sprecon-e-p94-dd 6, -dde 6, -ddey 6 - hf...sprecon-e-p94-dd 6, -dde 6, -ddey 6 one-box solutions...

© Sprecher Automation 2009

SPRECON-E-P94-DD 6, -DDE 6, -DDEY 6 ONE-BOX SOLUTIONS PROTECTION AND CONTROL DISTANCE PROTECTION

User manual for the protection part Structure version 5601

94.2.903.15en from software version 1.01

2009-03-03 Issue B

Table of Contents

SPRECON-E-Pxx-DDx6 User Manual Protection 5601/B 2 Sprecher Automation Deutschland GmbH

Table of Contents 0 Changes since structure version 5600............................................................................................... 11 1 Preface ............................................................................................................................................... 12 2 Application and function scope........................................................................................................... 12

2.1 Application ................................................................................................................................... 12 2.2 Function Scope ............................................................................................................................ 14

3 Technical data .................................................................................................................................... 20 3.1 EC Declaration of conformity ....................................................................................................... 20 3.2 Conditions for application............................................................................................................. 20 3.3 Input circuits................................................................................................................................. 20 3.4 Output circuits .............................................................................................................................. 22 3.5 Communication interfaces ........................................................................................................... 23 3.6 Design of the device .................................................................................................................... 24 3.7 Set values and ranges ................................................................................................................. 24 3.8 Performance characteristics ........................................................................................................ 24

3.8.1 Measuring ranges ................................................................................................................. 25 3.8.2 Accuracy................................................................................................................................ 25 3.8.3 Influencing variables ............................................................................................................. 26

3.9 Operating measurands ................................................................................................................ 26 3.10 Statistic values ........................................................................................................................... 26 3.11 Event memory............................................................................................................................ 27 3.12 Disturbance data memory.......................................................................................................... 27 3.13 Routine and type testing ............................................................................................................ 27

4 Design................................................................................................................................................. 29 4.1 Mechanical construction .............................................................................................................. 29 4.2 Control panel................................................................................................................................ 29 4.3 Terminals ..................................................................................................................................... 29

5 Functions ............................................................................................................................................ 30 5.1 General function........................................................................................................................... 30 5.2 Switching device On and Off ....................................................................................................... 31 5.3 Setting of Earth Factor ................................................................................................................. 32

5.3.1 Definition of the Earth Factor ................................................................................................ 32 5.3.2 Calculation of the Earth Factor with given system data........................................................ 33 5.3.3 Discussion of Earth Factor application.................................................................................. 34

5.4 Direction Decision ........................................................................................................................ 35 5.4.1 Short-Circuit Direction for distance protection (SCD) ........................................................... 35 5.4.2 Short-Circuit Direction for Overcurrent-Time Protection OTP............................................... 37 5.4.3 Earth Short-Circuit Direction ESCD (Zero Power Direction)................................................. 38

5.4.3.1 SDLRE Automatic within the non-earthed system ......................................................... 41 5.5 Distance Protection...................................................................................................................... 45

5.5.1 Startings of Distance Protection............................................................................................ 45 5.5.1.1 Current Starting, Voltage Dependent Current Starting (U-) I ......................................... 45

5.5.1.1.1 Current Starting I>> ................................................................................................. 46 5.5.1.1.2 Voltage Dependent Current Starting U-I.................................................................. 47

5.5.1.2 Angular-Dependent Polygonal Impedance Starting (Z<) ............................................... 51 5.5.2 Loop Determination............................................................................................................... 54

5.5.2.1 Earth Short Circuit Detection – Earth Fault Criterion (EFC)........................................... 54 5.5.2.1.1 Earth-Current Starting IE>EFC................................................................................. 54 5.5.2.1.2 Displacement Voltage Starting UNE>EFC ................................................................ 58

5.5.2.2 Suppression of Single-Pole Starts at Begin of an Earth Fault – t1p ................................ 59 5.5.2.3 Loop Selection................................................................................................................ 60

5.5.2.3.1 Selection Programs for Earthed Neutral Systems ................................................... 61 5.5.2.3.2 Selection Programs for Not Earthed Neutral Systems ............................................ 62

5.5.3 Distance Module ................................................................................................................... 64 5.5.3.1 Distance zones Z1,t1; Z2,t2 to Z4,t4 .............................................................................. 65 5.5.3.2 Distance zone Z1x,t1x .................................................................................................... 65 5.5.3.3 Directional Backup Time t5 and Time Limit t6................................................................ 66 5.5.3.4 Characteristic of the Distance Zones ............................................................................. 66

5.6 Overcurrent Time Protection (Emergency-)OTP/IDMT ............................................................... 69 5.6.1 Emergency overcurrent time protection (OTP) ..................................................................... 70

Table of Contents


5.6.2 Phase overcurrent time protection ........................................................................................ 71 5.6.2.1 Current starts IL>, IL>>, IL>>> and IL>>>> ...................................................................... 72 5.6.2.2 Timers tIL>, tIL>>, tIL>>>, tIL>>>>, tL>....................................................................................... 73

5.6.3 Earth overcurrent time protection.......................................................................................... 79 5.6.3.1 Earth fault starts IE>, IE>>, IE>>>, IE>>>>....................................................................... 80 5.6.3.2 Biasing IE> start .............................................................................................................. 81 5.6.3.3 Earth fault current timers tIE>, tIE>>, tIE>>>, tIE>>>>, tE> ....................................................... 82 5.6.3.4 Treatment of Intermitting Earth-faults............................................................................. 83

5.6.4 Behaviour with the distance protection OFF / direction decisions OFF................................ 87 5.6.4.1 Behaviour in earthed systems ........................................................................................ 87 5.6.4.2 Behaviour within the compensated or isolated system .................................................. 88

5.7 Earth-fault detection (EF)............................................................................................................. 89 5.7.1 Connecting an external earth-fault directional relay ............................................................. 91 5.7.2 Wattmetric earth fault direction decision, compensated system (not DD6) .......................... 91 5.7.3 Wattmetric earth fault direction decision, isolated system (not DD6) ................................... 96

5.8 Switch-On Protection (SOP) ........................................................................................................ 99 5.8.1 Switch-On Protection in the case of use of distance starts................................................... 99 5.8.2 Switch-on protection in case of use of the overcurrent time protection .............................. 100

5.9 Monitoring of negative sequence I (load unbalance, unbalance) .............................................. 107 5.10 Inrush restraint (harmonic restraint)......................................................................................... 109 5.11 Auto-Reclose (AR) ................................................................................................................... 112

5.11.1 AR on inhomogeneous line............................................................................................... 120 5.11.2 Signalling the circuit-breaker tripping................................................................................ 121

5.12 Teleprotection method (TP) ..................................................................................................... 123 5.12.1 Two-wire connection (three-wire connection) ................................................................... 126 5.12.2 Reverse interlock function and H2 logic............................................................................ 130

5.12.2.1 Reverse interlocking ................................................................................................... 130 5.12.2.2 H2 - Logic ................................................................................................................... 133

5.12.2.2.1 Method of action of the H2 logic .......................................................................... 133 5.12.2.2.2 Wired connection of the H2 logic ......................................................................... 135

5.12.3 Unidirectional operation .................................................................................................... 139 5.12.3.1 Unidirectional operation - transmitter ......................................................................... 139 5.12.3.2 Unidirectional operation - receiver.............................................................................. 140

5.12.4 Permissive overreach protection (POP, POTT)................................................................ 142 5.12.5 Blocking overreach protection (BOP)................................................................................ 145 5.12.6 Underreach protection – permissive (PUP, PUTT) and accelerated (AUP) ..................... 147 5.12.7 Intertripping at no start for weak infeeds........................................................................... 149

5.13 Voltage-Time Protection .......................................................................................................... 150 5.13.1 Overvoltage protection U>, U>> ....................................................................................... 151 5.13.2 Undervoltage protection U<, U<< ..................................................................................... 152 5.13.3 Displacement voltage protection UNE>, UNE>> (U4>, U4>>) .............................................. 153

5.14 Frequency protection ............................................................................................................... 155 5.15 Power protection ...................................................................................................................... 157 5.16 Overload Protection (thermal replica) ...................................................................................... 160

5.16.1 Level after supply interruption or operation....................................................................... 163 5.17 Monitoring of temperature limits (option) ................................................................................. 169 5.18 Reclosing lockout..................................................................................................................... 172 5.19 Group "General start" in the protection modules ..................................................................... 174 5.20 TRIP command (CB TRIP) ...................................................................................................... 175 5.21 Circuit-breaker failure protection (CBF) ................................................................................... 177 5.22 Fault location (FL) .................................................................................................................... 180 5.23 Current Annunciation I>an....................................................................................................... 182 5.24 Synchrocheck and Synchrocheck AR (only DDEY6) .............................................................. 184

