting for a three-phase shot)...... 153 ARMode = 1/2/3ph............................................................... 153 ARMode = 1/2ph, 1-phase or 2-phase reclosing in the first shot................................................................................154 ARMode = 1ph+1*2ph, 1-phase or 2-phase reclosing in the first shot..........................................................................154 ARMode = 1/2ph + 1*3ph, 1-phase, 2-phase or 3-phase reclosing in the first shot.......................................................155 ARMode = 1ph + 1*2/3ph, 1-phase, 2-phase or 3-phase reclosing in the first shot.......................................................155 External selection of auto reclosing mode............................156 Auto reclosing reclaim timer................................................. 156 Pulsing of the circuit breaker closing command and counter................................................................................. 156 Transient fault.......................................................................156 Permanent fault and reclosing unsuccessful signal............. 157 Lock-out initiation................................................................. 157 Evolving fault........................................................................158 Table of contents Breaker protection REQ650 2.2 IEC 5 Application manual

Thermal overload protection holding the auto recloser back159 Setting guidelines...................................................................... 159 Configuration........................................................................159 Auto recloser settings...........................................................165 Apparatus control APC...................................................................169 Application.................................................................................170 Bay control QCBAY..............................................................174 Switch controller SCSWI...................................................... 175 Switches SXCBR/SXSWI..................................................... 176 Proxy for signals from switching device via GOOSE XLNPROXY..........................................................................177 Interaction between modules.....................................................180 Setting guidelines...................................................................... 182 Bay control (QCBAY)........................................................... 183 Switch controller (SCSWI)....................................................183 Switch (SXCBR/SXSWI)...................................................... 184 Proxy for signals from switching device via GOOSE XLNPROXY..........................................................................185 Logic rotating switch for function selection and LHMI presentation SLGAPC.................................................................... 185 Application.................................................................................185 Setting guidelines...................................................................... 186 Selector mini switch VSGAPC........................................................186 Identification.............................................................................. 187 Application.................................................................................187 Setting guidelines...................................................................... 187 Single point generic control 8 signals SPC8GAPC........................ 188 Identification.............................................................................. 188 Application.................................................................................188 Setting guidelines...................................................................... 188 AutomationBits, command function for DNP3.0 AUTOBITS.......... 188 Identification.............................................................................. 189 Application.................................................................................189 Setting guidelines...................................................................... 189 Single command, 16 signals SINGLECMD.................................... 189 Identification.............................................................................. 189 Application.................................................................................189 Setting guidelines...................................................................... 191 Section 10 Logic.............................................................................193 Tripping logic SMPPTRC ...............................................................193 Identification.............................................................................. 193 Application.................................................................................193 Table of contents 6 Breaker protection REQ650 2.2 IEC Application manual

Single- and/or three-phase tripping......................................194 Single-, two- or three-phase tripping.................................... 196 Lock-out................................................................................196 Example of directional data..................................................197 Blocking of the function block...............................................199 Setting guidelines...................................................................... 199 Logic for group alarm ALMCALH....................................................199 Identification.............................................................................. 199 Application.................................................................................200 Setting guidelines...................................................................... 200 Logic for group alarm WRNCALH.................................................. 200 Identification.............................................................................. 200 Application............................................................................200 Setting guidelines.................................................................200 Logic for group indication INDCALH...............................................200 Identification.............................................................................. 200 Application............................................................................201 Setting guidelines.................................................................201 Configurable logic blocks................................................................201 Application.................................................................................201 Setting guidelines...................................................................... 201 Configuration........................................................................201 Fixed signal function block FXDSIGN............................................ 202 Identification.............................................................................. 202 Application.................................................................................202 Boolean 16 to Integer conversion B16I.......................................... 204 Identification.............................................................................. 204 Application.................................................................................204 Boolean to integer conversion with logical node representation, 16 bit BTIGAPC.....................................................205 Identification.............................................................................. 205 Application.................................................................................205 Integer to Boolean 16 conversion IB16.......................................... 206 Identification.............................................................................. 206 Application.................................................................................206 Integer to Boolean 16 conversion with logic node representation ITBGAPC................................................................207 Identification.............................................................................. 208 Application.................................................................................208 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC.....................................................................209 Identification.............................................................................. 209 Application.................................................................................209 Table of contents Breaker protection REQ650 2.2 IEC 7 Application manual

Comparator for integer inputs - INTCOMP..................................... 210 Identification.............................................................................. 210 Application.................................................................................210 Setting guidelines...................................................................... 210 Setting example.........................................................................210 Comparator for real inputs - REALCOMP...................................... 211 Identification.............................................................................. 211 Application.................................................................................211 Setting guidelines...................................................................... 211 Setting example.........................................................................212 Section 11 Monitoring.....................................................................215 Measurement..................................................................................215 Identification.............................................................................. 215 Application.................................................................................215 Zero clamping............................................................................217 Setting guidelines...................................................................... 218 Setting examples..................................................................221 Gas medium supervision SSIMG................................................... 225 Identification.............................................................................. 225 Application.................................................................................225 Setting guidelines...................................................................... 226 Liquid medium supervision SSIML................................................. 227 Identification.............................................................................. 227 Application.................................................................................227 Setting guidelines...................................................................... 227 Breaker monitoring SSCBR............................................................228 Identification.............................................................................. 228 Application.................................................................................228 Setting guidelines...................................................................... 231 Setting procedure on the IED...............................................231 Event function EVENT....................................................................232 Identification.............................................................................. 232 Application.................................................................................232 Setting guidelines...................................................................... 233 Disturbance report DRPRDRE....................................................... 233 Identification.............................................................................. 233 Application.................................................................................234 Setting guidelines...................................................................... 234 Recording times................................................................... 236 Binary input signals.............................................................. 237 Analog input signals............................................................. 238 Sub-function parameters......................................................238 Table of contents 8 Breaker protection REQ650 2.2 IEC Application manual

Identification.............................................................................. 240 Application.................................................................................240 Setting guidelines...................................................................... 240 Limit counter L4UFCNT..................................................................240 Identification.............................................................................. 241 Application.................................................................................241 Setting guidelines...................................................................... 241 Running hour-meter TEILGAPC.....................................................241 Identification.............................................................................. 241 Application.................................................................................241 Setting guidelines...................................................................... 242 Section 12 Metering....................................................................... 243 Pulse-counter logic PCFCNT......................................................... 243 Identification.............................................................................. 243 Application.................................................................................243 Setting guidelines...................................................................... 243 Function for energy calculation and demand handling ETPMMTR 244 Identification.............................................................................. 244 Application.................................................................................244 Setting guidelines...................................................................... 245 Section 13 Ethernet-based communication....................................247 Access point................................................................................... 247 Application.................................................................................247 Setting guidelines...................................................................... 247 Redundant communication.............................................................248 Identification.............................................................................. 248 Application.................................................................................249 Setting guidelines...................................................................... 250 Merging unit....................................................................................251 Application.................................................................................251 Setting guidelines...................................................................... 252 Routes............................................................................................ 252 Application.................................................................................252 Setting guidelines...................................................................... 252 Section 14 Station communication.................................................253 Communication protocols...............................................................253 IEC 61850-8-1 communication protocol......................................... 253 Application IEC 61850-8-1.........................................................253 Setting guidelines...................................................................... 255 Table of contents Breaker protection REQ650 2.2 IEC 9 Application manual

Sending data........................................................................ 255 Receiving data......................................................................255 IEC/UCA 61850-9-2LE communication protocol............................ 256 Introduction................................................................................256 Setting guidelines...................................................................... 258 Specific settings related to the IEC/UCA 61850-9-2LE communication..................................................................... 259 Loss of communication when used with LDCM....................259 Setting examples for IEC/UCA 61850-9-2LE and time synchronization.................................................................... 264 IEC 61850 quality expander QUALEXP.................................... 269 LON communication protocol......................................................... 270 Application.................................................................................270 MULTICMDRCV and MULTICMDSND..................................... 271 Identification......................................................................... 272 Application............................................................................272 Setting guidelines.................................................................272 SPA communication protocol......................................................... 272 Application.................................................................................272 Setting guidelines...................................................................... 273 IEC 60870-5-103 communication protocol..................................... 275 Application.................................................................................275 Functionality......................................................................... 275 Design.................................................................................. 276 Settings......................................................................................278 Settings for RS485 and optical serial communication.......... 279 Settings from PCM600......................................................... 280 Function and information types................................................. 282 DNP3 Communication protocol...................................................... 283 Application.................................................................................283 Section 15 Security........................................................................ 285 Authority status ATHSTAT............................................................. 285 Application.................................................................................285 Self supervision with internal event list INTERRSIG...................... 285 Application.................................................................................285 Change lock CHNGLCK.................................................................286 Application.................................................................................286 Denial of service SCHLCCH/RCHLCCH ....................................... 287 Application.................................................................................287 Setting guidelines...................................................................... 287 Section 16 Basic IED functions...................................................... 289 Table of contents 10 Breaker protection REQ650 2.2 IEC Application manual

Application.................................................................................289 Product information PRODINF....................................................... 289 Application.................................................................................289 Factory defined settings............................................................ 289 Measured value expander block RANGE_XP................................ 290 Identification.............................................................................. 290 Application.................................................................................291 Setting guidelines...................................................................... 291 Parameter setting groups............................................................... 291 Application.................................................................................291 Setting guidelines...................................................................... 292 Rated system frequency PRIMVAL................................................ 292 Identification.............................................................................. 292 Application.................................................................................292 Setting guidelines...................................................................... 292 Summation block 3 phase 3PHSUM.............................................. 292 Application.................................................................................292 Setting guidelines...................................................................... 293 Global base values GBASVAL....................................................... 293 Identification.............................................................................. 293 Application.................................................................................293 Setting guidelines...................................................................... 293 Signal matrix for binary inputs SMBI.............................................. 294 Application.................................................................................294 Setting guidelines...................................................................... 294 Signal matrix for binary outputs SMBO ......................................... 294 Application.................................................................................294 Setting guidelines...................................................................... 294 Signal matrix for analog inputs SMAI............................................. 295 Application.................................................................................295 Frequency values...................................................................... 295 Setting guidelines...................................................................... 296 Test mode functionality TESTMODE..............................................301 Application.................................................................................301 IEC 61850 protocol test mode..............................................302 Setting guidelines...................................................................... 303 Time synchronization TIMESYNCHGEN........................................303 Application.................................................................................303 Setting guidelines...................................................................... 304 System time..........................................................................304 Synchronization....................................................................304 Process bus IEC/UCA 61850-9-2LE synchronization.......... 308 Table of contents Breaker protection REQ650 2.2 IEC 11 Application manual

Current transformer requirements.................................................. 309 Current transformer basic classification and requirements....... 309 Conditions..................................................................................311 Fault current.............................................................................. 312 Secondary wire resistance and additional load......................... 312 General current transformer requirements................................ 313 Rated equivalent secondary e.m.f. requirements......................313 Breaker failure protection..................................................... 313 Current transformer requirements for CTs according to other standards..........................................................................314 Current transformers according to IEC 61869-2, class P, PR...........................................................................314 Current transformers according to IEC 61869-2, class PX, PXR (and old IEC 60044-6, class TPS and old British Standard, class X)........................................ 315 Current transformers according to ANSI/IEEE..................... 315 SNTP server requirements............................................................. 316 PTP requirements...........................................................................316 IEC/UCA 61850-9-2LE Merging unit requirements ....................... 316 Section 18 Glossary....................................................................... 319 Table of contents 12 Breaker protection REQ650 2.2 IEC Application manual

sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used. The manual can also provide assistance for calculating settings. 1.2 Intended audience GUID-C9B8127F-5748-4BEA-9E4F-CC762FE28A3A v11 This manual addresses the protection and control engineer responsible for planning, pre-engineering and engineering. The protection and control engineer must be experienced in electrical power engineering and have knowledge of related technology, such as protection schemes and communication principles. 1MRK 505 383-UEN A Section 1 Introduction Breaker protection REQ650 2.2 IEC 13 Application manual

GUID-3AA69EA6-F1D8-47C6-A8E6-562F29C67172 v15 IEC07000220-4-en.vsd Planning & purchase Engineering Installing Commissioning Operation Maintenance Decommissioning Deinstalling & disposal Application manual Operation manual Installation manual Engineering manual Communication protocol manual Cyber security deployment guideline Technical manual Commissioning manual IEC07000220 V4 EN-US Figure 1: The intended use of manuals throughout the product lifecycle The engineering manual contains instructions on how to engineer the IEDs using the various tools available within the PCM600 software. The manual provides instructions on how to set up a PCM600 project and insert IEDs to the project structure. The manual also recommends a sequence for the engineering of protection and control functions, LHMI functions as well as communication engineering for IEC 60870-5-103, IEC 61850, DNP3, LON and SPA. The installation manual contains instructions on how to install the IED. The manual provides procedures for mechanical and electrical installation. The chapters are organized in the chronological order in which the IED should be installed. The commissioning manual contains instructions on how to commission the IED. The manual can also be used by system engineers and maintenance personnel for assistance during the testing phase. The manual provides procedures for the checking of external circuitry and energizing the IED, parameter setting and configuration as well as verifying settings by secondary injection. The manual Section 1 1MRK 505 383-UEN A Introduction 14 Breaker protection REQ650 2.2 IEC Application manual

chapters are organized in the chronological order in which the IED should be commissioned. The relevant procedures may be followed also during the service and maintenance activities. The operation manual contains instructions on how to operate the IED once it has been commissioned. The manual provides instructions for the monitoring, controlling and setting of the IED. The manual also describes how to identify disturbances and how to view calculated and measured power grid data to determine the cause of a fault. The application manual contains application descriptions and setting guidelines sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used. The manual can also provide assistance for calculating settings. The technical manual contains operation principle descriptions, and lists function blocks, logic diagrams, input and output signals, setting parameters and technical data, sorted per function. The manual can be used as a technical reference during the engineering phase, installation and commissioning phase, and during normal service. The communication protocol manual describes the communication protocols supported by the IED. The manual concentrates on the vendor-specific implementations. The point list manual describes the outlook and properties of the data points specific to the IED. The manual should be used in conjunction with the corresponding communication protocol manual. The cyber security deployment guideline describes the process for handling cyber security when communicating with the IED. Certification, Authorization with role based access control, and product engineering for cyber security related events are described and sorted by function. The guideline can be used as a technical reference during the engineering phase, installation and commissioning phase, and during normal service. 1.3.2 Document revision history GUID-C8027F8A-D3CB-41C1-B078-F9E59BB73A6C v4 Document revision/date History –/May 2017 First release 1MRK 505 383-UEN A Section 1 Introduction Breaker protection REQ650 2.2 IEC 15 Application manual