5.24.1 Voltage check.................................................................................................................... 186 5.24.2 Synchronism check ........................................................................................................... 187 5.24.3 Adaptation of phase differences US1 - US2 and CB inherent delay ................................... 188 5.24.4 Blockage and bypassing the synchronization................................................................... 188 5.24.5 Signals, events and measurands of the synchrocheck..................................................... 189 5.24.6 Interaction with substation control..................................................................................... 189 5.24.7 Interaction with AR ............................................................................................................ 190

Table of Contents


5.25 Pulse shaper stage .................................................................................................................. 191 5.25.1 Example: Using I/O-coupling for AR in case of two circuit breakers................................. 195

5.26 Trip circuit supervision ............................................................................................................. 196 5.26.1 Using non-linear binary inputs .......................................................................................... 196 5.26.2 Using linear binary inputs.................................................................................................. 198

5.27 Event logging ........................................................................................................................... 200 5.28 Disturbance Record ................................................................................................................. 200

5.28.1 Additional causes for starting a record.............................................................................. 202 5.28.2 Additional binary tags in the record................................................................................... 202

5.29 Supervision and test functions................................................................................................. 203 5.29.1 Measurand check (MCHK)................................................................................................ 203

5.29.1.1 Signal of fuse voltage transformer's miniature circuit-breaker ................................... 204 5.29.1.2 Detection of the three-phase voltage failure............................................................... 205 5.29.1.3 Voltage unbalance without current unbalance ........................................................... 206 5.29.1.4 Detection of UNE without general start or earth fault................................................... 207 5.29.1.5 Monitoring of rotary voltage field ................................................................................ 208 5.29.1.6 Monitoring of current unbalance................................................................................. 209 5.29.1.7 IE start without UNE> or general starting ..................................................................... 209 5.29.1.8 Comparison of the current total with the measured IE ................................................ 210 5.29.1.9 Imin ............................................................................................................................. 212 5.29.1.10 Umin ......................................................................................................................... 212

5.29.2 Self-monitoring and start of protector................................................................................ 212 5.29.2.1 Alarms......................................................................................................................... 212 5.29.2.2 Malfunctions ............................................................................................................... 213 5.29.2.3 Measures to be taken in case of "Alarm" and "Malfunction“ ...................................... 214

5.29.3 Test menu ......................................................................................................................... 214 5.29.3.1 Start disturbance record ............................................................................................. 215 5.29.3.2 Loop measurands....................................................................................................... 215 5.29.3.3 Earth fault test ............................................................................................................ 216 5.29.3.4 Activating and deactivating information blocking........................................................ 216 5.29.3.5 Resetting the fault and grid fault number ................................................................... 216 5.29.3.6 Resetting the statistic values...................................................................................... 216 5.29.3.7 Test of inputs .............................................................................................................. 217 5.29.3.8 Relay test.................................................................................................................... 217 5.29.3.9 Temperature sensor of board PT100 ......................................................................... 218 5.29.3.10 CB test as trial AR and trial TRIP ............................................................................. 218 5.29.3.11 Resetting the thermal level (overload protection)..................................................... 219 5.29.3.12 Setting the overload protection to a thermal level .................................................... 219 5.29.3.13 Overload test with TRIP............................................................................................ 220 5.29.3.14 Telegram test............................................................................................................ 221 5.29.3.15 Software Reset ......................................................................................................... 221 5.29.3.16 Write default ............................................................................................................. 222

5.29.3.16.1 Password ........................................................................................................... 222 5.29.3.16.2 Identification....................................................................................................... 222 5.29.3.16.3 Setting set .......................................................................................................... 222 5.29.3.16.4 Menu entry "all“ .................................................................................................. 222

5.29.4 LED test............................................................................................................................. 223 5.30 Setting set ................................................................................................................................ 224

5.30.1 Characteristic Sets ............................................................................................................ 225 5.31 Inputs ....................................................................................................................................... 227

5.31.1 Use of digital optocoupler inputs (DI)................................................................................ 227 5.31.1.1 Remote reset LED and report..................................................................................... 227 5.31.1.2 Test mode................................................................................................................... 227 5.31.1.3 Information blocking ................................................................................................... 227 5.31.1.4 Phase rotation change via input signal....................................................................... 228

5.31.2 Using virtual inputs (vDI) ................................................................................................... 228 5.31.3 Using the "inputs 1...4“ ...................................................................................................... 228 5.31.4 Processing binary input signals ........................................................................................ 229 5.31.5 Recommendations regarding the infeed of the input signals............................................ 230 5.31.6 Mathematical preprocessing of temperature inputs (optional).......................................... 231

Table of Contents


5.32 Data outputs............................................................................................................................. 232 5.32.1 Operating measurand display ........................................................................................... 232 5.32.2 Report................................................................................................................................ 236 5.32.3 Statistic values .................................................................................................................. 237 5.32.4 LED ................................................................................................................................... 238 5.32.5 Relays ............................................................................................................................... 239 5.32.6 Virtual digital inputs (vDI) .................................................................................................. 240

5.33 Remote Parameterization ........................................................................................................ 241 5.34 Real-time clock, time synchronization ..................................................................................... 241

6 Assembly and connection................................................................................................................. 242 6.1 Unpacking the devices............................................................................................................... 242 6.2 Device identification ................................................................................................................... 242 6.3 Requirements regarding the installation location....................................................................... 242 6.4 Assembly ................................................................................................................................... 242 6.5 Connection of the device ........................................................................................................... 243

6.5.1 Connecting the Control Panel ............................................................................................. 243 6.5.2 Connection to transformers' secondary circuits .................................................................. 244 6.5.3 Connection of the signal circuits ......................................................................................... 245 6.5.4 PE conductor....................................................................................................................... 245 6.5.5 Isolation ............................................................................................................................... 245

6.6 Connection of a PC.................................................................................................................... 245 6.7 Connection of telecontrol and substation control systems ........................................................ 245

7 Operation of the protection device ................................................................................................... 246 7.1 Control panel.............................................................................................................................. 246 7.2 PC-aided operator control.......................................................................................................... 246

7.2.1 Interface .............................................................................................................................. 246 7.2.2 COMM-3 operating software............................................................................................... 247

8 Setting............................................................................................................................................... 248 8.1 Overview of the available submenus for protector setting......................................................... 251 8.2 Settings ...................................................................................................................................... 253

8.2.1 Category “Firmware adaptation“ ......................................................................................... 253 8.2.2 Category “Equipment adaptation“ ....................................................................................... 253

8.2.2.1 Device Adaptation: Temperature recording.................................................................. 253 8.2.2.2 CB Adaptation: CB manual CLOSE and CB CLOSE issued by substation control ..... 253 8.2.2.3 CB Adaptation: CB ready to trip and CB tripping alarm interrupted............................. 253 8.2.2.4 CB Adaptation: Trip circuit supervision ........................................................................ 253 8.2.2.5 Transformer adaptation: Rated currents and rated voltages........................................ 253 8.2.2.6 Transformer adaptation: Current transformer earthing ................................................ 254 8.2.2.7 Transformer adaptation: fuse voltage transformer ....................................................... 254 8.2.2.8 Transformer adaptation: P, Q display inverted............................................................. 254 8.2.2.9 Transformer adaptation: Using the voltage transformer U4 ......................................... 254 8.2.2.10 Characteristic set: number of characteristic sets and selection thereof..................... 255

8.2.3 Category “System adaptation“ ............................................................................................ 255 8.2.3.1 System neutral.............................................................................................................. 255 8.2.3.2 System adaptation: SDLRE Automatic......................................................................... 255 8.2.3.3 System adaptation: Earth factor ................................................................................... 255 8.2.3.4 Phase rotation .............................................................................................................. 256

8.2.4 Category “Protection modules“ ........................................................................................... 256 8.2.5 Category “General“ ............................................................................................................. 256

8.2.5.1 Device On/Off ............................................................................................................... 256 8.2.5.2 Relays........................................................................................................................... 256 8.2.5.3 Optocoupler .................................................................................................................. 257 8.2.5.4 Virtual Inputs................................................................................................................. 257 8.2.5.5 Disturbance Record...................................................................................................... 257 8.2.5.6 Moreover: Language switching..................................................................................... 257