Document numbers Application manual 1MRK 505 383-UEN Commissioning manual 1MRK 505 385-UEN Product guide 1MRK 505 386-BEN Technical manual 1MRK 505 384-UEN Type test certificate 1MRK 505 386-TEN 650 series manuals Document numbers Operation manual 1MRK 500 128-UEN Engineering manual 1MRK 511 420-UEN Installation manual 1MRK 514 027-UEN Communication protocol manual, DNP3 1MRK 511 413-UUS Communication protocol manual, IEC 60870-5-103 1MRK 511 416-UEN Communication protocol manual, IEC 61850 Edition 1 1MRK 511 414-UEN Communication protocol manual, IEC 61850 Edition 2 1MRK 511 415-UEN Communication protocol manual, LON 1MRK 511 417-UEN Communication protocol manual, SPA 1MRK 511 418-UEN Point list manual, DNP3 1MRK 511 419-UUS Accessories guide IEC: 1MRK 514 012-UEN ANSI: 1MRK 514 012-UUS Cyber security deployment guideline 1MRK 511 421-UEN Connection and Installation components 1MRK 513 003-BEN Test system, COMBITEST 1MRK 512 001-BEN Application guide, Communication set-up 1MRK 505 382-UEN 1.4 Document symbols and conventions 1.4.1 Symbols GUID-2945B229-DAB0-4F15-8A0E-B9CF0C2C7B15 v12 The electrical warning icon indicates the presence of a hazard which could result in electrical shock. The warning icon indicates the presence of a hazard which could result in personal injury. Section 1 1MRK 505 383-UEN A Introduction 16 Breaker protection REQ650 2.2 IEC Application manual

warning about the temperature of product surfaces. Class 1 Laser product. Take adequate measures to protect the eyes and do not view directly with optical instruments. The caution icon indicates important information or warning related to the concept discussed in the text. It might indicate the presence of a hazard which could result in corruption of software or damage to equipment or property. The information icon alerts the reader of important facts and conditions. The tip icon indicates advice on, for example, how to design your project or how to use a certain function. Although warning hazards are related to personal injury, it is necessary to understand that under certain operational conditions, operation of damaged equipment may result in degraded process performance leading to personal injury or death. It is important that the user fully complies with all warning and cautionary notices. 1.4.2 Document conventions GUID-96DFAB1A-98FE-4B26-8E90-F7CEB14B1AB6 v6 • Abbreviations and acronyms in this manual are spelled out in the glossary. The glossary also contains definitions of important terms. • Push button navigation in the LHMI menu structure is presented by using the push button icons. For example, to navigate between the options, use and . • HMI menu paths are presented in bold. For example, select Main menu/Settings. • LHMI messages are shown in Courier font. For example, to save the changes in non-volatile memory, select Yes and press . • Parameter names are shown in italics. For example, the function can be enabled and disabled with the Operation setting. • Each function block symbol shows the available input/output signal. 1MRK 505 383-UEN A Section 1 Introduction Breaker protection REQ650 2.2 IEC 17 Application manual

signal name may be customized using the PCM600 software. • the character * after an input signal name indicates that the signal must be connected to another function block in the application configuration to achieve a valid application configuration. • Logic diagrams describe the signal logic inside the function block and are bordered by dashed lines. • Signals in frames with a shaded area on their right hand side represent setting parameter signals that are only settable via the PST, ECT or LHMI. • If an internal signal path cannot be drawn with a continuous line, the suffix -int is added to the signal name to indicate where the signal starts and continues. • Signal paths that extend beyond the logic diagram and continue in another diagram have the suffix ”-cont.” Illustrations are used as an example and might show other products than the one the manual describes. The example that is illustrated is still valid. 1.5 IEC 61850 edition 1 / edition 2 mapping GUID-C5133366-7260-4C47-A975-7DBAB3A33A96 v4 Function block names are used in ACT and PST to identify functions. Respective function block names of Edition 1 logical nodes and Edition 2 logical nodes are shown in the table below. Table 1: IEC 61850 edition 1 / edition 2 mapping Function block name Edition 1 logical nodes Edition 2 logical nodes AGSAL AGSAL SECLLN0 AGSAL ALMCALH ALMCALH ALMCALH ALTIM - ALTIM ALTMS - ALTMS ALTRK - ALTRK BRCPTOC BRCPTOC BRCPTOC BTIGAPC B16IFCVI BTIGAPC CCPDSC CCRPLD CCPDSC CCRBRF CCRBRF CCRBRF CCSSPVC CCSRDIF CCSSPVC CMMXU CMMXU CMMXU CMSQI CMSQI CMSQI Table continues on next page Section 1 1MRK 505 383-UEN A Introduction 18 Breaker protection REQ650 2.2 IEC Application manual

Edition 1 logical nodes Edition 2 logical nodes CVGAPC GF2LLN0 GF2MMXN GF2PHAR GF2PTOV GF2PTUC GF2PTUV GF2PVOC PH1PTRC GF2MMXN GF2PHAR GF2PTOV GF2PTUC GF2PTUV GF2PVOC PH1PTRC CVMMXN CVMMXN CVMMXN DPGAPC DPGGIO DPGAPC DRPRDRE DRPRDRE DRPRDRE EF4PTOC EF4LLN0 EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EFPIOC EFPIOC EFPIOC ETPMMTR ETPMMTR ETPMMTR FUFSPVC SDDRFUF FUFSPVC HZPDIF HZPDIF HZPDIF INDCALH INDCALH INDCALH ITBGAPC IB16FCVB ITBGAPC L4UFCNT L4UFCNT L4UFCNT LCPTTR LCPTTR LCPTTR LD0LLN0 LLN0 LLN0 LDLPSCH LDLPDIF LDLPSCH LFPTTR LFPTTR LFPTTR LMBRFLO LMBRFLO LMBRFLO LOVPTUV LOVPTUV LOVPTUV LPHD LPHD LPHD LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC MVGAPC MVGGIO MVGAPC NS4PTOC EF4LLN0 EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EF4PTRC EF4RDIR PH1PTOC OC4PTOC OC4LLN0 GEN4PHAR PH3PTOC PH3PTRC GEN4PHAR PH3PTOC PH3PTRC OV2PTOV GEN2LLN0 OV2PTOV PH1PTRC OV2PTOV PH1PTRC PCFCNT PCGGIO PCFCNT Table continues on next page 1MRK 505 383-UEN A Section 1 Introduction Breaker protection REQ650 2.2 IEC 19 Application manual

Edition 1 logical nodes Edition 2 logical nodes PHPIOC PHPIOC PHPIOC QCBAY QCBAY BAY/LLN0 QCRSV QCRSV QCRSV RCHLCCH RCHLCCH RCHLCCH REFPDIF REFPDIF REFPDIF ROV2PTOV GEN2LLN0 PH1PTRC ROV2PTOV PH1PTRC ROV2PTOV SCHLCCH SCHLCCH SCHLCCH SCILO SCILO SCILO SCSWI SCSWI SCSWI SESRSYN RSY1LLN0 AUT1RSYN MAN1RSYN SYNRSYN AUT1RSYN MAN1RSYN SYNRSYN SLGAPC SLGGIO SLGAPC SMBRREC SMBRREC SMBRREC SMPPTRC SMPPTRC SMPPTRC SP16GAPC SP16GGIO SP16GAPC SPC8GAPC SPC8GGIO SPC8GAPC SPGAPC SPGGIO SPGAPC SSCBR SSCBR SSCBR SSIMG SSIMG SSIMG SSIML SSIML SSIML SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T3WPDIF T3WPDIF T3WGAPC T3WPDIF T3WPHAR T3WPTRC TEIGAPC TEIGGIO TEIGAPC TEILGAPC TEILGGIO TEILGAPC TMAGAPC TMAGGIO TMAGAPC TRPTTR TRPTTR TRPTTR UV2PTUV GEN2LLN0 PH1PTRC UV2PTUV PH1PTRC UV2PTUV VMMXU VMMXU VMMXU VMSQI VMSQI VMSQI VNMMXU VNMMXU VNMMXU VSGAPC VSGGIO VSGAPC WRNCALH WRNCALH WRNCALH ZCLCPSCH ZCLCPLAL ZCLCPSCH Table continues on next page Section 1 1MRK 505 383-UEN A Introduction 20 Breaker protection REQ650 2.2 IEC Application manual

Edition 1 logical nodes Edition 2 logical nodes ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZMFPDIS ZMFLLN0 PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU PSFPDIS PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU 1MRK 505 383-UEN A Section 1 Introduction Breaker protection REQ650 2.2 IEC 21 Application manual

GUID-3F024D79-D031-42DC-B0BC-1F3757B8D3E0 v4 Breaker protection REQ650 provides a standalone solution for applications where synchrocheck controlled closing of the circuit breaker is required, but the integration of the automatic reclosing function into the main line protection IED is not preferred or suitable. The advanced automatic reclosing, synchronizing, synchrocheck and energizing check functions of REQ650 provides an optimized standalone product. REQ650 provides backup to the main protection with redundant protection and control functions. One pre-configured package has been defined for the following application: • A breaker bay connecting a transmission line to a busbar, with back-up protection functions enabling single or three phase trip (B11) The backup protection is based on basic overcurrent and voltage based functions. In line protection applications, autoreclosing with or without synchrocheck is available. The package is configured and ready for direct use. Analog and control circuits have been pre-defined and other signals need to be applied as required for each application. The pre-configured IED can be changed and adapted to suit specific applications with the application configuration tool. The IED can be used in applications with the IEC/UCA 61850-9-2LE process bus with up to four Merging Units (MU). Each MU has eight analogue channels, four current and four voltages. Conventional input transformer module and Merging Unit channels can be mixed freely in your application. Forcing of binary inputs and outputs is a convenient way to test wiring in substations as well as testing configuration logic in the IEDs. Basically it means that all binary inputs and outputs on the IED I/O modules (BOM, BIM and IOM) can be forced to arbitrary values. Central Account Management is an authentication infrastructure that offers a secure solution for enforcing access control to IEDs and other systems within a substation. This incorporates management of user accounts, roles and certificates and the distribution of such, a procedure completely transparent to the user. The Flexible Product Naming allows the customer to use an IED-vendor independent IEC 61850 model of the IED. This customer model will be used as the 1MRK 505 383-UEN A Section 2 Application Breaker protection REQ650 2.2 IEC 23 Application manual

(e.g., names on the local HMI and names in the tools). This offers significant flexibility to adapt the IED to the customers' system and standard solution. GUID-F5776DD1-BD04-4872-BB89-A0412B4B5CC3 v1 The following tables list all the functions available in the IED. Those functions that are not exposed to the user or do not need to be configured are not described in this manual. 2.2 Back-up protection functions GUID-A8D0852F-807F-4442-8730-E44808E194F0 v13 IEC 61850 or function name ANSI Function description Breaker REQ650 (B11) Current protection PHPIOC 50 Instantaneous phase overcurrent protection 1 OC4PTOC 51_671) Directional phase overcurrent protection, four steps 1 EFPIOC 50N Instantaneous residual overcurrent protection 1 EF4PTOC 51N 67N2) Directional residual overcurrent protection, four steps 1 NS4PTOC 46I2 Four step directional negative phase sequence overcurrent protection 1 LCPTTR 26 Thermal overload protection, one time constant, Celsius 1 LFPTTR 26 Thermal overload protection, one time constant, Fahrenheit 1 CCRBRF 50BF Breaker failure protection 1 STBPTOC 50STB Stub protection 1 CCPDSC 52PD Pole discordance protection 1 BRCPTOC 46 Broken conductor check 1 Voltage protection UV2PTUV 27 Two step undervoltage protection 1 OV2PTOV 59 Two step overvoltage protection 1 ROV2PTOV 59N Two step residual overvoltage protection 1 LOVPTUV 27 Loss of voltage check 1 1) 67 requires voltage 2) 67N requires voltage Section 2 1MRK 505 383-UEN A Application 24 Breaker protection REQ650 2.2 IEC Application manual

GUID-E3777F16-0B76-4157-A3BF-0B6B978863DE v15 IEC 61850 or function name ANSI Function description Breaker REQ650 (B11) Control SESRSYN 25 Synchrocheck, energizing check and synchronizing 1 SMBRREC 79 Autorecloser 1 QCBAY Bay control 1 LOCREM Handling of LR-switch positions 1 LOCREMCTRL LHMI control of PSTO 1 SXCBR Circuit breaker 3 SCILO Interlocking 1 SCSWI Switch controller 5 SXSWI Circuit switch 3 XLNPROXY Proxy for signals from switching device via GOOSE 4 SLGAPC Logic rotating switch for function selection and LHMI presentation 15 VSGAPC Selector mini switch 30 DPGAPC Generic communication function for Double Point indication 16 SPC8GAPC Single point generic control function 8 signals 5 AUTOBITS Automation bits, command function for DNP3.0 3 SINGLECMD Single command, 16 signals 4 I103CMD Function commands for IEC 60870-5-103 1 I103GENCMD Function commands generic for IEC 60870-5-103 50 I103POSCMD IED commands with position and select for IEC 60870-5-103 50 I103POSCMDV IED direct commands with position for IEC 60870-5-503 50 I103IEDCMD IED commands for IEC 60870-5-103 1 I103USRCMD Function commands user defined for IEC 60870-5-103 4 Secondary system supervision CCSSPVC 87 Current circuit supervison 1 FUFSPVC Fuse failure supervision 1 Logic SMPPTRC 94 Tripping logic 6 SMAGAPC General start matrix block 6 STARTCOMB Start combinator 32 TMAGAPC Trip matrix logic 12 ALMCALH Logic for group alarm 5 WRNCALH Logic for group warning 5 INDCALH Logic for group indication 5 Table continues on next page 1MRK 505 383-UEN A Section 2 Application Breaker protection REQ650 2.2 IEC 25 Application manual

function name ANSI Function description Breaker REQ650 (B11) AND, GATE, INV, LLD, OR, PULSETIMER, RSMEMORY, SRMEMORY, TIMERSET, XOR Basic configurable logic blocks (see Table 2) 40–420 FXDSIGN Fixed signal function block 1 B16I Boolean to integer conversion, 16 bit 18 BTIGAPC Boolean to integer conversion with logical node representation, 16 bit 16 IB16 Integer to Boolean 16 conversion 18 ITBGAPC Integer to Boolean 16 conversion with Logic Node representation 16 TEIGAPC Elapsed time integrator with limit transgression and overflow supervision 12 INTCOMP Comparator for integer inputs 30 REALCOMP Comparator for real inputs 30 Table 2: Total number of instances for basic configurable logic blocks Basic configurable logic block Total number of instances AND 280 GATE 40 INV 420 LLD 40 OR 298 PULSETIMER 40 RSMEMORY 40 SRMEMORY 40 TIMERSET 60 XOR 40 IEC 61850 or function name ANSI Function description Breaker REQ650 (B11) Monitoring CVMMXN Power system measurement 6 CMMXU Current measurement 10 VMMXU Voltage measurement phase-phase 6 CMSQI Current sequence measurement 6 VMSQI Voltage sequence measurement 6 VNMMXU Voltage measurement phase-earth 6 AISVBAS General service value presentation of analog inputs 1 Table continues on next page Section 2 1MRK 505 383-UEN A Application 26 Breaker protection REQ650 2.2 IEC Application manual

function name ANSI Function description Breaker REQ650 (B11) SSIMG 63 Insulation supervision for gas medium 21 SSIML 71 Insulation supervision for liquid medium 3 SSCBR Circuit breaker condition monitoring 3 EVENT Event function 20 DRPRDRE, A1RADR- A4RADR, B1RBDR- B22RBDR Disturbance report 1 SPGAPC Generic communication function for single point indication 64 SP16GAPC Generic communication function for single point indication 16 inputs 16 MVGAPC Generic communication function for measured values 24 BINSTATREP Logical signal status report 3 RANGE_XP Measured value expander block 66 I103MEAS Measurands for IEC 60870-5-103 1 I103MEASUSR Measurands user defined signals for IEC 60870-5-103 3 I103AR Function status auto-recloser for IEC 60870-5-103 1 I103EF Function status earth-fault for IEC 60870-5-103 1 I103FLTPROT Function status fault protection for IEC 60870-5-103 1 I103IED IED status for IEC 60870-5-103 1 I103SUPERV Supervision status for IEC 60870-5-103 1 I103USRDEF Status for user defined signals for IEC 60870-5-103 20 L4UFCNT Event counter with limit supervision 30 TEILGAPC Running hour meter 6 Metering PCFCNT Pulse-counter logic 16 ETPMMTR Function for energy calculation and demand handling 6 2.4 Communication GUID-5F144B53-B9A7-4173-80CF-CD4C84579CB5 v15 IEC 61850 or function name ANSI Function description Breaker REQ650 (B11) Station communication LONSPA, SPA SPA communication protocol 1 ADE LON communciation protocol 1 HORZCOMM Network variables via LON 1 Table continues on next page 1MRK 505 383-UEN A Section 2 Application Breaker protection REQ650 2.2 IEC 27 Application manual

function name ANSI Function description Breaker REQ650 (B11) PROTOCOL Operation selection between SPA and IEC 60870-5-103 for SLM 1 RS485PROT Operation selection for RS485 1 RS485GEN RS485 1 DNPGEN DNP3.0 communication general protocol 1 CHSERRS485 DNP3.0 for EIA-485 communication protocol 1 CH1TCP, CH2TCP, CH3TCP, CH4TCP DNP3.0 for TCP/IP communication protocol 1 CHSEROPT DNP3.0 for TCP/IP and EIA-485 communication protocol 1 MSTSER DNP3.0 serial master 1 MST1TCP, MST2TCP, MST3TCP, MST4TCP DNP3.0 for TCP/IP communication protocol 1 DNPFREC DNP3.0 fault records for TCP/IP and EIA-485 communication protocol 1 IEC 61850-8-1 IEC 61850 1 GOOSEINTLKRCV Horizontal communication via GOOSE for interlocking 59 GOOSEBINRCV GOOSE binary receive 16 GOOSEDPRCV GOOSE function block to receive a double point value 64 GOOSEINTRCV GOOSE function block to receive an integer value 32 GOOSEMVRCV GOOSE function block to receive a measurand value 60 GOOSESPRCV GOOSE function block to receive a single point value 64 GOOSEXLNRCV GOOSE function block to receive a switching device 9 MULTICMDRCV/ MULTICMDSND Multiple command and transmit 60/10 OPTICAL103 IEC 60870-5-103 Optical serial communication 1 RS485103 IEC 60870-5-103 serial communication for RS485 1 AGSAL Generic security application component 1 LD0LLN0 IEC 61850 LD0 LLN0 1 SYSLLN0 IEC 61850 SYS LLN0 1 LPHD Physical device information 1 PCMACCS IED configuration protocol 1 SECALARM Component for mapping security events on protocols such as DNP3 and IEC103 1 FSTACCS Field service tool access 1 IEC 61850-9-2 Process bus communication, 4 merging units 1-P31 ACTIVLOG Activity logging 1 ALTRK Service tracking 1 PRP IEC 62439-3 Parallel redundancy protocol 1-P23 HSR IEC 62439-3 High-availability seamless redundancy 1-P24 PTP Precision time protocol 1 Table continues on next page Section 2 1MRK 505 383-UEN A Application 28 Breaker protection REQ650 2.2 IEC Application manual

function name ANSI Function description Breaker REQ650 (B11) FRONTSTATUS Access point diagnostic for front Ethernet port 1 SCHLCCH Access point diagnostic for non-redundant Ethernet port 4 RCHLCCH Access point diagnostic for redundant Ethernet ports 2 DHCP DHCP configuration for front access point 1 QUALEXP IEC 61850 quality expander 32 2.5 Basic IED functions GUID-C8F0E5D2-E305-4184-9627-F6B5864216CA v12 Table 3: Basic IED functions IEC 61850 or function name Description INTERRSIG Self supervision with internal event list TIMESYNCHGEN Time synchronization module BININPUT, SYNCHCAN, SYNCHGPS, SYNCHCMPPS, SYNCHLON, SYNCHPPH, SYNCHPPS, SNTP, SYNCHSPA Time synchronization PTP Precision time protocol TIMEZONE Time synchronization IRIG-B Time synchronization SETGRPS Number of setting groups ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO Signal matrix for binary outputs SMAI1 - SMAI12 Signal matrix for analog inputs 3PHSUM Summation block 3 phase ATHSTAT Authority status ATHCHCK Authority check AUTHMAN Authority management FTPACCS FTP access with password GBASVAL Global base values for settings ALTMS Time master supervision ALTIM Time management COMSTATUS Protocol diagnostic 1MRK 505 383-UEN A Section 2 Application Breaker protection REQ650 2.2 IEC 29 Application manual

IEC 61850 or function name ANSI Description LHMICTRL Local HMI signals LANGUAGE Local human machine language SCREEN Local HMI Local human machine screen behavior FNKEYTY1–FNKEYTY5 FNKEYMD1– FNKEYMD5 Parameter setting function for HMI in PCM600 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1– GRP1_LED15 GRP2_LED1– GRP2_LED15 GRP3_LED1– GRP3_LED15 Basic part for CP HW LED indication module Section 2 1MRK 505 383-UEN A Application 30 Breaker protection REQ650 2.2 IEC Application manual

3.1.1 Introduction GUID-79B8BC84-4AAB-44E7-86CD-FF63098B009D v2 The basic delivery includes one binary input module and one binary output module, which is sufficient for the default configured IO to trip and close circuit breaker. All IEDs can be reconfigured with the help of the application configuration tool in PCM600. The IED can be adapted to special applications and special logic can be developed, such as logic for automatic opening of disconnectors and closing of ring bays, automatic load transfer from one busbar to the other, and so on. The basic IED configuration is provided with the signal matrix, single line diagram and the application configuration prepared for the functions included in the product by default. All parameters should be verified by the customer, since these are specific to the system, object or application. Optional functions and optional IO ordered will not be configured at delivery. It should be noted that the standard only includes one binary input and one binary output module and only the key functions such as tripping are connected to the outputs in the signal matrix tool. The required total IO must be calculated and specified at ordering. The configurations are as far as found necessary provided with application comments to explain why the signals have been connected in the special way. On request, ABB is available to support the re-configuration work, either directly or to do the design checking. 3.1.1.1 Description of B11 GUID-D9C6EAEB-A4EA-49BF-BE90-CC3CAF1CA476 v1 A breaker bay connecting a transmission line to a busbar, with back-up protection functions enabling single or three phase trip. 1MRK 505 383-UEN A Section 3 Configuration Breaker protection REQ650 2.2 IEC 31 Application manual

12AI (7I+5U) CC RBRF 50BF 3I>BF EF4 PTOC 51N_67N 4(IN>) EF PIOC 50N IN>> PH PIOC 50 3I>> VN MMXU MET UN VN MMXU MET UN S SIMG 63 S SIML 71 WA2_VT WA1_VT LINE_CT LINE_VT SMP PTRC 94 1->0 SMB RREC 79 5(0→1) SMP PTRC 94 1→0 SES RSYN 25 SC/VC UV2 PTUV 27 2(3U<) V MSQI MET Usqi VN MMXU MET UN V MMXU MET U FUF SPVC U>/I< DRP RDRE DFR/SER DR C MMXU MET I C MSQI MET Isqi ETP MMTR MET W/Varh CV MMXN MET P/Q Other Functions available from the function library CCS SPVC 87 INd/I BRC PTOC 46 lub LC PTTR 26 q> LOV PTUV 27 NS4 PTOC 46I2 ROV2 PTOV 59N 3U0 OV2 PTOV 59 3U> OC4 PTOC 51_67 4(3I>) IEC10000323-6-en.vsd STB PTOC 50STB 3I>STB LF PTTR 26 θ> S CILO 3 Control S CSWI 3 Control S XSWI 3 Control Q CBAY 3 Control S SCBR S SCBR S SCBR Control CC PDSC 52PD PD S XCBR 3 Control S XCBR 3 Control S XCBR 3 Control IEC10000323 V6 EN-US Figure 2: Configuration diagram for configuration B11 Section 3 1MRK 505 383-UEN A Configuration 32 Breaker protection REQ650 2.2 IEC Application manual

measurement results and correct protection operations. For power measuring, all directional and differential functions, the directions of the input currents must be defined in order to reflect the way the current transformers are installed/connected in the field ( primary and secondary connections ). Measuring and protection algorithms in the IED use primary system quantities. Setting values are in primary quantities as well and it is important to set the data about the connected current and voltage transformers properly. An AISVBAS reference PhaseAngleRef can be defined to facilitate service values reading. This analog channel's phase angle will always be fixed to zero degrees and remaining analog channel's phase angle information will be shown in relation to this analog input. During testing and commissioning of the IED, the reference channel can be changed to facilitate testing and service values reading. The IED has the ability to receive analog values from primary equipment, that are sampled by Merging units (MU) connected to a process bus, via the IEC 61850-9-2 LE protocol. The availability of VT inputs depends on the ordered transformer input module (TRM) type. 4.2 Setting guidelines SEMOD55068-1 v1 SEMOD130348-4 v4 The available setting parameters related to analog inputs are depending on the actual hardware (TRM) and the logic configuration made in PCM600. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 33 Application manual