8.2.6 Category “Communication and Substation Control“ ........................................................... 257 8.2.6.1 Communication............................................................................................................. 257

8.2.6.1.1 Baudrate and parity of the RS232 interface “SERV“ ............................................. 257 8.2.6.1.2 Baudrate and parity of the IEC 60850-5-103 interface .......................................... 258 8.2.6.1.3 Device address ...................................................................................................... 258

Table of Contents


8.2.6.2 Substation Control ........................................................................................................ 258 8.2.6.2.1 Remote setting....................................................................................................... 258 8.2.6.2.2 Command blocking ................................................................................................ 258 8.2.6.2.3 Information blocking............................................................................................... 258 8.2.6.2.4 Transfer of CB Close from the substation control.................................................. 258

8.3 Output Configuration.................................................................................................................. 259 8.3.1 LEDs.................................................................................................................................... 259 8.3.2 Relays ................................................................................................................................. 260 8.3.3 Assignment of Output Commands to Virtual Digital Inputs (vDI) ........................................ 261

8.4 Configuration of Digital Inputs (DI)............................................................................................. 263 8.5 Configuration of analogue temperature sensors (module PT100) ............................................ 265 8.6 Operator control in main menu, resets ...................................................................................... 266

8.6.1 Reset LED and report ......................................................................................................... 266 8.6.2 Reset RC lockout (reclosing lockout).................................................................................. 266 8.6.3 Clear Event-Memory ........................................................................................................... 266 8.6.4 Identification ........................................................................................................................ 266 8.6.5 Protection restart and software reset .................................................................................. 267 8.6.6 Date/Time............................................................................................................................ 267 8.6.7 Password............................................................................................................................. 267 8.6.8 Further resets...................................................................................................................... 268

8.7 Determination of setting data, configuration and connection..................................................... 268 9 Readout ............................................................................................................................................ 269

9.1 Operating measurand display.................................................................................................... 271 9.2 Displaying the current statistic values........................................................................................ 271 9.3 Displaying the event memory .................................................................................................... 271 9.4 Display of device identification................................................................................................... 272 9.5 Display of device type (firmware adaptation)............................................................................. 272 9.6 Display of device address.......................................................................................................... 273

10 Start-up........................................................................................................................................... 274 10.1 Preparations............................................................................................................................. 274 10.2 Checking the terminals ............................................................................................................ 275

10.2.1 Checking the nominal values of the protector................................................................... 275 10.2.2 Checking the power supply terminal ................................................................................. 275 10.2.3 Checking the current transformer terminals...................................................................... 275 10.2.4 Checking the voltage transformer terminals ..................................................................... 275 10.2.5 Checking the signal circuits' terminal connections............................................................ 275

10.3 Protection check ...................................................................................................................... 277 10.3.1 Applying the auxiliary voltage ........................................................................................... 277 10.3.2 Checking the settings and the configuration..................................................................... 277 10.3.3 LED test............................................................................................................................. 277 10.3.4 Test of the communication connections............................................................................ 277 10.3.5 Check date and time ......................................................................................................... 278 10.3.6 Check with secondary values............................................................................................ 278

10.3.6.1 Checking the input signals.......................................................................................... 278 10.3.6.2 Checking the output relays ......................................................................................... 279 10.3.6.3 Connecting the current and voltage measurement .................................................... 279 10.3.6.4 Checking the effect of the fuse voltage transformer................................................... 279 10.3.6.5 Checking the current and voltage starts..................................................................... 279 10.3.6.6 Checking impedance starting Z<................................................................................ 280 10.3.6.7 Checking the distance zones...................................................................................... 281 10.3.6.8 Checking the direction decision.................................................................................. 282 10.3.6.9 Checking the power pickup value (earth fault) ........................................................... 283 10.3.6.10 Checking the output signal circuits........................................................................... 283 10.3.6.11 Check of CB TRIP command ................................................................................... 284 10.3.6.12 Checking the pulse shaper stage ............................................................................. 284 10.3.6.13 Checking the teleprotection function ........................................................................ 284

10.3.6.13.1 Reverse Interlock Function ................................................................................ 284 10.3.6.13.2 H2 Logic............................................................................................................. 284 10.3.6.13.3 Two-wire comparison......................................................................................... 285 10.3.6.13.4 Unidirectional operation ..................................................................................... 285

Table of Contents


10.3.6.13.5 POP mode / BOP mode..................................................................................... 285 10.3.6.14 Checking the AR....................................................................................................... 285 10.3.6.15 Checking the thermal replica.................................................................................... 286 10.3.6.16 Check of temperature acquisition PT100 ................................................................. 287 10.3.6.17 Checking the switch-on protection ........................................................................... 287 10.3.6.18 Checking the voltage protection ............................................................................... 287 10.3.6.19 Checking the frequency protection........................................................................... 288 10.3.6.20 Checking the power protection................................................................................. 288 10.3.6.21 Checking the circuit-breaker failure protection......................................................... 288

10.3.7 Check with primary values ................................................................................................ 289 10.3.7.1 Checking the rotating field and balance ..................................................................... 289 10.3.7.2 Checking the operating measurand display ............................................................... 289 10.3.7.3 Checking the direction and other ratings.................................................................... 290 10.3.7.4 Checking the earth fault direction............................................................................... 290

10.3.7.4.1 Auxiliary solution using the voltage transformer .................................................. 290 10.3.7.4.2 Test by producing a real earth fault ..................................................................... 293

10.3.7.5 Checking the voltage transformer polarity U4 = US2................................................... 294 10.3.7.6 Checking the CB TRIP and CLOSE ........................................................................... 295 10.3.7.7 Checking the thermal replica...................................................................................... 295

10.4 Making protector ready for operation....................................................................................... 296 11 Maintenance ................................................................................................................................... 297

11.1 Routine check .......................................................................................................................... 297 11.2 Troubleshooting ....................................................................................................................... 298

12 Storage ........................................................................................................................................... 298 13 Order data for the PC software COMM-3, SDA 2 .......................................................................... 299

Figures and Characteristics Fig. 3.3-1 Input characteristic ................................................................................................................ 21 Fig. 3.4-1 DC breaking capacity of CO and AO relay contacts ............................................................. 22 Fig. 3.4-2 DC breaking capacity of DO relay contacts .......................................................................... 23 Fig. 5.3-1 Measurement of zero impedance.......................................................................................... 32 Fig. 5.4-1 Characteristic curve of direction decision ............................................................................. 36 Fig. 5.4-2 Active principle of earth short-circuit direction (definite time OTP shown)............................ 40 Fig. 5.4-3 Active principle Earth short-circuit direction and SDLRE automatic (DT of OTP shown) ..... 43 Fig. 5.5-1 Characteristic of current starting (U-) I .................................................................................. 45 Fig. 5.5-2 Earth short circuits in systems with a not earthed neutral point............................................ 47 Fig. 5.5-3 Characteristic of voltage-dependent current starting in impedance plane............................ 47 Fig. 5.5-4 Characteristic of polygonal impedance starting Z<............................................................... 51 Fig. 5.5-5 Earth-current biasing if three-pole IL > Ibias ............................................................................ 56 Fig. 5.5-6 Earth-current biasing, comparison one, two and three-phase IL > Ibias ................................. 57 Fig. 5.5-7 Effect of timer t1p on distance protection starting................................................................. 60 Fig. 5.5-8 Comparison of zone times start settings at zone changes of measured impedance ........... 65 Fig. 5.5-9 Characteristic of distance zones (for reverse direction dotted)............................................. 66 Fig. 5.6-1 Possible characteristic of overcurrent time protection .......................................................... 69 Fig. 5.6-2 Active principle Phase overcurrent time protection IL> ........................................................ 71 Fig. 5.6-3 IDMT characteristic, long time inverse (example with “tIL>max Delay time“=600 s)............ 75 Fig. 5.6-4 IDMT characteristic, type A, normally inverse....................................................................... 76 Fig. 5.6-5 IDMT characteristic, type B, very inverse ............................................................................. 77 Fig. 5.6-6 IDMT characteristic, type C, extremely inverse .................................................................... 78 Fig. 5.6-7 Basic principle, earth overcurrent time protection IE> ........................................................... 79 Fig. 5.6-8 Basic principle of intermittent earth-fault protection IE>int...................................................... 83 Fig. 5.6-9 Operating principle of the IE>int stage................................................................................... 85 Fig. 5.6-10 Operating principle of the IE>int stage................................................................................. 86 Fig. 5.7-1 Active principle Earth fault detection..................................................................................... 89 Fig. 5.7-2 Active principle Earth fault direction...................................................................................... 92 Fig. 5.7-3 Representation of the relations U and I as well as P and Q in the coordinate system......... 94 Fig. 5.8-1 Switch-onto fault protection with distance starts ................................................................. 100 Fig. 5.8-2 Active principle Switch-On Protection ................................................................................ 102 Fig. 5.8-3 Example: application of the switch-on protection................................................................ 104 Fig. 5.9-1 Active principle, negative sequence protection I, stage Ineg> shown ................................ 107

Table of Contents


Fig. 5.10-1 Active principle Inrush restraint for phase current start, overcurrent-time protection ....... 110 Fig. 5.11-1 AR Enable and blockage................................................................................................... 112 Fig. 5.11-2 AR readiness..................................................................................................................... 113 Fig. 5.11-3 Examples for a successful AR procedure ......................................................................... 117 Fig. 5.11-4 AR on inhomogeneous line ............................................................................................... 120 Fig. 5.11-5 AR on inhomogeneous line - section factor f .................................................................... 121 Fig. 5.12-1 Teleprotection – CLOSE / TRIP / Blockage / Generation of the signal "TP ready“ .......... 124 Fig. 5.12-2 Two-wire connection via relays for standard inputs .......................................................... 126 Fig. 5.12-3 Two-wire connection, parallel circuit for low loop voltages ............................................... 126 Fig. 5.12-4 Three-wire connection....................................................................................................... 126 Fig. 5.12-5 Active principle two-wire connection ................................................................................. 128 Fig. 5.12-6 Connection principles ”reverse interlock”.......................................................................... 130 Fig. 5.12-7 Active principle “reverse interlock” ................................................................................... 131 Fig. 5.12-8 H2 Logic within the system ............................................................................................... 134 Fig. 5.12-9 Principle of connection between two stations ................................................................... 136 Fig. 5.12-10 Connection variants to the station blocking bus in case of DDx 6 as directional relay... 137 Fig. 5.12-11 Active principle "transmitter“ in unidirectional mode ...................................................... 139 Fig. 5.12-12 Active principle "receiver“ in unidirectional mode .......................................................... 140 Fig. 5.12-13 Active principle permissive overreach protection (POP)................................................. 142 Fig. 5.12-14 Active principle blocking overreach protection (BOP)..................................................... 145 Fig. 5.12-15 Active principle permissive and accelerated underreach protection (PUP, AUP) .......... 147 Fig. 5.13-1 Active principle U> ........................................................................................................... 151 Fig. 5.13-2 Active principle Displacement voltage protection............................................................. 153 Fig. 5.14-1 Active principle Frequency protection – one stage shown............................................... 155 Fig. 5.15-1 Active principle Power protection..................................................................................... 157 Fig. 5.15-2 Definition of the power directions ...................................................................................... 157 Fig. 5.16-1 Active principle Overload protection ................................................................................ 161 Fig. 5.16-2 Trip characteristics for k=1.1 and without preload (Ip=0).................................................. 164 Fig. 5.16-3 Trip characteristics for k=1.1 and Ip=0.9⋅In....................................................................... 165 Fig. 5.16-4 Trip characteristics for k=1,1 and Ip = 1⋅In........................................................................ 166 Fig. 5.16-5 Trip characteristics for different preloads Ip...................................................................... 167 Fig. 5.16-6 Characteristics for cooling at I = 0, switching-off at 100% ................................................ 168 Fig. 5.17-1 Active principle of the temperature protection based on temperature 1 ........................... 169 Fig. 5.18-1 Active principle of the central reclosing lockout ................................................................ 172 Fig. 5.20-1 Active principle of the TRIP command stage .................................................................... 175 Fig. 5.21-1 Active principle Circuit-breaker failure protection............................................................. 178 Fig. 5.22-1 Inputs and outputs of the fault location ............................................................................. 181 Fig. 5.23-1 Active principle Phase current annunciation stages ........................................................ 182 Fig. 5.24-1 Active principle Synchrocheck ......................................................................................... 185 Fig. 5.24-2 Connection versions of the transformer U4 = US2............................................................. 188 Fig. 5.25-1 Block diagram to position the function group ”pulse shaper stage“ .................................. 191 Fig. 5.25-2 Retriggerable / non retriggerable (here setting in accordance with Fig. 5.25-6)............... 192 Fig. 5.25-3 Max. possible feedback of output to input with logic operation......................................... 192 Fig. 5.25-4 Beginning with "On" edge, end with "Off" edge ................................................................ 194 Fig. 5.25-5 Beginning with "On" edge, end with reset signal to separate input .................................. 194 Fig. 5.25-6 Beginning and end with "On" edge ................................................................................... 194 Fig. 5.25-7 Beginning with "Off" edge, end with reset signal to separate input .................................. 194 Fig. 5.25-8 Beginning and end with "Off" edge ................................................................................... 194 Fig. 5.25-9 Using the AR together with two circuit-breakers ............................................................... 195 Fig. 5.26-1 Active principle Trip circuit supervision ............................................................................. 196 Fig. 5.26-2 Block diagrams - Trip circuit supervision .......................................................................... 197 Fig. 5.26-3 Supplementary block diagrams for trip circuit supervision with linear inputs.................... 198 Fig. 5.28-1 Disturbance data record.................................................................................................... 201 Fig. 5.28-2 Start of disturbance record by any output commands ...................................................... 202 Fig. 5.28-3 Any output commands as tag in disturbance record......................................................... 202 Fig. 5.29-1 Measurand check U: fuse voltage transformer input ........................................................ 204 Fig. 5.29-2 Measurand check U: I without three-phase U................................................................... 205 Fig. 5.29-3 Measurand check U: three-phase U < Umin without current change ................................. 206 Fig. 5.29-4 Measurand check U: U – unbalance without I – unbalance.............................................. 207 Fig. 5.29-5 Measurand check U: UNE without IE or earth fault ............................................................. 208

Table of Contents


Fig. 5.29-6 Measurand check U: rotating field..................................................................................... 208 Fig. 5.29-7 Measurand check I: Current unbalance ............................................................................ 209 Fig. 5.29-8 Measurand check I: IE start without UNE> or general starting............................................ 209 Fig. 5.29-9 Measurand check I: Comparison IE calculated with IE measured ..................................... 210 Fig. 5.29-10 Measurand check I: Biasing the summation current pickup value.................................. 211 Fig. 5.29-11 CB tests........................................................................................................................... 219 Fig. 5.31-1 Principle of setting the pickup and reset times for digital inputs ....................................... 229 Fig. 5.31-2 Principle of input configuration .......................................................................................... 229 Fig. 5.31-3 Wiring of the inputs, from very bad to very good .............................................................. 230 Fig. 5.31-4 Principle of configuration of temperature inputs................................................................ 231 Fig. 5.32-1 Principle of LED configuration........................................................................................... 238 Fig. 5.32-2 Principle of the combinatory logic for the configuration of the output relays .................... 239 Fig. 5.32-3 Principle of the combinatory logic for the configuration of the vDI.................................... 240 Fig. 6.5-1 Eyelet fastener for cables on the front plates...................................................................... 243 Fig. 6.5-2 Connection of Control Panel to Central Unit ....................................................................... 244 Fig. 8.2-1 Current transformer earthing on line end - busbar end....................................................... 254 Fig. 10.3-1 Determination of Z< characteristic curve corners ............................................................. 281 Fig. 10.3-2 Determination of the zone characteristic curve corners.................................................... 281 Fig. 10.3-3 Circuitry to check the earth fault direction with UNE calculated ......................................... 292 Fig. 10.3-4 Circuitry to check the earth fault direction, if UNE via transformer U4 ............................... 293 Fig. 11.2-1 Connection to current transformer .................................................................................... 307 Fig. 11.2-2 Connection to two phase-current transformers – inadmissible for earthed systems ........ 307 Fig. 11.2-3 Variants for connection to voltage transformers ............................................................... 308 Fig. 11.2-4 Variants for connection to voltage transformers for DDEY 6 ............................................ 308 Fig. 11.2-5 Examples for connection of synchronization voltage US2 for DDEY 6 .............................. 309 Fig. 11.2-6 Connection of temperature sensors to the PT100 module ............................................... 309