SEMOD55055-5 v3 All phase angles are calculated in relation to a defined reference. An appropriate analog input channel is selected and used as phase reference. The parameter PhaseAngleRef defines the analog channel that is used as phase angle reference. 4.2.1.1 Example SEMOD55055-11 v5 4.2.2 Setting of current channels SEMOD55055-16 v6 The direction of a current to the IED is depending on the connection of the CT. Unless indicated otherwise, the main CTs are supposed to be star connected and can be connected with the earthing point to the object or from the object. This information must be set in the IED. The convention of the directionality is defined as follows: A positive value of current, power, and so on means that the quantity has the direction into the object and a negative value means direction out from the object. For directional functions the direction into the object is defined as Forward and the direction out from the object is defined as Reverse. See Figure 3 A positive value of current, power, and so on (forward) means that the quantity flows towards the object. A negative value of current, power, and so on (reverse) means that the quantity flows away from the object. See Figure 3. Protected Object Line, transformer, etc Forward Reverse Definition of direction for directional functions Measured quantity is positive when flowing towards the object e.g. P, Q, I Reverse Forward Definition of direction for directional functions e.g. P, Q, I Measured quantity is positive when flowing towards the object Set parameter CTStarPoint Correct Setting is "ToObject" Set parameter CTStarPoint Correct Setting is "FromObject" en05000456.vsd IEC05000456 V1 EN-US Figure 3: Internal convention of the directionality in the IED With correct setting of the primary CT direction, CTStarPoint set to FromObject or ToObject, a positive quantities always flowing towards the protected object and a direction defined as Forward always is looking towards the protected object. The following examples show the principle. 4.2.2.1 Example 1 SEMOD55055-23 v6 Two IEDs used for protection of two objects. Section 4 1MRK 505 383-UEN A Analog inputs 34 Breaker protection REQ650 2.2 IEC Application manual

Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Forward Reverse Definition of direction for directional functions Line protection Setting of current input: Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Setting of current input: Set parameter CTStarPoint with Line as reference object. Correct setting is "FromObject" IEC05000753=IEC05 000753=1=en=Origin al[1].vsd Is Is Ip Ip Ip IED IED IEC05000753 V2 EN-US Figure 4: Example how to set CTStarPoint parameters in the IED Figure 4 shows the normal case where the objects have their own CTs. The settings for CT direction shall be done according to the figure. To protect the line, direction of the directional functions of the line protection shall be set to Forward. This means that the protection is looking towards the line. 4.2.2.2 Example 2 SEMOD55055-29 v7 Two IEDs used for protection of two objects and sharing a CT. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 35 Application manual

Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Forward Reverse Definition of direction for directional functions Line protection Setting of current input: Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Setting of current input: Set parameter CTStarPoint with Line as reference object. Correct setting is "FromObject" IED IED IEC05000460 V2 EN-US Figure 5: Example how to set CTStarPoint parameters in the IED This example is similar to example 1, but here the transformer is feeding just one line and the line protection uses the same CT as the transformer protection does. The CT direction is set with different reference objects for the two IEDs though it is the same current from the same CT that is feeding the two IEDs. With these settings, the directional functions of the line protection shall be set to Forward to look towards the line. 4.2.2.3 Example 3 SEMOD55055-35 v7 One IED used to protect two objects. Section 4 1MRK 505 383-UEN A Analog inputs 36 Breaker protection REQ650 2.2 IEC Application manual

Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Reverse Forward Definition of direction for directional line functions Setting of current input: Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" IED IEC05000461 V2 EN-US Figure 6: Example how to set CTStarPoint parameters in the IED In this example, one IED includes both transformer and line protections and the line protection uses the same CT as the transformer protection does. For both current input channels, the CT direction is set with the transformer as reference object. This means that the direction Forward for the line protection is towards the transformer. To look towards the line, the direction of the directional functions of the line protection must be set to Reverse. The direction Forward/Reverse is related to the reference object that is the transformer in this case. When a function is set to Reverse and shall protect an object in reverse direction, it shall be noted that some directional functions are not symmetrical regarding the reach in forward and reverse direction. It is in first hand the reach of the directional criteria that can differ. Normally it is not any limitation but it is advisable to have it in mind and check if it is acceptable for the application in question. If the IED has sufficient number of analog current inputs, an alternative solution is shown in Figure 7. The same currents are fed to two separate groups of inputs and the line and transformer protection functions are configured to the different inputs. The CT direction for the current channels to the line protection is set with the line as reference object and the directional functions of the line protection shall be set to Forward to protect the line. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 37 Application manual

for transformer functions: Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Forward Reverse Definition of direction for directional line functions Setting of current input for transformer functions: Set parameter CTStarPoint with Transformer as reference object. Correct setting is "ToObject" Setting of current input for line functions: Set parameter CTStarPoint with Line as reference object. Correct setting is "FromObject" IED IEC05000462 V2 EN-US Figure 7: Example how to set CTStarPoint parameters in the IED Figure 8: For busbar protection, it is possible to set the CTStarPoint parameters in two ways. The first solution will be to use busbar as a reference object. In that case for all CT inputs marked with 1 in Figure 8, set CTStarPoint = ToObject, and for all CT inputs marked with 2 in Figure 8, set CTStarPoint = FromObject. The second solution will be to use all connected bays as reference objects. In that case for all CT inputs marked with 1 in Figure 8, set CTStarPoint = FromObject, and for all CT inputs marked with 2 in Figure 8, set CTStarPoint = ToObject. Regardless which one of the above two options is selected, busbar differential protection will behave correctly. The main CT ratios must also be set. This is done by setting the two parameters CTsec and CTprim for each current channel. For a 1000/1 A CT, the following settings shall be used: • CTprim = 1000 (value in A) • CTsec =1 (value in A). Section 4 1MRK 505 383-UEN A Analog inputs 38 Breaker protection REQ650 2.2 IEC Application manual

commonly used CT connections SEMOD55055-296 v7 Figure 9 defines the marking of current transformer terminals commonly used around the world: In the SMAI function block, you have to set if the SMAI block is measuring current or voltage. This is done with the parameter: AnalogInputType: Current/Voltage. The ConnectionType: phase - phase/phase-earth and GlobalBaseSel. ISec IPri S1 (X1) P1 (H1) P2 (H2) S2 (X2) P2 (H2) P1 (H1) x x a) b) c) en06000641.vsd S2 (X2) S1 (X1) IEC06000641 V1 EN-US Figure 9: Commonly used markings of CT terminals Where: a) is symbol and terminal marking used in this document. Terminals marked with a square indicates the primary and secondary winding terminals with the same (that is, positive) polarity b) and c) are equivalent symbols and terminal marking used by IEC (ANSI) standard for CTs. Note that for these two cases the CT polarity marking is correct! It shall be noted that depending on national standard and utility practices, the rated secondary current of a CT has typically one of the following values: • 1A • 5A However, in some cases, the following rated secondary currents are used as well: • 2A • 10A The IED fully supports all of these rated secondary values. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 39 Application manual

• use 1A rated CT input into the IED in order to connect CTs with 1A and 2A secondary rating • use 5A rated CT input into the IED in order to connect CTs with 5A and 10A secondary rating 4.2.2.5 Example on how to connect a star connected three-phase CT set to the IED SEMOD55055-352 v11 Figure 10 gives an example about the wiring of a star connected two-phase CT set to the IED. It gives an overview of the actions which are needed to make this measurement available to the built-in protection and control functions within the IED as well. For correct terminal designations, see the connection diagrams valid for the delivered IED. L1 IL1 IL2 IL3 L2 L3 Protected Object CT 600/5 Star Connected IL1 IL2 IL3 IED IEC13000002-4-en.vsdx 1 2 3 4 SMAI2 BLOCK REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N AI3P AI1 AI2 AI3 AI4 AIN 5 IN IEC13000002 V4 EN-US Figure 10: Star connected three-phase CT set with star point towards the protected object Section 4 1MRK 505 383-UEN A Analog inputs 40 Breaker protection REQ650 2.2 IEC Application manual

three-phase CT set to the three CT inputs of the IED. 2) The current inputs are located in the TRM. It shall be noted that for all these current inputs the following setting values shall be entered for the example shown in Figure 10. • CTprim=600A • CTsec=5A • CTStarPoint=ToObject Ratio of the first two parameters is only used inside the IED. The third parameter (CTStarPoint=ToObject) as set in this example causes no change on the measured currents. In other words, currents are already measured towards the protected object. 3) These three connections are the links between the three current inputs and the three input channels of the preprocessing function block 4). Depending on the type of functions, which need this current information, more than one preprocessing block might be connected in parallel to the same three physical CT inputs. 4) The preprocessing block that has the task to digitally filter the connected analog inputs and calculate: • fundamental frequency phasors for all three input channels • harmonic content for all three input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block. For this application most of the preprocessing settings can be left to the default values. If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in power plants), then the setting parameters DFTReference shall be set accordingly. Section SMAI in this manual provides information on adaptive frequency tracking for the signal matrix for analogue inputs (SMAI). 5) AI3P in the SMAI function block is a grouped signal which contains all the data about the phases L1, L2, L3 and neutral quantity; in particular the data about fundamental frequency phasors, harmonic content and positive sequence, negative and zero sequence quantities are available. AI1, AI2, AI3, AI4 are the output signals from the SMAI function block which contain the fundamental frequency phasors and the harmonic content of the corresponding input channels of the preprocessing function block. AIN is the signal which contains the fundamental frequency phasors and the harmonic content of the neutral quantity. In this example, GRP2N is not connected so this data is calculated by the preprocessing function block on the basis of the inputs GRPL1, GRPL2 and GRPL3. If GRP2N is connected, the data reflects the measured value of GRP2N. Another alternative is to have the star point of the three-phase CT set as shown in Figure 11: 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 41 Application manual

Figure 11: Star connected three-phase CT set with its star point away from the protected object In the example, everything is done in a similar way as in the above described example (Figure 10). The only difference is the setting of the parameter CTStarPoint of the used current inputs on the TRM (item 2 in Figure 11 and 10): • CTprim=600A • CTsec=5A • CTStarPoint=FromObject The ratio of the first two parameters is only used inside the IED. The third parameter as set in this example will negate the measured currents in order to ensure that the currents are measured towards the protected object within the IED. A third alternative is to have the residual/neutral current from the three-phase CT set connected to the IED as shown in Figure 11. Section 4 1MRK 505 383-UEN A Analog inputs 42 Breaker protection REQ650 2.2 IEC Application manual

Figure 12: Star connected three-phase CT set with its star point away from the protected object and the residual/neutral current connected to the IED Where: 1) Shows how to connect three individual phase currents from a star connected three-phase CT set to the three CT inputs of the IED. 2) Shows how to connect residual/neutral current from the three-phase CT set to the fourth input in the IED. It shall be noted that if this connection is not made, the IED will still calculate this current internally by vectorial summation of the three individual phase currents. 3) Is the TRM where these current inputs are located. It shall be noted that for all these current inputs the following setting values shall be entered. • CTprim=800A • CTsec=1A • CTStarPoint=FromObject • ConnectionType=Ph-N The ratio of the first two parameters is only used inside the IED. The third parameter as set in this example will have no influence on measured currents (that is, currents are already measured towards the protected object). 4) Are three connections made in the Signal Matrix tool (SMT) and Application configuration tool (ACT), which connects these three current inputs to the first three input channels on the preprocessing function block 6). Depending on the type of functions, which need this current information, more than one preprocessing block might be connected in parallel to these three CT inputs. Table continues on next page 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 43 Application manual

(ACT), which connects the residual/neutral current input to the fourth input channel of the preprocessing function block 6). Note that this connection in SMT shall not be done if the residual/neutral current is not connected to the IED. 6) Is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate: • fundamental frequency phasors for all input channels • harmonic content for all input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors of the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block in the configuration tool. For this application, most of the preprocessing settings can be left to the default values. If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations), then the setting parameters DFTReference shall be set accordingly. 4.2.2.6 Example how to connect delta connected three-phase CT set to the IED SEMOD55055-392 v7 Figure 13 gives an example how to connect a delta connected three-phase CT set to the IED. It gives an overview of the required actions by the user in order to make this measurement available to the built-in protection and control functions in the IED as well. For correct terminal designations, see the connection diagrams valid for the delivered IED. Section 4 1MRK 505 383-UEN A Analog inputs 44 Breaker protection REQ650 2.2 IEC Application manual

Figure 13: Delta DAB connected three-phase CT set 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 45 Application manual

CT set to three CT inputs of the IED. 2) is the TRM where these current inputs are located. It shall be noted that for all these current inputs the following setting values shall be entered. CTprim=600A CTsec=5A • CTStarPoint=ToObject • ConnectionType=Ph-Ph 3) are three connections made in Signal Matrix Tool (SMT), Application configuration tool (ACT), which connect these three current inputs to first three input channels of the preprocessing function block 4). Depending on the type of functions which need this current information, more then one preprocessing block might be connected in parallel to these three CT inputs. 4) is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate: • fundamental frequency phasors for all three input channels • harmonic content for all three input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block. For this application most of the preprocessing settings can be left to the default values. If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations) then the setting parameters DFTReference shall be set accordingly. Another alternative is to have the delta connected CT set as shown in figure 14: Section 4 1MRK 505 383-UEN A Analog inputs 46 Breaker protection REQ650 2.2 IEC Application manual

Figure 14: Delta DAC connected three-phase CT set In this case, everything is done in a similar way as in the above described example, except that for all used current inputs on the TRM the following setting parameters shall be entered: CTprim=800A CTsec=1A • CTStarPoint=ToObject • ConnectionType=Ph-Ph It is important to notice the references in SMAI. As inputs at Ph-Ph are expected to be L1L2, L2L3 respectively L3L1 we need to tilt 180º by setting ToObject. 4.2.2.7 Example how to connect single-phase CT to the IED SEMOD55055-431 v8 Figure 15 gives an example how to connect the single-phase CT to the IED. It gives an overview of the required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED as well. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 47 Application manual

valid for the delivered IED. Protected Object L1 L2 L3 IED INP INS INS 2 IEC11000029-4-en.vsdx 4 3 CT 1000/1 a) b) (+) (+) (-) (-) (+) (-) 1 SMAI2 BLOCK REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC11000029 V4 EN-US Figure 15: Connections for single-phase CT input Where: 1) shows how to connect single-phase CT input in the IED. 2) is TRM where these current inputs are located. It shall be noted that for all these current inputs the following setting values shall be entered. For connection (a) shown in Fgure 15: CTprim= 1000 A CTsec= 1A CTStarPoint=ToObject For connection (b) shown in Figure 15: CTprim= 1000 A CTsec= 1A CTStarPoint=FromObject 3) shows the connection made in SMT tool, which connect this CT input to the fourth input channel of the preprocessing function block 4). 4) is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate values. The calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block. If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the power plants) then the setting parameters DFTReference shall be set accordingly. Section 4 1MRK 505 383-UEN A Analog inputs 48 Breaker protection REQ650 2.2 IEC Application manual

rated primary current and minimum pickup of a protection IED GUID-8EB19363-9178-4F04-A6AC-AF0C2F99C5AB v1 Note that for all line protection applications (e.g. distance protection or line differential protection) the parameter Base Current (i.e. IBase setting in the IED) used by the relevant protection function, shall always be set equal to the largest rated CT primary current among all CTs involved in the protection scheme. The rated CT primary current value is set as parameter CTPrim under the IED TRM settings. For all other protection applications (e.g. generator, shunt reactor, shunt capacitor and transformer protection) it is typically desirable to set IBase parameter equal to the rated current of the protected object. However this is only recommended to do if the rated current of the protected object is within the range of 40% to 120% of the selected CT rated primary current. If for any reason (e.g. high maximum short circuit current) the rated current of the protected object is less than 40% of the rated CT primary current, it is strongly recommended to set the parameter IBase in the IED to be equal to the largest rated CT primary current among all CTs involved in the protection scheme and installed on the same voltage level. This will effectively make the protection scheme less sensitive; however, such measures are necessary in order to avoid possible problems with loss of the measurement accuracy in the IED. Regardless of the applied relationship between the IBase parameter and the rated CT primary current, the corresponding minimum pickup of the function on the CT secondary side must always be verified. It is strongly recommended that the minimum pickup of any instantaneous protection function (e.g. differential, restricted earth fault, distance, instantaneous overcurrent, etc.) shall under no circumstances be less than 4% of the used IED CT input rating (i.e. 1A or 5A). This corresponds to 40mA secondary for IED 1A rated inputs and to 200mA secondary for IED 5A rated inputs used by the function. This shall be individually verified for all current inputs involved in the protection scheme. Note that exceptions from the above 4% rule may be acceptable for very special applications (e.g. when Multipurpose filter SMAIHPAC is involved in the protection scheme). 4.2.4 Setting of voltage channels SEMOD55055-44 v4 As the IED uses primary system quantities, the main VT ratios must be known to the IED. This is done by setting the two parameters VTsec and VTprim for each voltage channel. The phase-to-phase value can be used even if each channel is connected to a phase-to-earth voltage from the VT. 4.2.4.1 Example SEMOD55055-47 v3 Consider a VT with the following data: 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 49 Application manual

(Equation 1) The following setting should be used: VTprim=132 (value in kV) VTsec=110 (value in V) 4.2.4.2 Examples how to connect, configure and set VT inputs for most commonly used VT connections SEMOD55055-60 v6 Figure 16 defines the marking of voltage transformer terminals commonly used around the world. A (H1) B (H2) b (X2) a (X1) A (H1) N (H2) n (X2) a (X1) b) c) A (H1) N (H2) dn (X2) da (X1) d) UPri + + USec a) en06000591.vsd IEC06000591 V1 EN-US Figure 16: Commonly used markings of VT terminals Where: a) is the symbol and terminal marking used in this document. Terminals marked with a square indicate the primary and secondary winding terminals with the same (positive) polarity b) is the equivalent symbol and terminal marking used by IEC (ANSI) standard for phase-to- earth connected VTs c) is the equivalent symbol and terminal marking used by IEC (ANSI) standard for open delta connected VTs d) is the equivalent symbol and terminal marking used by IEC (ANSI) standard for phase-to- phase connected VTs It shall be noted that depending on national standard and utility practices the rated secondary voltage of a VT has typically one of the following values: • 100 V • 110 V • 115 V • 120 V • 230 V The IED fully supports all of these values and most of them will be shown in the following examples. Section 4 1MRK 505 383-UEN A Analog inputs 50 Breaker protection REQ650 2.2 IEC Application manual

the IED SEMOD55055-87 v9 Figure 17 gives an example on how to connect a three phase-to-earth connected VT to the IED. It gives an overview of required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED. For correct terminal designations, see the connection diagrams valid for the delivered IED. L1 IED L2 L3 66 3 110 3 kV V 1 3 2 66 3 110 3 kV V 66 3 110 3 kV V . #Not used 5 IEC06000599-4-en.vsdx 4 SMAI2 BLOCK REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000599 V4 EN-US Figure 17: A Three phase-to-earth connected VT 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 51 Application manual

Figure 18: A two phase-to-earth connected VT Where: 1) shows how to connect three secondary phase-to-earth voltages to three VT inputs on the IED 2) is the TRM where these three voltage inputs are located. For these three voltage inputs, the following setting values shall be entered: VTprim =132 kV VTsec = 110 V Inside the IED, only the ratio of these two parameters is used. It shall be noted that the ratio of the entered values exactly corresponds to ratio of one individual VT. 66 66 3 110 110 3 = EQUATION1903 V1 EN-US (Equation 2) Table continues on next page Section 4 1MRK 505 383-UEN A Analog inputs 52 Breaker protection REQ650 2.2 IEC Application manual

voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions which need this voltage information, more then one preprocessing block might be connected in parallel to these three VT inputs. 4) shows that in this example the fourth (that is, residual) input channel of the preprocessing block is not connected in SMT tool. Thus the preprocessing block will automatically calculate 3Uo inside by vectorial sum from the three phase to earth voltages connected to the first three input channels of the same preprocessing block. Alternatively, the fourth input channel can be connected to open delta VT input, as shown in Figure 20. 5) is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate: • fundamental frequency phasors for all input channels • harmonic content for all input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block in the configuration tool. For this application most of the preprocessing settings can be left to the default values. However the following settings shall be set as shown here: UBase=66 kV (that is, rated Ph-Ph voltage) If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations) then the setting parameters DFTReference shall be set accordingly. 4.2.4.4 Example on how to connect a phase-to-phase connected VT to the IED SEMOD55055-134 v7 Figure 19 gives an example how to connect a phase-to-phase connected VT to the IED. It gives an overview of the required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED. It shall be noted that this VT connection is only used on lower voltage levels (that is, rated primary voltage below 40 kV). 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 53 Application manual

Figure 19: A Two phase-to-phase connected VT Where: 1) shows how to connect the secondary side of a phase-to-phase VT to the VT inputs on the IED 2) is the TRM where these three voltage inputs are located. It shall be noted that for these three voltage inputs the following setting values shall be entered: VTprim=13.8 kV VTsec=120 V Please note that inside the IED only ratio of these two parameters is used. Table continues on next page Section 4 1MRK 505 383-UEN A Analog inputs 54 Breaker protection REQ650 2.2 IEC Application manual

(ACT), which connects these three voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions, which need this voltage information, more than one preprocessing block might be connected in parallel to these three VT inputs 4) shows that in this example the fourth (that is, residual) input channel of the preprocessing block is not connected in SMT. Note. If the parameters UL1, UL2, UL3, UN should be used the open delta must be connected here. 5) Preprocessing block has a task to digitally filter the connected analog inputs and calculate: • fundamental frequency phasors for all four input channels • harmonic content for all four input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block in the configuration tool. For this application most of the preprocessing settings can be left to the default values. However the following settings shall be set as shown here: ConnectionType=Ph-Ph UBase=13.8 kV If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations) then the setting parameters DFTReference shall be set accordingly. 4.2.4.5 Example on how to connect an open delta VT to the IED for high impedance earthed or unearthed networks SEMOD55055-163 v9 Figure 20 gives an example about the wiring of an open delta VT to the IED for high impedance earthed or unearthed power systems. It shall be noted that this type of VT connection presents a secondary voltage proportional to 3U0 to the IED. In case of a solid earth fault close to the VT location the primary value of 3Uo will be equal to: 3 0 3 3 Ph Ph Ph N U U U - - = × = × EQUATION1921 V3 EN-US (Equation 3) The primary rated voltage of an open Delta VT is always equal to UPh-E. Three series connected VT secondary windings gives a secondary voltage equal to three times the individual VT secondary winding rating. Thus the secondary windings of open delta VTs quite often have a secondary rated voltage equal to one third of the rated phase-to-phase VT secondary voltage (110/3V in this particular example). Figure 20 gives overview of required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED as well. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 55 Application manual

5 IEC06000601-4-en.vsdx # Not Used # Not Used SMAI2 BLOCK REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000601 V4 EN-US Figure 20: Open delta connected VT in high impedance earthed power system Section 4 1MRK 505 383-UEN A Analog inputs 56 Breaker protection REQ650 2.2 IEC Application manual

IED. +3U0 shall be connected to the IED 2) is the TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: 3 6.6 11.43 VTprim kV = × = EQUATION1923 V1 EN-US (Equation 4) 110 sec 3 110 3 VT V = × = EQUATION1924 V1 EN-US (Equation 5) Inside the IED, only the ratio of these two parameters is used. It shall be noted that the ratio of the entered values exactly corresponds to ratio of one individual open delta VT. 6.6 3 6.6 3 110 110 3 × = EQUATION1925 V1 EN-US (Equation 6) 3) shows that in this example the first three input channel of the preprocessing block is not connected in SMT tool or ACT tool. 4) shows the connection made in Signal Matrix Tool (SMT), Application configuration tool (ACT), which connect this voltage input to the fourth input channel of the preprocessing function block 5). 5) is a Preprocessing block that has the task to digitally filter the connected analog input and calculate: • fundamental frequency phasors for all four input channels • harmonic content for all four input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block in the configuration tool. For this application most of the preprocessing settings can be left to the default values. If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations ) then the setting parameters DFTReference shall be set accordingly. 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 57 Application manual

impedance earthed or solidly earthed power systems SEMOD55055-199 v6 Figure 21 gives an example about the connection of an open delta VT to the IED for low impedance earthed or solidly earthed power systems. It shall be noted that this type of VT connection presents secondary voltage proportional to 3U0 to the IED. In case of a solid earth fault close to the VT location the primary value of 3Uo will be equal to: 3 3 Ph Ph Ph E U Uo U - - = = EQUATION1926 V1 EN-US (Equation 7) The primary rated voltage of such VT is always equal to UPh-E Therefore, three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating. Thus the secondary windings of such open delta VTs quite often has a secondary rated voltage close to rated phase-to-phase VT secondary voltage, that is, 115V or 115/√3V as in this particular example. Figure 21 gives an overview of the actions which are needed to make this measurement available to the built-in protection and control functions within the IED. Section 4 1MRK 505 383-UEN A Analog inputs 58 Breaker protection REQ650 2.2 IEC Application manual

# Not Used # Not Used SMAI2 BLOCK REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N AI3P AI1 AI2 AI3 AI4 AIN 2 3 4 5 IEC06000602 V4 EN-US Figure 21: Open delta connected VT in low impedance or solidly earthed power system 1MRK 505 383-UEN A Section 4 Analog inputs Breaker protection REQ650 2.2 IEC 59 Application manual

IED. +3Uo shall be connected to the IED. 2) is TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: 3 138 138 3 VTprim kV = × = EQUATION1928 V1 EN-US (Equation 8) 115 sec 3 115 3 VT V = × = EQUATION1929 V1 EN-US (Equation 9) Inside the IED, only the ratio of these two parameters is used. It shall be noted that the ratio of the entered values exactly corresponds to ratio of one individual open delta VT. 138 138 3 115 115 3 = EQUATION1930 V1 EN-US (Equation 10) 3) shows that in this example the first three input channel of the preprocessing block is not connected in SMT tool. 4) shows the connection made in Signal Matrix Tool (SMT), which connect this voltage input to the fourth input channel of the preprocessing function block 4). 5) preprocessing block has a task to digitally filter the connected analog inputs and calculate: • fundamental frequency phasors for all four input channels • harmonic content for all four input channels • positive, negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels (channel one taken as reference for sequence quantities) These calculated values are then available for all built-in protection and control functions within the IED, which are connected to this preprocessing function block in the configuration tool. For this application most of the preprocessing settings can be left to the default values. If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations) then the setting parameters DFTReference shall be set accordingly. Section 4 1MRK 505 383-UEN A Analog inputs 60 Breaker protection REQ650 2.2 IEC Application manual