Equations 5-1: Phase-to-phase loop ...................................................................................................................... 32 5-2: Phase-to-earth fault loop................................................................................................................ 32 5-3: Earth factor..................................................................................................................................... 32 5-4: Earth factor 1.................................................................................................................................. 33 5-5: Earth factor 2.................................................................................................................................. 33 5-6: Definition calculated displacement voltage uNE.............................................................................. 38 5-7: Definition calculated earth current iE .............................................................................................. 38 5-8: Current setting values .................................................................................................................... 46 5-9: Voltage setting values .................................................................................................................... 48 5-10: Setting value Zs ............................................................................................................................ 51 5-11: Setting value Xs ............................................................................................................................ 52 5-12: Biasing IE>EFC a) ........................................................................................................................ 54 5-13: Biasing IE>EFC b) ........................................................................................................................ 54 5-14: Biasing IE>EFC c)......................................................................................................................... 54 5-15: Distance zones: X ........................................................................................................................ 67 5-16: Distance zones: R ........................................................................................................................ 67 5-17: long-term inverse, trip time........................................................................................................... 73 5-18: inverse, trip time ........................................................................................................................... 73 5-19: very inverse, trip time ................................................................................................................... 73 5-20: extremely inverse, trip time .......................................................................................................... 73 5-21: Bias IE> a)..................................................................................................................................... 81 5-22: Bias IE> b)..................................................................................................................................... 81 5-23: Bias IE> c)..................................................................................................................................... 82 5-24: Power setting P> or Q>................................................................................................................ 90 5-25: Earth-fault direction operate value ............................................................................................... 93 5-26: Earth-fault direction, setting value P> .......................................................................................... 94 5-27: Determination of the total factor fb................................................................................................ 96 5-28: Earth-fault direction setting value Q>........................................................................................... 97 5-29: Section Factor f .......................................................................................................................... 121 5-30: Voltage settings.......................................................................................................................... 151 5-31: Power setting.............................................................................................................................. 158 5-32: Trip delay thermal replica........................................................................................................... 160

Table of Contents


5-33: Pickup factor, thermal replica..................................................................................................... 160 5-34: Effect of temperature on pickup factor ....................................................................................... 160 5-35: Level, thermal replica ................................................................................................................. 162 5-36: Trip time for level F..................................................................................................................... 162 5-37: Time constant thermal replica .................................................................................................... 162 5-38: Fault location: Setting X ............................................................................................................. 180 5-39: Fault location: Distance.............................................................................................................. 180 5-40: Biasing of current total check ..................................................................................................... 210 5-41: Correlation of measured to calculated secondary IE .................................................................. 234 5-42: Angle determined from powers P and Q.................................................................................... 234 10-1: UNE of one voltage...................................................................................................................... 280 10-2: Current for tripping after 0.1⋅τ..................................................................................................... 286 10-3: Current for tripping after a specified time................................................................................... 286 10-4: Time from level F1 to F2.............................................................................................................. 287 10-5: Current for raising level F1 to F2 within a specific time............................................................... 287 10-6: Cooling to level F2 ...................................................................................................................... 287

Tables Table 1 Loop selection at multiple startings of overcurrent-time protection.......................................... 38 Table 2 Start programs of U-I starting ................................................................................................... 49 Table 3 Assignment of loops to measurands for distance and direction determination........................ 60 Table 4 Loop selection for two-pole faults in earthed neutral systems ................................................. 61 Table 5 Loop selection for three-pole faults in earthed neutral systems............................................... 62 Table 6 Loop selection at cyclical phase preferential............................................................................ 62 Table 7 Loop selection at acyclical phase preferential of phase L1...................................................... 63 Table 8 Loop selection at acyclical phase preferential of phase L2...................................................... 63 Table 9 Loop selection at acyclical phase preferential of phase L3...................................................... 63 Table 10 Equipment adaptation .......................................................................................................... 310 Table 11 System Adaptation ............................................................................................................... 311 Table 12 Protection Modules............................................................................................................... 312 Table 13 General................................................................................................................................. 333 Table 14 Communication+Substation Control..................................................................................... 336 Table 15 Input configuration................................................................................................................ 337 Table 16 Input signals explained......................................................................................................... 341 Table 17 Temperature sensors of module PT100 (Option)................................................................. 342 Table 18 Output configuration of relays .............................................................................................. 343 Table 19 Output configuration of LED................................................................................................. 357 Table 20 Output configuration of virtual digital inputs ......................................................................... 370 Table 21 Output commands explained................................................................................................ 384

Appendices Appendix 1: Overview of mounting variants ........................................................................................ 300 Appendix 2: Dimensional diagram, surface-mounted with separately mounted control panel ........... 301 Appendix 3: Dimensional diagram, with attached hinged mounted control panel............................... 302 Appendix 4: Dimensional diagram, control unit, flush-mounted with attached control panel.............. 303 Appendix 5: Dimensional diagram, control unit with variable mounting brackets ............................... 303 Appendix 6: View of control panel ....................................................................................................... 304 Appendix 7: Terminal arrangement of the modules relevant for protection ........................................ 305 Appendix 8: Connection diagram with connection example In=1 A .................................................... 306 Appendix 9: Connection versions in measuring circuits...................................................................... 307 Appendix 10: Connection of temperature sensors to PT100 module ................................................. 309 Appendix 11: Settings DDx 6 .............................................................................................................. 310 Appendix 12: Message list................................................................................................................... 392 Appendix 13: Assignment of buttons for the protection system menus .............................................. 413 Appendix 14: Abbreviations and explanations .................................................................................... 414 Appendix 15: Symbols used in circuit diagrams.................................................................................. 415 Appendix 16: Error report .................................................................................................................... 416

Application and function scope


0 Changes since structure version 5600 The releases of the protection firmware of the DDx 6 identified with higher structure version numbers contain the extensions and improvements specified below.

5601: 1. Earth fault criterion: Within the non-grounded system, an additional, third request combination

for a fault involving the earth is added: “4932 EarthFault if“ “IE> and UNE>EFC“. With this setting, no unbalance need to exist versus the standardized “IE>and UNE>EFC+asym“.

2. Earth fault criterion: The setting “4906 ULLmax/ULLmin asym.“ can be set as of 1.1. 3. Direction decision: The application point for utilization of the voltage memory can be selected via

the setting “1908 Umem if ULL <“ (separated from “18208 Umin=min. Voltage“). The appropriate output command “1974 3ph. U<Umem min“ signals that the voltage value has been undercut.

4. AR: the CB position signals can be taken into consideration for AR readiness “9949 CB Pos for AR Ready“ “consider“. Thus, an AR can be rejected in OFF and not in ON position.

5. AR: separate setting for the reclaim time after a manual ON “9905 tblockAR CBC CB Close“. The output command pertaining to it “9979 tblockAR CBC runs“ signals expiry. So far, the reclaim time following manual ON was linked to the setting “8005 top Operat.Time SOTF“ of the switch-on protection.

6. AR: only first AR with overreach stage 7. AR: Introduction of a second operating time “9919 top2 from 2ndDeadTime“. The first op-

erating time is identified as “9914 top1Time1st DeadTime“. 8. Earth fault direction: The connection of external earth fault direction decisions, e.g. by ERER3, is

possible for all device models. The inputs have been renamed slightly: “7061 EarthFlt. forw.ext“ “7062 EarthFlt. rev. ext“: “7061 EarthFlt. forw.ext“ “7062 EarthFlt. rev. ext“.

9. Earth fault direction: New output commands separated from the internal earth fault direction de-cisions are available for external earth fault direction decisions “7061 EarthFlt. forw.ext“ and “7062 EarthFlt. rev. ext“.

10. (Emergency-)OTP/IDMT: Setting range for “1112 tL> Time Factor“ and “2112 tE> Time Factor“ has been extended to max. 3.5 s. At the same time, the upper limit for “1113 tIL> max Time Delay“ or “2113 tIE> max Time Delay“ has been adjusted to 4200 s.

11. Negative Sequence I: setting range for “3112 tIneg> Time Factor“ extended to max. 3.5 s. At the same time, the upper limit has been adapted for “3113 tIneg>max Time Delay“ to 4200 s.

12. Measuring circuit monitoring: If no voltage-related start is used, change-over to emergency over-current time protection is delayed in most cases by the time “18211 tU Time Malf. U Path“.