Figure 22: Local human-machine interface The LHMI of the IED contains the following elements: • Keypad • Display (LCD) • LED indicators • Communication port for PCM600 1MRK 505 383-UEN A Section 5 Local HMI Breaker protection REQ650 2.2 IEC 61 Application manual

5.1 Display GUID-55739D4F-1DA5-4112-B5C7-217AAF360EA5 v11 The LHMI includes a graphical monochrome liquid crystal display (LCD) with a resolution of 320 x 240 pixels. The character size can vary. The amount of characters and rows fitting the view depends on the character size and the view that is shown. The display view is divided into four basic areas. IEC15000270-1-en.vsdx IEC15000270 V1 EN-US Figure 23: Display layout 1 Path 2 Content 3 Status 4 Scroll bar (appears when needed) The function key button panel shows on request what actions are possible with the function buttons. Each function button has a LED indication that can be used as a Section 5 1MRK 505 383-UEN A Local HMI 62 Breaker protection REQ650 2.2 IEC Application manual

required signal with PCM600. IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN-US Figure 24: Function button panel The indication LED panel shows on request the alarm text labels for the indication LEDs. Three indication LED pages are available. IEC13000240-1-en.vsd GUID-5157100F-E8C0-4FAB-B979-FD4A971475E3 V1 EN-US Figure 25: Indication LED panel The function button and indication LED panels are not visible at the same time. Each panel is shown by pressing one of the function buttons or the Multipage button. Pressing the ESC button clears the panel from the display. Both panels have a dynamic width that depends on the label string length. 1MRK 505 383-UEN A Section 5 Local HMI Breaker protection REQ650 2.2 IEC 63 Application manual

There are 15 programmable indication LEDs on the front of the LHMI. Each LED can indicate three states with the colors: green, yellow and red. The texts related to each three-color LED are divided into three panels. There are 3 separate panels of LEDs available. The 15 physical three-color LEDs in one LED group can indicate 45 different signals. Altogether, 135 signals can be indicated since there are three LED groups. The LEDs are lit according to priority, with red being the highest and green the lowest priority. For example, if on one panel there is an indication that requires the green LED to be lit, and on another panel there is an indication that requires the red LED to be lit, the red LED takes priority and is lit. The LEDs can be configured with PCM600 and the operation mode can be selected with the LHMI or PCM600. Information panels for the indication LEDs are shown by pressing the Multipage button. Pressing that button cycles through the three pages. A lit or un- acknowledged LED is indicated with a highlight. Such lines can be selected by using the Up/Down arrow buttons. Pressing the Enter key shows details about the selected LED. Pressing the ESC button exits from information pop-ups as well as from the LED panel as such. The Multipage button has a LED. This LED is lit whenever any LED on any panel is lit. If there are un-acknowledged indication LEDs, then the Multipage LED blinks. To acknowledge LEDs, press the Clear button to enter the Reset menu (refer to description of this menu for details). There are two additional LEDs which are next to the control buttons and . These LEDs can indicate the status of two arbitrary binary signals by configuring the OPENCLOSE_LED function block. For instance, OPENCLOSE_LED can be connected to a circuit breaker to indicate the breaker open/close status on the LEDs. Section 5 1MRK 505 383-UEN A Local HMI 64 Breaker protection REQ650 2.2 IEC Application manual

Figure 26: OPENCLOSE_LED connected to SXCBR 5.3 Keypad AMU0600428 v17 The LHMI keypad contains push-buttons which are used to navigate in different views or menus. The push-buttons are also used to acknowledge alarms, reset indications, provide help and switch between local and remote control mode. The keypad also contains programmable push-buttons that can be configured either as menu shortcut or control buttons. 1MRK 505 383-UEN A Section 5 Local HMI Breaker protection REQ650 2.2 IEC 65 Application manual

Figure 27: LHMI keypad with object control, navigation and command push- buttons and RJ-45 communication port 1...5 Function button 6 Close 7 Open 8 Escape 9 Left 10 Down 11 Up 12 Right 13 Key 14 Enter 15 Remote/Local 16 Uplink LED 17 Not in use 18 Multipage 19 Menu Section 5 1MRK 505 383-UEN A Local HMI 66 Breaker protection REQ650 2.2 IEC Application manual

24 IED status LEDs 5.4 Local HMI functionality 5.4.1 Protection and alarm indication GUID-09CCB9F1-9B27-4C12-B253-FBE95EA537F5 v15 Protection indicators The protection indicator LEDs are Ready, Start and Trip. The start and trip LEDs are configured via the disturbance recorder. The yellow and red status LEDs are configured in the disturbance recorder function, DRPRDRE, by connecting a start or trip signal from the actual function to a BxRBDR binary input function block using the PCM600 and configure the setting to Off, Start or Trip for that particular signal. Table 5: Ready LED (green) LED state Description Off Auxiliary supply voltage is disconnected. On Normal operation. Flashing Internal fault has occurred. Table 6: Start LED (yellow) LED state Description Off Normal operation. On A protection function has started and an indication message is displayed. The start indication is latching and must be reset via communication, LHMI or binary input on the LEDGEN component. To open the reset menu on the LHMI, press . Flashing The IED is in test mode and protection functions are blocked, or the IEC61850 protocol is blocking one or more functions. The indication disappears when the IED is no longer in test mode and blocking is removed. The blocking of functions through the IEC61850 protocol can be reset in Main menu/Test/Reset IEC61850 Mod. The yellow LED changes to either On or Off state depending on the state of operation. 1MRK 505 383-UEN A Section 5 Local HMI Breaker protection REQ650 2.2 IEC 67 Application manual

LED state Description Off Normal operation. On A protection function has tripped. An indication message is displayed if the auto-indication feature is enabled in the local HMI. The trip indication is latching and must be reset via communication, LHMI or binary input on the LEDGEN component. To open the reset menu on the LHMI, press . Flasing Configuration mode. Alarm indicators The 15 programmable three-color LEDs are used for alarm indication. An individual alarm/status signal, connected to any of the LED function blocks, can be assigned to one of the three LED colors when configuring the IED. Table 8: Alarm indications LED state Description Off Normal operation. All activation signals are off. On • Follow-S sequence: The activation signal is on. • LatchedColl-S sequence: The activation signal is on, or it is off but the indication has not been acknowledged. • LatchedAck-F-S sequence: The indication has been acknowledged, but the activation signal is still on. • LatchedAck-S-F sequence: The activation signal is on, or it is off but the indication has not been acknowledged. • LatchedReset-S sequence: The activation signal is on, or it is off but the indication has not been acknowledged. Flashing • Follow-F sequence: The activation signal is on. • LatchedAck-F-S sequence: The activation signal is on, or it is off but the indication has not been acknowledged. • LatchedAck-S-F sequence: The indication has been acknowledged, but the activation signal is still on. 5.4.2 Parameter management GUID-5EE466E3-932B-4311-9FE1-76ECD8D6E245 v9 The LHMI is used to access the relay parameters. Three types of parameters can be read and written. • Numerical values • String values • Enumerated values Numerical values are presented either in integer or in decimal format with minimum and maximum values. Character strings can be edited character by character. Enumerated values have a predefined set of selectable values. Section 5 1MRK 505 383-UEN A Local HMI 68 Breaker protection REQ650 2.2 IEC Application manual

• The green uplink LED on the left is lit when the cable is successfully connected to the port. • The yellow LED is not used; it is always off. IEC13000280-1-en.vsd 1 2 GUID-AACFC753-BFB9-47FE-9512-3C4180731A1B V1 EN-US Figure 28: RJ-45 communication port and green indicator LED 1 RJ-45 connector 2 Green indicator LED The default IP address for the IED front port is 10.1.150.3 and the corresponding subnetwork mask is 255.255.254.0. It can be set through the local HMI path Main menu/Configuration/Communication/Ethernet configuration/FRONT port/ AP_FRONT. Do not connect the IED front port to a LAN. Connect only a single local PC with PCM600 to the front port. It is only intended for temporary use, such as commissioning and testing. 1MRK 505 383-UEN A Section 5 Local HMI Breaker protection REQ650 2.2 IEC 69 Application manual

PHPIOC IP14506-1 v6 6.1.1 Identification M14880-1 v5 Function description IEC 61850 identification IEC 60617 identification ANSI/IEEE C37.2 device number Instantaneous phase overcurrent protection PHPIOC 3I>> SYMBOL-Z V1 EN-US 50 6.1.2 Application M12911-3 v6 Long transmission lines often transfer great quantities of electric power from generation to consumption areas. The unbalance of the produced and consumed electric power at each end of the transmission line is very large. This means that a fault on the line can easily endanger the stability of a complete system. The transient stability of a power system depends mostly on three parameters (at constant amount of transmitted electric power): • The type of the fault. Three-phase faults are the most dangerous, because no power can be transmitted through the fault point during fault conditions. • The magnitude of the fault current. A high fault current indicates that the decrease of transmitted power is high. • The total fault clearing time. The phase angles between the EMFs of the generators on both sides of the transmission line increase over the permitted stability limits if the total fault clearing time, which consists of the protection operating time and the breaker opening time, is too long. The fault current on long transmission lines depends mostly on the fault position and decreases with the distance from the generation point. For this reason the protection must operate very quickly for faults very close to the generation (and relay) point, for which very high fault currents are characteristic. The instantaneous phase overcurrent protection PHPIOC can operate in 10 ms for faults characterized by very high currents. 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 71 Application manual

the local HMI or PCM600. This protection function must operate only in a selective way. So check all system and transient conditions that could cause its unwanted operation. Only detailed network studies can determine the operating conditions under which the highest possible fault current is expected on the line. In most cases, this current appears during three-phase fault conditions. But also examine single-phase-to-earth and two-phase-to-earth conditions. Also study transients that could cause a high increase of the line current for short times. A typical example is a transmission line with a power transformer at the remote end, which can cause high inrush current when connected to the network and can thus also cause the operation of the built-in, instantaneous, overcurrent protection. Common base IED values for primary current (IBase), primary voltage (UBase) and primary power (SBase) are set in the global base values for settings function GBASVAL. GlobalBaseSel: This is used to select GBASVAL function for reference of base values. Operation: Set the protection to On/Off. OpMode: This parameter can be set to 2 out of 3 or 1 out of 3. The setting controls the minimum number of phase currents that must be larger than the set operate current IP>> for operation. Normally this parameter is set to 1 out of 3and will thus detect all fault types. If the protection is to be used mainly for multi phase faults, 2 out of 3 should be chosen. IP>>: Set operate current in % of IB. IP>>Max and IP>>Min should only be changed if remote setting of operation current level, IP>>, is used. The limits are used for decreasing the used range of the IP>> setting. If IP>> is set outside IP>>Max and IP>>Min, the closest of the limits to IP>> is used by the function. If IP>>Max is smaller than IP>>Min, the limits are swapped. StValMult: The set operate current can be changed by activation of the binary input ENMULT to the set factor StValMult. 6.1.3.1 Meshed network without parallel line M12915-9 v8 The following fault calculations have to be done for three-phase, single-phase-to- earth and two-phase-to-earth faults. With reference to Figure 29, apply a fault in B and then calculate the current through-fault phase current IfB. The calculation Section 6 1MRK 505 383-UEN A Current protection 72 Breaker protection REQ650 2.2 IEC Application manual

maximum source impedance values for ZB in order to get the maximum through fault current from A to B. ~ ~ ZA ZB Z L A B IED I fB Fault IEC09000022-1-en.vsd IEC09000022 V1 EN-US Figure 29: Through fault current from A to B: IfB Then a fault in A has to be applied and the through fault current IfA has to be calculated, Figure 30. In order to get the maximum through fault current, the minimum value for ZB and the maximum value for ZA have to be considered. IEC09000023-1-en.vsd ~ ~ ZA ZB Z L A B IED I fA Fault IEC09000023 V1 EN-US Figure 30: Through fault current from B to A: IfA The IED must not trip for any of the two through-fault currents. Hence the minimum theoretical current setting (Imin) will be: Imin MAX IfA IfB , ( ) ³ EQUATION78 V1 EN-US (Equation 11) A safety margin of 5% for the maximum protection static inaccuracy and a safety margin of 5% for the maximum possible transient overreach have to be introduced. An additional 20% is suggested due to the inaccuracy of the instrument transformers under transient conditions and inaccuracy in the system data. 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 73 Application manual

protection is then: min 1.3 sI I ³ × EQUATION79 V3 EN-US (Equation 12) The protection function can be used for the specific application only if this setting value is equal to or less than the maximum fault current that the IED has to clear, IF in Figure 31. IEC09000024-1-en.vsd ~ ~ ZA ZB Z L A B IED I F Fault IEC09000024 V1 EN-US Figure 31: Fault current: IF 100 Is IP IBase >>= × EQUATION1147 V3 EN-US (Equation 13) 6.1.3.2 Meshed network with parallel line M12915-34 v7 In case of parallel lines, the influence of the induced current from the parallel line to the protected line has to be considered. One example is given in Figure 32, where the two lines are connected to the same busbars. In this case the influence of the induced fault current from the faulty line (line 1) to the healthy line (line 2) is considered together with the two through fault currents IfA and IfB mentioned previously. The maximal influence from the parallel line for the IED in Figure 32 will be with a fault at the C point with the C breaker open. A fault in C has to be applied, and then the maximum current seen from the IED (IM ) on the healthy line (this applies for single-phase-to-earth and two-phase-to- earth faults) is calculated. Section 6 1MRK 505 383-UEN A Current protection 74 Breaker protection REQ650 2.2 IEC Application manual