13. Activation and deactivation of a signal and measured value interlock additionally in test menu 14. Teleprotection, new modes: permisssive underreach protection (PUP-PUTT) 15. Teleprotection: new input signal “19065 TP Connect.disturbed“ 16. Teleprotection: with a blockage of teleprotection function in all modes no send signal will be acti-

vated 17. Voltage protection: resetting ratios can be set up to 0.99 or 1,01



1 Preface Essentially, only protection-specific issues are dealt with in this manual. To this effect, the indi-vidual protection functions and their mode of action are presented. All the information required for operation of the protection device is contained in the following sections. Regarding the com-munication with the device, only the most important hints of protection functions are given herein. The far-reaching separation of protection and control system is also reflected by the separate setting of the protector. Only the protector is set on the device and via the operating software COMM-3. For reading information on the device, the protection and the control part provide vari-ous screens on the graphic display.

In the following chapters, the term "protection device" is frequently used, which is justified due to the fact mentioned before that the device parts are separated. Likewise, the abbreviation “DDx6“ characterizing the protector should be used to identify the device type. The individual letters identify the main functions:

D Digital protection D Distance protection x stands for

E Earth-fault direction decision Y Synchrocheck

6 Series

2 Application and function scope

2.1 Application SPRECON®-E-Pxx-DDx 6 is a one-box solution for protection and control, which guarantees pro-tection of primary equipment by simultaneously accomplishing control and monitoring functions in electric power systems. Consequently separation of control and protection technology together with approved algorithms of digital signal processing provides security, offers availability and re-liability at the highest possible level.

The digital distance protectors DDx 6 are preferably used as a selective protection for single- and double-fed lines (overhead lines and cables) in the medium-voltage or, respectively, the lower high-voltage level. They are suitable for all system configurations (radial, ring, and meshed sys-tems) and methods of neutral-point connection (earthed with or without limiting resistance, in-ductive, isolated).

Other significant applications are the back-up protection for transformers, busbars as well as for lines with phase comparison protection as main protection. In addition to the main function - determination of the distance from the fault location - the func-tions and supplementary functions useful for protection of feeders are included in the multifunc-tional protection device. By using signal transmission (teleprotection) between protection devices, the off times can be reduced while selectivity is improved simultaneously. For overhead lines, the integrated automatic reclose (AR) function complements the available fea-tures in a meaningful fashion to reduce the duration of supply interruption. Operating facilities, such as cables and transformers, can be protected additionally by means of the overload protection as a safeguard against overloads applied for an inadmissibly long time. To this effect, preloads are not taken into consideration. A voltage incl. displacement-voltage time protection, negative sequence I (load unbalance protec-tion), power protection, frequency monitoring feature and circuit-breaker failure protection com-plete the functionality to provide for a complete feeder protection. If used in earthed power systems which may feature a high resistive zero-sequence field imped-ance (e. g. resistive earthed systems, earthed overhead lines without shield wire), determination of zero power direction has been provided.



The DDE 6 is equipped, versus the DD 6, with a wattmetric earth-fault direction detection which makes it perfect for use in compensated or isolated systems.

If system-synchronized connection is required, e. g. in case of AR, the DDEY 6 provides this function.

2.2 Function Scope Reference Type

Protection Functions IEEE C37.2

IEC 61850-7-4 DD 6 DDE 6 DDEY 6

Distance protection 21 PDIS X X X Current starting I>> (PTOC) X X X Voltage-dependent U-I starting (PVOC) X X X Polygonal Z< starting X X X Distance zones / overreach zones 4 / 1 4 / 1 4 / 1 Directional backup time / time limit (non direct.) X / X X / X X / X

Short-circuit direction decision 67 PTOC / RDIR X X X

Switch-on protection (SOTF, SOP) 50 PIOC X X X Automatic reclosing (AR) 79 RREC 3-pole 3- pole 3- pole Teleprotection (TP) 85 PSCH X X X Backup and overcurrent-time protection X X X

IL> (backup-)DT/IDMT, four stages 50, 51 PIOC PTOC X X X

IE> (backup-) DT/IDMT, four stages 50N,51N, 51Ns

PIOC PTOC X X X

Earth-fault short circuit direction 67N PTOC / RDIR X X X

Phase selective earth-fault detection 64 PHIZ X X X Earth-fault direction decision 67Ns PSDE X X

Capture of external earth-fault directions (PTEF/ PSDE) X X X

Current annunciations (2x IL>an, 1x IE>an) X X X Inrush biasing PHAR X X X Overvoltage-time protection (U>, UNE>), two stages 59, 59N PTOV X X X Undervoltage-time protection (U<), two stages 27 PTUV X X X

Frequency protection (f<, f>), four stages 81 PTUF / PTOF X X X

Directional power protection (P, Q), 2x 2 stages 32 PDOP / (PDUP) X X X

Unbalance protection (Ineg) 46 PTOC X X X Overload protection 49 PTTR X X X Temperature protection 49 STMP Option Option Option Reclosing lockout 86 PMRI X X X

CB failure protection (CBF) 50BF PTOC / RBRF X X X

CB TRIP by external signal (PTRC) X X X Synchronizer 25 RSYN X Fault locator (FL) 21FL RFLO X X X Phase-sequence reversal X X X Pulse shaper (programmable logic) X X X Trip-circuit supervision 74TC X X X Characteristic sets 4 4 4 Logic + timer for optocoupler inputs X X X virtual binary (digital) inputs (vDI) 15 15 15 Logic + timer for output relays X X X Measurands, short report X X X Event logging, non volatile RDRE X X X

Disturbance date recording, non volatile RADR / RBDR X X X

Statistics X X X Measurand checks, self supervision X X X Assistance for test- and putting into operation X X X

Distance Protection Startings Various starting procedures permit optimum adaptation to the conditions in the operating equip-ment in order to ensure a high starting security: • Current starting I>> • Voltage-dependent current starting (U-I start) • Angle-dependent, polygonal under-impedance starting Z< with six-system measuring These starts can work in parallel.

Short-Circuit Direction Decision • The direction decision is based on the 90° circuit, i.e. the use of fault-free voltages. • In the case of the three-pole short-line fault, the direction decision is made with the help of

the voltage memory (uL12hist - uL23hist) and the current iL31. These variables are used to achieve an unlimited sensitivity of the direction decision.

Loop Determination • comprehensive setting options of loop selection are available, permitting to realize, amongst

other things, a phase priority in case of double earth faults

Distance Protection With up to five polygonal distance zones • Z1 t1, Z1x t1x, Z2 t2, Z3 t3, Z4 t4 • with the possibility of using the impedance stage Z1x t1x as an overreach stage for interaction

with the functions “AR“, “Signal comparison“ or “Switch-on protection“ • this stage can also be activated by means of an external input signal Z1x t1x (as grading zone

or overreach stage) • the directional back-up time stage t5 • the non-directional time limit t6 • frequency-independent

Switch-On Protection (SOTF) Fulfils two tasks within its operating time: 1. Switching on to a short-circuit is dealt with - main function 2. Prevents starting or TRIP of the protective functions (Emergency) overcurrent-time protection

I>(>>>), negative sequence protection by short-time overcurrent or negative sequence protection on switching on high loads with a higher than normal inrush current.

The switch-on-to-fault protection can be started by • any distance starting • impedance smaller than zone (Z1, Z1x or Z2) or • separate current starting of SOTF

Auto-Reclose (AR) • three-pole automatic reclose with up to 5 reclosure shots • the first dead time can be "short“ or "long“ at choice. Any further dead times are always

"long“ • Starting-up the AR by various protection functions in addition to distance-dependence • The breaker-tripping signal in case of the "non-final TRIP command" can be interrupted by the

break contact element (NC) of an output relay. • Another relay contact closes for a short time if the intended “CLOSE command“ fails, for ex-

ample, due to an intermediate blocking of the AR. Thus, the previously suppressed breaker tripping pulse can be simulated subsequently.

• On an inhomogeneous line (cable and overhead line section), AR can be performed selectively at the overhead line section.

Teleprotection System (TP) • Reverse interlocking, i.e. shortened TRIP command time in case of lacking protector starting

on the appropriate line outgoing feeders. As extension - the auxiliary logic circuit "H2" can be used to switch off all faults in the basic time.

• Signal comparison (SCMP) using the remote station protection result via a two-wire signal loop

• Intertripping for weak infeeds



When using teleprotection equipment: • Unidirectional operation (transmitting only in one direction) • Signal comparison based on the permissive overreach protection (POP) principle • Signal comparison based on the blocking overreach protection (BOP) principle • Signal comparison based on permissive underreach protection (PUP, AUP) principles.

Emergency (back-up) Overcurrent-Time Protection / Overcurrent-Time Protection (I>, I>>, I>>>, I>>>>) The DDx 6 works automatically as a non-directional Overcurrent-Time Protection (OTP), if • the measurand supervision system detects a malfunction in the voltage path, • the fuse of voltage transformer has tripped/blown, which has been communicated to the pro-

tection device, and • within the overcurrent time protection, stages have been enabled for operation in case of

faults in the voltage path. All stages depending on the voltage are deactivated in case of faults in the voltage path. In addition to its action as Emergency OTP, the overcurrent time protection can also work, at choice, parallel to the distance protection. It is subdivided into the tasks of phase fault and earth short-circuit fault treatment.

• Phase short-circuit fault - IL> (Emergency) OTP o up to four-stage independent, phase-selective definite-time (DT) overcurrent protection

(IL> ... IL>>>> with the timers tIL>...tIL>>>>) o the first stage (IL>) can be operated as phase-selective inverse-time overcurrent protec-

tion (IDMT) with various IEC characteristics o if possible selection whether non-directionally, forward or reverse measurement is to do.

• Earth short-circuit fault treatment - IE> (Emergency) OTP In earthed networks, especially in such as feature earth-fault current limitation, the following can be used as backup protection: o up to four-stage earth fault current time protection: IE>, tIE> ... IE>>>>, tIE>>>> o the first stage (IE>) can be operated as inverse-time overcurrent protection (IDMT) with

various IEC characteristics o if possible selection whether non-directionally, forward or reverse measurement is to do o earth short-circuit fault direction decision based on zero power direction o for the first stage IE>, sensitive setting for zero current is possible, as instrument trans-

former fault currents can be biased in an object-specific fashion in case of symmetrical three-pole short circuits.

In all system types, a trip time can be realized for short-circuits involving the earth which dif-fers from that which can be realized if the earth is not involved.

Earth Fault Detection • In compensated and isolated-neutral systems, one stage can be used for phase-selective

earth-fault detection • Optionally, a TRIP command can be issued, if an earth-fault power is additionally exceeded • An external directional earth-fault relay can be connected (e.g. ERER 3 made by Sprecher

Automation Deutschland GmbH). The earth-fault direction decision will be further processed as an internal functional group of the same kind (in event logging, alarms referring to control system).

Earth-Fault Direction Decision (not in DD 6) • based on active and reactive power assessment, the earth-fault direction decision for single-

pole earth faults is available. • a sensitivity regulator with the help of the "assessment number" enables the operator to rec-

ognize the line with the earth-fault with enhanced reliability and to suppress non-relevant earth-fault direction reports.

• Optionally, a TRIP command can be created depending on various conditions. Current Annunciation (I>an) • Two phase current annunciation stages (IL>an, IL>>an) and

• one for earth-fault current (IE>an) signal specific operating conditions without starting the pro-tection device.

Inrush Restraint • Effective for over-current time protection and negative sequence protection • Inrush restraint by weighting the contents of the 2nd harmonic compared to the fundamental

wave, adjustable threshold ratio, effect at choice phase-selective or crossblocking.

Voltage-Time Protection • Two-stage overvoltage time protection U>, tU> and U>>, tU>> • Two-stage undervoltage time protection U<, tU< and U<<, tU<< • Two-stage displacement-voltage time protection UNE>, tUNE> and UNE>>, tUNE>> • Can be used at choice as signal or tripping stage

Frequency Time Protection • Four-stage frequency time protection f1><, tf1>< ... f4><, tf4>< • At choice for underfrequency or overfrequency • Can be used at choice as signal or tripping stage

Power Protection For signalling and for switching OFF power limit violations and wrong power direction • Two-stage monitoring of active power, directed or non-directional • Two-stage monitoring of reactive power, directed or non-directional

Load Unbalance Protection (negative sequence Ineg) • Two-stage negative sequence protection Ineg>, tIneg> and Ineg>>, tIneg>> • The first stage can be operated as inverse-time overcurrent protection (IDMT) with various IEC

characteristics

Overload Protection (thermal replica) • Operates taking account of the preload • Two warning levels for adjustable filling levels (in %) of the thermal replica • Optional TRIP command of overload protection if the 100% value is reached

Temperature Protection (optional) Utilization of the optional board PT100 for temperature acquisition • If appropriate devices and sensors are provided, temperature monitoring of objects is possible,

e.g. for ambient temperature, winding temperature • Limit comparison, on request non-delayed output command if the settings are exceeded • Warning levels adjustable

Reclosing Lockout • Prevents the object to be protect from being connected after tripping due to faults for thermal

reasons, as long as the release values have not been undercut or remote reset has been per-formed

• selectable setting of the reclosing lockout by thermal level of overload protection and tem-perature monitoring

Circuit-Breaker Failure Protection (CBF) • Detects the failure of the reference circuit breaker on executing the TRIP command • Possibility of monitoring of the execution of TRIP generated by an external device • When the device is used in the higher-level feeder, the trip request due to a CB failure is real-

ized in a lower-level outgoing feeder.

CB TRIP due to an external signal • External devices can arrange for the TRIP command to be performed by the DDx 6. This has

the advantage of being recorded in the event memory and for monitoring for CB failure.

Synchrocheck (only in DDEY 6) • Implementation of connection in case of synchronism of both part systems. • separate function groups and consequently separate parameters exist for synchronization in

case of



• auto-reclosure by the protection device (Synchrocheck AR) and • switching ON via the substation control

Fault Location (FL) Fault location determines: • the primary fault reactance • the distance of the fault location in km • the fault distance in per cent

Phase rotation change • An input is provided to change the phase rotation direction for detection of measured values

in the protection device

Inputs (digital DI) There are two types of digital inputs: • physical optocoupler inputs “DI“ • virtual inputs (vDI) which implement, in the software, the feedback from the protection relay

output to an input

Input signal processing • Assignment of the inputs to internal functions • Logic operation of the input signals AND, OR and negation of signals is possible. Thus, fail-

safe circuits for the binary inputs can be realised. • Pickup and reset times can be defined for each binary input • For several temperature inputs of the same type, the processing functions "average, maxi-

mum and minimum" can be applied

Pulse Shaper Stage • Signal 1 and signal 2 are used for input/output coupling (pass-through function) • Various start and stop versions and time delays for these signals • Setting options for flip-flop effects (saving till reset)

Trip Circuit Supervision • Monitoring for continuity and existence of the auxiliary voltage, at choice by means of one or

two binary inputs

Change of characteristic sets The input of max. four characteristic sets has been provided. Selection of the currently active characteristic set is possible • as local operation, • alternatively via optocouplers or • by substation control equipment commands. • as change-over is effected very quickly, it can also be effected during starting

Output to output relays • A minimum operating time can be assigned to each relay • Several output commands (negated/not negated), logic OR and AND gated can be configured

for each relay

Output to virtual inputs • Several output commands (negated/not negated), logic OR and AND gated can be configured

for each virtual input "vDI". These combined signals are subsequently available as input vDI.

Measurand display In the protection system main menu, the measurand display (primary values and secondary val-ues) is available in the LCD: • Currents IL1, IL2, IL3, IEmeasured, IEcalculated, Inegative sequence • Voltage UL1E, UL2E, UL3E, UNE, UL12, UL23, UL31, Unegative sequence, U4 • System frequency • Three-phase power values, powers in the phases • cos(ϕ) • Earth-fault measurands (in case of earth fault)



• If a thermal protection is used: • level of the replica • remaining time until level will reach 100%, assuming a constant current • duration till reset of the reclosing lockout set by the function

• with temperature acquisition: all currently present, configured and arithmetically pre-processed temperatures.

• Synchrocheck measurands, if synchronization is requested Additionally, selected operating measurands can be displayed in the control menu in the scope of the configuration of the control software.

Reports • Display of short information concerning grid faults, alarms and malfunctions

LED display The LEDs are operated in the same way as is known from the D...2 and D...3 series for display-ing various signals on an LED (in deviation from the protection and control system's alarm modes). • Steady light • flashing light, with the flashing light being the dominating one

Event logging • Events are time- and date-stamped and stored in a ring memory and broken down into main or

sub-events • The events are recorded with event group assignment

Disturbance Data Record • Disturbance data logging includes storing of the digital instantaneous values of the meas-

urands • Storing of important reactions such as starting, TRIP command, etc. • Comprehensive analysis using the "SDA2" graphic software

Statistics • Saving the current total of the individual phases in case of TRIP commands • Number of close and open operations

Measurand check • Monitoring of the incoming voltages and currents for plausibility and unbalance.

Self-monitoring • Test routines after switching on the auxiliary voltage and continuous monitoring of the protec-

tor's software and hardware increase the availability.