Figure 32: Two parallel lines. Influence from parallel line to the through fault current: IM The minimum theoretical current setting for the overcurrent protection function (Imin) will be: Imin MAX IfA IfB IM , , ( ) ³ EQUATION82 V1 EN-US (Equation 14) Where IfA and IfB have been described in the previous paragraph. Considering the safety margins mentioned previously, the minimum setting (Is) for the instantaneous phase overcurrent protection 3-phase output is then: Is ³1.3·Imin EQUATION83 V2 EN-US (Equation 15) The protection function can be used for the specific application only if this setting value is equal or less than the maximum phase fault current that the IED has to clear. The IED setting value IP>> is given in percentage of the primary base current value, IBase. The value for IP>> is given from this formula: 100 Is IP IBase >>= × EQUATION1147 V3 EN-US (Equation 16) 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 75 Application manual

OC4PTOC SEMOD129998-1 v8 6.2.1 Identification M14885-1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI/IEEE C37.2 device number Directional phase overcurrent protection, four steps OC4PTOC TOC-REVA V2 EN-US 51_67 6.2.2 Application M15335-3 v9 Directional phase overcurrent protection, four steps OC4PTOC is used in several applications in the power system. Some applications are: • Short circuit protection of feeders in distribution and subtransmission systems. Normally these feeders have a radial structure. • Back-up short circuit protection of transmission lines. • Back-up short circuit protection of power transformers. • Short circuit protection of different kinds of equipment connected to the power system such as; shunt capacitor banks, shunt reactors, motors and others. • Back-up short circuit protection of power generators. In many applications several steps with different current pickup levels and time delays are needed. OC4PTOC can have up to four different, individually settable steps. The following options are possible: Non-directional / Directional function: In most applications the non-directional functionality is used. This is mostly the case when no fault current can be fed from the protected object itself. In order to achieve both selectivity and fast fault clearance, the directional function can be necessary. If VT inputs are not available or not connected, the setting parameter DirModex (x = step 1, 2, 3 or 4) shall be left to the default value Non-directional. Choice of time delay characteristics: There are several types of time delay characteristics available such as definite time delay and different types of inverse time delay characteristics. The selectivity between different overcurrent protections is normally enabled by co-ordination between the function time delays of the different protections. To enable optimal co-ordination between all overcurrent Section 6 1MRK 505 383-UEN A Current protection 76 Breaker protection REQ650 2.2 IEC Application manual

range of standardized inverse time characteristics are available for IEC and ANSI. It is also possible to tailor make the inverse time characteristic. Normally, it is required that the phase overcurrent protection shall reset as fast as possible when the current level gets lower than the operation level. In some cases some sort of delayed reset is required. Therefore, different kinds of reset characteristics can be used. For some protection applications, there can be a need to change the current pick-up level for some time. A typical case is when the protection will measure the current to a large motor. At the start up sequence of a motor the start current can be significantly larger than the rated current of the motor. Therefore, there is a possibility to give a setting of a multiplication factor to the current pick-up level. This multiplication factor is activated from a binary input signal to the function. Power transformers can have a large inrush current, when being energized. This phenomenon is due to saturation of the transformer magnetic core during parts of the period. There is a risk that inrush current will reach levels above the pick-up current of the phase overcurrent protection. The inrush current has a large 2nd harmonic content. This can be used to avoid unwanted operation of the protection function. Therefore, OC4PTOC has a possibility of 2nd harmonic restrain if the level of 2nd harmonic current reaches a value above a set percent of the fundamental current. The phase overcurrent protection is often used as a protection for two and three phase short circuits. In some cases, it is not wanted to detect single-phase earth faults by the phase overcurrent protection. This fault type is detected and cleared after operation of earth fault protection. Therefore, it is possible to make a choice how many phases, at minimum, that have to have current above the pick-up level, to enable operation. If set 1 of 3 it is sufficient to have high current in one phase only. If set 2 of 3 or 3 of 3 single-phase earth faults are not detected. 6.2.3 Setting guidelines IP14982-1 v1 M12982-4 v13 When inverse time overcurrent characteristic is selected, the operate time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero. The parameters for the directional phase overcurrent protection, four steps OC4PTOC are set via the local HMI or PCM600. The following settings can be done for OC4PTOC. 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 77 Application manual

and primary power (SBase) are set in the global base values for settings function GBASVAL. GlobalBaseSel: This is used to select GBASVAL function for reference of base values. MeasType: Selection of discrete Fourier filtered (DFT) or true RMS filtered (RMS) signals. RMS is used when the harmonic contents are to be considered, for example in applications with shunt capacitors. Operation: The protection can be set to On or Off. AngleRCA: Protection characteristic angle set in degrees. If the angle of the fault loop current has the angle RCA, the direction to the fault is forward. AngleROA: Angle value, given in degrees, to define the angle sector of the directional function, shown in Figure 33. StartPhSel: Number of phases, with high current, required for operation. The setting possibilities are: 1 out of 3, 2 out of 3 and 3 out of 3. The default setting is 1 out of 3. IMinOpPhSel: Minimum current setting level for releasing the directional start signals in % of IB. This setting should be less than the lowest step setting. The default setting is 7% of IB. 2ndHarmStab: Operate level of 2nd harmonic current restrain set in % of the fundamental current. The setting range is 5 - 100% in steps of 1%. The default setting is 20%. Section 6 1MRK 505 383-UEN A Current protection 78 Breaker protection REQ650 2.2 IEC Application manual

Figure 33: Directional function characteristic 1. RCA = Relay characteristic angle 2. ROA = Relay operating angle 3. Reverse 4. Forward 6.2.3.1 Settings for each step M12982-19 v10 x means step 1, 2, 3 and 4. DirModex: The directional mode of step x. Possible settings are Off/Non- directional/Forward/Reverse. Characteristx: Selection of time characteristic for step x. Definite time delay and different types of inverse time characteristics are available according to Table 9. 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 79 Application manual

Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time User Programmable ASEA RI RXIDG or RD (logarithmic) The different characteristics are described in Technical manual. Ix>: Operate phase current level for step x given in % of IB. Ix>Max and Ix>Min should only be changed if remote setting of operation current level, Ix>, is used. The limits are used for decreasing the used range of the Ix> setting. If Ix> is set outside Ix>Max and Ix>Min, the closest of the limits to Ix> is used by the function. If Ix>Max is smaller than Ix>Min, the limits are swapped. tx: Definite time delay for step x. The definite time tx is added to the inverse time when inverse time characteristic is selected. Note that the value set is the time between activation of the start and the trip outputs. kx: Time multiplier for inverse time delay for step x. IMinx: Minimum operate current in % of IB for all inverse time characteristics, below which no operation takes place. IMinx: Minimum operate current for step x in % of IBase. Set IMinx below Ix> for every step to achieve ANSI reset characteristic according to standard. If IMinx is set above Ix> for any step the ANSI reset works as if current is zero when current drops below IMinx. Section 6 1MRK 505 383-UEN A Current protection 80 Breaker protection REQ650 2.2 IEC Application manual

the inverse time characteristic might give a very short operation time. By setting this parameter the operation time of the step can never be shorter than the setting. Setting range: 0.000 - 60.000s in steps of 0.001s. IxMult: Multiplier for scaling of the current setting value. If a binary input signal ENMULTx (enableMultiplier) is activated the current operation level is increased by this setting constant. Setting range: 1.0-10.0 IMinx Operate time Current tx txMin IEC10000058 IEC10000058 V2 EN-US Figure 34: Minimum operate current and operate time for inverse time characteristics In order to fully comply with the definition of the curve, the setting parameter txMin shall be set to a value equal to the operating time of the selected inverse curve for twenty times the set current pickup value. Note that the operate time is dependent on the selected time multiplier setting kx. ResetTypeCrvx: The reset of the delay timer can be made as shown in Table 10. Table 10: Reset possibilities Curve name Curve index no. Instantaneous 1 IEC Reset (constant time) 2 ANSI Reset (inverse time) 3 The delay characteristics are described in Technical manual. There are some restrictions regarding the choice of the reset delay. For the definite time delay characteristics, the possible delay time setting instantaneous (1) and IEC (2 = set constant time reset). 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 81 Application manual

are available: instantaneous (1), IEC (2 = set constant time reset) and ANSI (3 = current dependent reset time). For IEC inverse time characteristics, the possible delay time settings are instantaneous (1) and IEC (2 = set constant time reset). For the customer tailor-made inverse time delay characteristics (type 17), all three types of reset time characteristics are available: instantaneous (1), IEC (2 = set constant time reset) and ANSI (3 = current dependent reset time). If the current- dependent type is used, settings pr, tr and cr must be given. tResetx: Constant reset time delay in seconds for step x. tPCrvx, tACrvx, tBCrvx, tCCrvx: These parameters are used by the customer to create the inverse time characteristic curve. See equation 17 for the time characteristic equation. For more information, refer to Technical manual. [ ] > p A t s B IxMult i C in = + × - æ ö ç ÷ ç ÷ ç ÷ æ ö ç ÷ ç ÷ è ø è ø EQUATION1261 V2 EN-US (Equation 17) tPRCrvx, tTRCrvx, tCRCrvx: These parameters are used by the customer to create the inverse reset time characteristic curve. For more information, refer to Technical manual. HarmRestrainx: Enables the block of step x from the harmonic restrain function (2nd harmonic). This function should be used when there is a risk of an unwanted trip caused by power transformer inrush currents. It can be set to Off/On. 6.2.3.2 Setting example GUID-20729467-24AB-42F0-9FD1-D2959028732E v1 Directional phase overcurrent protection, four steps can be used in different ways, depending on the application where the protection is used. A general description is given below. The operating current setting of the inverse time protection, or the lowest current step of the definite time protection, must be defined so that the highest possible load current does not cause protection operation. The protection reset current must also be considered so that a short peak of overcurrent does not cause the operation of a protection even when the overcurrent has ceased. This phenomenon is described in Figure 35. Section 6 1MRK 505 383-UEN A Current protection 82 Breaker protection REQ650 2.2 IEC Application manual

Line phase current Time (s) Reset current IEC05000203-en-2.vsd IEC05000203 V4 EN-US Figure 35: Operate and reset current for an overcurrent protection The lowest setting value can be written according to Equation 18. Imax Ipu 1.2 k ³ × EQUATION1262 V2 EN-US (Equation 18) where: 1.2 is a safety factor k is the reset ratio of the protection Imax is the maximum load current The load current up to the present situation can be found from operation statistics. The current setting must remain valid for several years. In most cases, the setting values are updated once every five years or less often. Investigate the maximum load current that the equipment on the line can withstand. Study components, such as line conductors, current transformers, circuit breakers, and disconnectors. The manufacturer of the equipment normally gives the maximum thermal load current of the equipment. The maximum load current on the line has to be estimated. There is also a demand that all faults within the zone that the protection shall cover must be detected by the phase overcurrent protection. The minimum fault current Iscmin to be detected by 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 83 Application manual

current setting can be written according to Equation 19. Ipu £ 0.7 Iscmin × EQUATION1263 V2 EN-US (Equation 19) where: 0.7 is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection. As a summary, the operating current shall be chosen within the interval stated in Equation 20. 1.2 Imax Ipu 0.7 Iscmin k × £ £ × EQUATION1264 V2 EN-US (Equation 20) The high current function of the overcurrent protection, which only has a short- delay trip time, must be given a current setting so that the protection is selective to other protection functions in the power system. It is desirable to have rapid tripping of faults within a large part of the power system to be protected by the protection (primary protected zone). A fault current calculation gives the largest current of faults, Iscmax, at the most remote part of the primary protected zone. The risk of transient overreach must be considered, due to a possible DC component of the short circuit current. The lowest current setting of the fastest stage can be written according to max 1.2 t sc Ihigh k I ³ × × EQUATION1265 V1 EN-US (Equation 21) where: 1.2 is a safety factor kt is a factor that takes care of the transient overreach due to the DC component of the fault current and can be considered to be less than 1.05 Iscmax is the largest fault current at a fault at the most remote point of the primary protection zone. The operate time of the phase overcurrent protection has to be chosen so that the fault time is short enough that the protected equipment will not be destroyed due to thermal overload while, at the same time, selectivity is assured. For overcurrent protection in a radial fed network, the time setting can be chosen in a graphical way. This is mostly used in the case of inverse time overcurrent protection. Figure 36 shows how the time-versus-current curves are plotted in a diagram. The time setting is chosen to get the shortest fault time with maintained selectivity. Section 6 1MRK 505 383-UEN A Current protection 84 Breaker protection REQ650 2.2 IEC Application manual

critical time difference. Time-current curves Fault Current 10 10 0.01 10000 en05000204.ai Str tfunc1 n n tfunc2 Trip time n IEC05000204 V2 EN-US Figure 36: Fault time with maintained selectivity The operation time can be set individually for each overcurrent protection. To assure selectivity between different protection functions in the radial network, there has to be a minimum time difference Dt between the time delays of two protections. To determine the shortest possible time difference, the operation time of the protection, the breaker opening time and the protection resetting time must be known. These time delays can vary significantly between different protective equipment. The following time delays can be estimated: Protection operation time: 15-60 ms Protection resetting time: 15-60 ms Breaker opening time: 20-120 ms 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 85 Application manual

Assume two substations A and B directly connected to each other via one line, as shown in the Figure 37. Consider a fault located at another line from the station B. The fault current to the overcurrent protection of IED B1 has a magnitude so that the overcurrent protection will start and subsequently trip, and the overcurrent protection of IED A1 must have a delayed operation in order to avoid maloperation. The sequence of events during the fault can be described using a time axis shown in Figure 37. I> I> A1 B1 Feeder Time axis t=0 t=t2 t=t3 The fault occurs B1 trips and A1 starts Breaker at B1 opens =IEC05000205=2=en=Original.vsd Fault t=t4 Protection A1 resets t=t1 B1 and A1 start IEC05000205 V2 EN-US Figure 37: Sequence of events during fault where: t=0 is when the fault occurs t=t1 is when protection IED B1 and protection IED A1 start t=t2 is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker. t=t3 is when the circuit breaker at IED B1 opens. The circuit breaker opening time is t3 - t2 t=t4 is when the overcurrent protection at IED A1 resets. The protection resetting time is t4 - t3. To ensure that the overcurrent protection at IED A1 is selective to the overcurrent protection at IED B1, the minimum time difference must be larger than the time t3. There are uncertainties in the values of protection operation time, breaker opening time and protection resetting time. Therefore a safety margin has to be included. With normal values the needed time difference can be calculated according to Equation 22. Section 6 1MRK 505 383-UEN A Current protection 86 Breaker protection REQ650 2.2 IEC Application manual

(Equation 22) where it is considered that: the operate time of overcurrent protection B1 is 40 ms the breaker open time is 100 ms the resetting time of protection A1 is 40 ms and the additional margin is 40 ms 6.3 Instantaneous residual overcurrent protection EFPIOC IP14508-1 v3 6.3.1 Identification M14887-1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI/IEEE C37.2 device number Instantaneous residual overcurrent protection EFPIOC IN>> IEF V1 EN-US 50N 6.3.2 Application M12699-3 v5 In many applications, when fault current is limited to a defined value by the object impedance, an instantaneous earth-fault protection can provide fast and selective tripping. The Instantaneous residual overcurrent EFPIOC, which can operate in 15 ms (50 Hz nominal system frequency) for faults characterized by very high currents, is included in the IED. 6.3.3 Setting guidelines IP14985-1 v1 M12762-44 v2 M12762-4 v4 The parameters for the Instantaneous residual overcurrent protection EFPIOC are set via the local HMI or PCM600. Some guidelines for the choice of setting parameter for EFPIOC is given. M12762-6 v8 Common base IED values for primary current (IBase), primary voltage (UBase) and primary power (SBase) are set in the global base values for settings function GBASVAL. 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 87 Application manual

values. The basic requirement is to assure selectivity, that is EFPIOC shall not be allowed to operate for faults at other objects than the protected object (line). For a normal line in a meshed system single phase-to-earth faults and phase-to- phase-to-earth faults shall be calculated as shown in Figure 38 and Figure 39. The residual currents (3I0) to the protection are calculated. For a fault at the remote line end this fault current is IfB. In this calculation the operational state with high source impedance ZA and low source impedance ZB should be used. For the fault at the home busbar this fault current is IfA. In this calculation the operational state with low source impedance ZA and high source impedance ZB should be used. ~ ~ ZA ZB Z L A B IED I fB Fault IEC09000022-1-en.vsd IEC09000022 V1 EN-US Figure 38: Through fault current from A to B: IfB IEC09000023-1-en.vsd ~ ~ ZA ZB Z L A B IED I fA Fault IEC09000023 V1 EN-US Figure 39: Through fault current from B to A: IfA The function shall not operate for any of the calculated currents to the protection. The minimum theoretical current setting (Imin) will be:   Im fA, fB in MAX I I  EQUATION284 V2 EN-US (Equation 23) Section 6 1MRK 505 383-UEN A Current protection 88 Breaker protection REQ650 2.2 IEC Application manual

5% for maximum possible transient overreach have to be introduced. An additional 20% is suggested due to inaccuracy of instrument transformers under transient conditions and inaccuracy in the system data. The minimum primary current setting (Is) is: Is = 1.3 × Imin EQUATION285 V3 EN-US (Equation 24) In case of parallel lines with zero sequence mutual coupling a fault on the parallel line, as shown in Figure 40, should be calculated. IEC09000025-1-en.vsd ~ ~ ZA ZB ZL1 A B I M Fault IED ZL2 M C Line 1 Line 2 IEC09000025 V1 EN-US Figure 40: Two parallel lines. Influence from parallel line to the through fault current: IM The minimum theoretical current setting (Imin) will in this case be: Imin M AX IfA IfB IM , , ( ) ³ EQUATION287 V1 EN-US (Equation 25) Where: IfA and IfB have been described for the single line case. Considering the safety margins mentioned previously, the minimum setting (Is) is: Is = 1.3 × Imin EQUATION288 V3 EN-US (Equation 26) The IED setting value IN>> is given in percent of the primary base current value, IBase. The value for IN>> is given by the formula: 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 89 Application manual

(Equation 27) Transformer inrush current shall be considered. The setting of the protection is set as a percentage of the base current (IBase). Operation: set the protection to On or Off. IN>>: Set operate current in % of IB. IN>>Max and IN>>Min should only be changed if remote setting of operation current level, IN>>, is used. The limits are used for decreasing the used range of the IN>> setting. If IN>> is set outside IN>>Max and IN>>Min, the closest of the limits to IN>> is used by the function. If IN>>Max is smaller than IN>>Min, the limits are swapped. StValMult: The set operate current can be changed by activation of the binary input ENMULT to the set factor StValMult. 6.4 Directional residual overcurrent protection, four steps EF4PTOC IP14509-1 v8 6.4.1 Identification M14881-1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI/IEEE C37.2 device number Directional residual overcurrent protection, four steps EF4PTOC 4(IN>) 4 alt 4 TEF-REVA V2 EN-US 51N_67N 6.4.2 Setting guidelines IP14988-1 v1 M15282-3 v11 When inverse time overcurrent characteristic is selected, the operate time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero. The parameters for the four step residual overcurrent protection are set via the local HMI or PCM600. The following settings can be done for the function. Section 6 1MRK 505 383-UEN A Current protection 90 Breaker protection REQ650 2.2 IEC Application manual

and primary power (SBase) are set in the global base values for settings function GBASVAL. GlobalBaseSel: This is used to select GBASVAL function for reference of base values. SeqTypeUPol: This is used to select the type of voltage polarising quantity i.e. Zero seq and Neg seq for direction detection. SeqTypeIPol: This is used to select the type of current polarising quantity i.e. Zero seq and Neg seq for direction detection. SeqTypeIDir: This is used to select the type of operating current quantity i.e. Zero seq and Neg seq for direction detection. 6.4.2.1 Common settings for all steps M15282-81 v10 AngleRCA: Relay characteristic angle given in degree. This angle is defined as shown in Figure 41. The angle is defined positive when the residual current lags the reference voltage (Upol = 3U0 or U2) Upol = -3U0 or IN>Dir RCA Operation -3U2 IEC05000135-5-en.vsdx IEC05000135 V5 EN-US Figure 41: Relay characteristic angle given in degree In a normal transmission network a normal value of RCA is about 65°. The setting range is -180° to +180°. polMethod: Defines if the directional polarization is from 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 91 Application manual

• Current (3I0 · ZNpol or 3I2 ·ZNpol where ZNpol is RNpol + jXNpol), or • both currents and voltage, Dual (dual polarizing, (3U0 + 3I0 · ZNpol) or (U2 + I2 · ZNpol)). Normally voltage polarizing from the internally calculated residual sum or an external open delta is used. Current polarizing is useful when the local source is strong and a high sensitivity is required. In such cases the polarizing voltage (3U0) can be below 1% and it is then necessary to use current polarizing or dual polarizing. Multiply the required set current (primary) with the minimum impedance (ZNpol) and check that the percentage of the phase-to-earth voltage is definitely higher than 1% (minimum 3U0>UPolMin setting) as a verification. RNPol, XNPol: The zero-sequence source is set in primary ohms as base for the current polarizing. The polarizing voltage is then achieved as 3I0 · ZNpol. The ZNpol can be defined as (ZS1-ZS0)/3, that is the earth return impedance of the source behind the protection. The maximum earth-fault current at the local source can be used to calculate the value of ZN as U/(√3 · 3I0) Typically, the minimum ZNPol (3 · zero sequence source) is set. The setting is in primary ohms. When the dual polarizing method is used, it is important that the setting INx> or the product 3I0 · ZNpol is not greater than 3U0. If so, there is a risk for incorrect operation for faults in the reverse direction. IPolMin: is the minimum earth-fault current accepted for directional evaluation. For smaller currents than this value, the operation will be blocked. A typical setting is 5-10% of IB. UPolMin: Minimum polarization (reference) polarizing voltage for the directional function, given in % of UBase/√3. IN>Dir: Operate residual current release level in % of IB for directional comparison scheme. The setting is given in % of IB and must be set below the lowest INx> setting, set for the directional measurement. The output signals, STFW and STRV can be used in a teleprotection scheme. The appropriate signal should be configured to the communication scheme block. 6.4.2.2 2nd harmonic restrain M15282-90 v6 If a power transformer is energized there is a risk that the current transformer core will saturate during part of the period, resulting in a transformer inrush current. This will give a declining residual current in the network, as the inrush current is deviating between the phases. There is a risk that the residual overcurrent function will give an unwanted trip. The inrush current has a relatively large ratio of 2nd harmonic component. This component can be used to create a restrain signal to prevent this unwanted function. Section 6 1MRK 505 383-UEN A Current protection 92 Breaker protection REQ650 2.2 IEC Application manual

protection. Here the 2nd harmonic restrain can prevent unwanted operation as well. 2ndHarmStab: The rate of 2nd harmonic current content for activation of the 2nd harmonic restrain signal. The setting is given in % of the fundamental frequency residual current. 6.4.2.3 Parallel transformer inrush current logic M15282-97 v6 In case of parallel transformers there is a risk of sympathetic inrush current. If one of the transformers is in operation, and the parallel transformer is switched in, the asymmetric inrush current of the switched-in transformer will cause partial saturation of the transformer already in service. This is called transferred saturation. The 2nd harmonic of the inrush currents of the two transformers will be in phase opposition. The summation of the two currents will thus give a small 2nd harmonic current. The residual fundamental current will however be significant. The inrush current of the transformer in service before the parallel transformer energizing, will be a little delayed compared to the first transformer. Therefore, we will have high 2nd harmonic current initially. After a short period this current will however be small and the normal 2nd harmonic blocking will reset. en05000136.vsd Power System IN> IN> IEC05000136 V1 EN-US Figure 42: Application for parallel transformer inrush current logic If the BlkParTransf function is activated, the 2nd harmonic restrain signal will latch as long as the residual current measured by the relay is larger than a selected step current level. Assume that step 4 is chosen to be the most sensitive step of the four step residual overcurrent protection function EF4PTOC. The harmonic restrain blocking is enabled for this step. Also the same current setting as this step is chosen for the blocking at parallel transformer energizing. The settings for the parallel transformer logic are described below. BlkParTransf: This is used to On blocking at energising of parallel transformers. UseStartValue: Gives which current level should be used for the activation of the blocking signal. This is given as one of the settings of the steps: Step 1/2/3/4. Normally, the step having the lowest operation current level should be set. 1MRK 505 383-UEN A Section 6 Current protection Breaker protection REQ650 2.2 IEC 93 Application manual

M15282-106 v4 In case of energizing a faulty object there is a risk of having a long fault clearance time, if the fault current is too small to give fast operation of the protection. The switch on to fault function can be activated from auxiliary signals from the circuit breaker, either the close command or the open/close position (change of position). This logic can be used to issue a fast trip if one breaker pole does not close properly at a manual or automatic closing. SOTF and under time are similar functions to achieve fast clearance at asymmetrical closing based on requirements from different utilities. The function is divided into two parts. The SOTF function will give operation from step 2 or 3 during a set time after change in the position of the circuit breaker. The SOTF function has a set time delay. The under time function, which has 2nd harmonic restrain blocking, will give operation from step 4. The 2nd harmonic restrain will prevent unwanted function in case of transformer inrush current. The under time function has a set time delay. Below the settings for switch on to fault logics are described. SOTF: This parameter can be set: Off/SOTF/Under Time/SOTF+Under Time. ActivationSOTF: This setting will select the signal to activate SOTF function; CB position open/CB position closed/CB close command. StepForSOTF: If this parameter is set on step 3, the step 3 start signal will be used as current set level. If set on step 2, the step 2 start signal will be used as current set level. HarmBlkSOTF: This is used to On/Off harmonic restrain during SOTF conditions. tSOTF: Time delay for operation of the SOTF function. The setting range is 0.000 - 60.000 s in step of 0.001 s. The default setting is 0.100 s t4U: Time interval when the SOTF function is active after breaker closing. The setting range is 0.000 - 60.000 s in step of 0.001 s. The default setting is 1.000 s. ActUnderTime: Describes the mode to activate the sensitive undertime function. The function can be activated by Circuit breaker position (change) or Circuit breaker command. tUnderTime: Time delay for operation of the sensitive undertime function. The setting range is 0.000 - 60.000 s in step of 0.001 s. The default setting is 0.300 s 6.4.2.5 Settings for each step (x = 1, 2, 3 and 4) M15282-9 v12 Operation: Sets the protection to On or Off. Section 6 1MRK 505 383-UEN A Current protection 94 Breaker protection REQ650 2.2 IEC Application manual