Testing and start-up aids For commissioning and checking the device, the following are available in addition to comprehen-sive operating measurands: • Start disturbance record • Loop measurands • Earth fault test • Overload test • Various resets • Trial TRIP, trial AR to check the function of the circuit breaker, • Indication of levels at the inputs, • Indication of the output relay states, • Actuation of relays for testing • Telegram test • Check of LEDs

Technical data


3 Technical data

3.1 EC Declaration of conformity The SPRECON®-E-Pxx-DDx 6 devices are in accordance with the following European Directives: • 2006/95/EC Directive of the European Parliament and the European Council dated 12 Decem-

ber 2006 on the harmonization of the statutes of the member countries concerning electrical equipment for utilisation within fixed voltage limits - Low Voltage Directive - (OJ No. L 374 dated 27 December 2006),

• 2004/108/EC Directive of the European Parliament and the European Council dated 15 De-cember 2004 on the harmonization of the statutes of the member countries concerning elec-tromagnetic compatibility and on suppression of the Directive 89/336/EEC (OJ No. L 390 dated 31 December 2004),

The device series has been developed and produced for industrial applications. The device is in conformity with the standard product requirements EN 60255-6 (IEC 60255-6); VDE 0435, part 303. Further standards are specified in the data below.

3.2 Conditions for application Admissible ambient conditions - operating temperature -10 °C...+55 °C - storage temperature -25 °C...+55 °C - transport temperature -25 °C...+70 °C - humidity rating, yearly mean value 75%

for 30 days <95% at <40 °C, condensation not admissible - relative humidity (IEC 60068-2-78) for 56 days 93% at <40 °C condensation not admissible The devices should be arranged in such way that they are not exposed to direct sunlight or con-siderable temperature fluctuations that could cause condensation.

! It is not admissible to remove or to insert individual modules while voltage is applied.

Mechanical robustness Seismic test (in operation): EN 60255-21-3 Class 2

horizontal 1...8.5 Hz ±7 mm; 8.5...35 Hz: 2g vertical 1...8.5 Hz ±3.5 mm; 8.5...35 Hz: 1g

- Vibration strain EN 60255-21-1 Class 2 suitable for heavy-duty transport condition, ship application in operation 10 ... 150 Hz; 0.075 mm; 1 g Continuous stress (not in operation) 10...150 Hz; 2 g

- Shock loading EN 60255-21-2 in operation Class 2: 11 ms; 10 g High resistance (not in operation) Class 1: 11 ms; 15 g Repeated shock (not in operation) Class 1: 16 ms; 10 g

3.3 Input circuits Measuring input circuits - Rated frequency 50 Hz - Current paths

Rated current (In) various terminals 1 and 5 A Load capability

permanent 4·In 10 s 30·In 1 s 100·In

Technical data


Limiting dynamic value (10 ms) 250·In Power input at In 1A/5A

Phase current transformer < 0.1/0.2 VA Earth current transformer, double sensitivity of phase current transformers < 0.1/0.3 VA Earth current transformer, 20-fold sensitivity < 0.2/0.5 VA

- Voltage paths Rated voltage (Un) 100 V / 110 V /120 V (120 V limited to +15 %) Load capability, continuous 180 V Power input at Un=100 V < 0.2 VA

Binary signal inputs (optocouplers DI) - Number (identification DI) 15 - Rated input voltage (Ui)

a) Wide range: 24 V ... 220 V DC Changeover threshold L→H 10 V ... 17 V Changeover threshold H→L 14.3 V / 7.3 V max. current 35 mA

b) 110 V: 65 V ... 220 V DC Changeover threshold L→H 61 V ... 65 V Changeover threshold H→L 64.4 V ... 60.4 V max. current 8 mA

c) 220 V: 130 V ... 220 V DC Changeover threshold L→H 126 V ... 130 V Changeover threshold H→L 129.8 V ... 125.8 V max. current 4 mA

- Current, if input reacted < 2 mA at 220 V DC - Admissible input voltage tolerance -20 % to +15 % - Input impedance non-linear - Admissible capacitive coupling of inputs 100 nF at 220 V DC

Fig. 3.3-1 Input characteristic

Auxiliary power supply - depending on design, rating range Uaux 48-60 V DC

or 110 V DC or 220 V DC, 230 V AC admissible operating range referred to the rating range 0.8...1.15·Uaux maximum ripple at DC ≤ 12 %

- maximum power input (basic design with modules: CPU, PS, PROT):

0 25 50 100 125 150 175 200 225 2501

10

100

Input voltage / V

Varying voltage digital input

10 V O switch level O 17 V

Input active

110 V binary input

220 V binary inputInpu

t cur

rent

/mA

1.0 to 1.5 mA at 24 V ≤ 2 mA at 230 V

Technical data


in case of direct voltage supply / 230 V AC approx. 20 W / 32 VA in idle state (1 relay active) in case of direct voltage supply approx. 15 W

at 230 V AC < 30 VA - Hold-up time in case of failure of auxiliary supply (IEC 60255-11, 1979)

Modules fitted in device: PS, CPU9.1, PROT, CP at rated voltage (60V / 220V) > 50 ms

- Peak inrush current <2 A (voltage-related)

3.4 Output circuits Output relays - command outputs (marked: CO) having 2 make contacts each 4

Switching voltage 250 V DC, 250 V AC Making capacity 1000 W (VA) at L/R = 40 ms Breaking capacity L/R = 40 ms: 0.2 A at 220 V DC cosϕ = 0.4: 4 A at 230 V AC Continuous current 5 A Short-time current for 0.5 s 30 A Pickup time typ. 7 ms

Fig. 3.4-1 DC breaking capacity of CO and AO relay contacts

- Alarm outputs (marked: AO) with 1 CO contact 2 Switching voltage 250 V DC, 250 V AC Making capacity 1000 W (VA) at L/R = 40 ms Breaking capacity L/R = 40 ms: 0.3 A at 220 V DC cosϕ = 0.4: 4 A at 230 V AC Continuous current 5 A Short-time current for 0.5 s 30 A Pickup time typ. 7 ms

- Signal outputs (marked DO) 8 Switching voltage 250 V DC, 250 V AC Making/breaking capacity 30 W / VA Minimum current switched (contacts gold-plated) 10 mA at 5 V

after destruction of the gold layer 100 mA at 12 V Continuous current 1 A Pickup time typ. 7 ms

0,1 0,2 0,5 1 2 5 10 20

DC current /A

10

20

30 40 50

300

200

100

Maximum DC load breaking capability

1 contact

2 contacts in series

2-pole resistive load

DC

vol

tage

/V

Technical data


Fig. 3.4-2 DC breaking capacity of DO relay contacts

Displays - LEDs (freely programmable) red: 24 States that can be represented if activated by protection device Steady light, flashing, off - LCD graphical, lighted

3.5 Communication interfaces - Service interface – SERV (on CPU9) for connection of maintenance PC on site RS232 with RJ45 socket

max. baud rate 38400 Baud max. cable length 10 m electrical isolation none

- interface for remote connection (e.g. modem) – X4 (on PS) Option RS232 with SUB-D 9 pin male connector

Baud rate 300...57600 Baud max. cable length 10 m electrical isolation 1.5 kV

Remark: parallel operation of the interfaces SERV and X4 on PS is not admissible! The two interfaces can be used for operation of the protection device by means of the COMM-3 application software.

- Interface to control panel – CP (on CPU9) RS422 Proprietary with RJ45 socket

max. baud rate 38400 Baud max. cable length 10 m electrical isolation 1.5 kV

- System communication interfaces – on CPU9 optional up to 2 possible protocols asynchronous, synchronous Types RS232, RS422/485 or fibre optic connection electrical isolation 1.5 kV RS232: Baud rates 300...57600 Baud admissible cable length 10 m Connection SUB-D 9 pin male connector RS485: Baud rates 300...57600 Baud or 375 kBaud system bus admissible cable length at 38400 Baud <1 km Connection SUB-D 9 pin male connector Fibre Optic: BFOC-(ST)/2.5; optional: FSMA instead of ST

optical wavelength 820..860 nm Types of fibre optics Multi-mode graded index fibre 50/125 µm, 62.5/125 µm

0,1 0,2 0,5 1 2 5 1010

20

30 40 50

300

200

100

resistive load

Maximum DC load breaking capability

DC current /A

DC

vol

tage

/V

Technical data


Mono-mode step index fibre 9/125 µm Distance 1 km (max. 4 km1 for 50/125 µm) - Ethernet LAN Interface CPU9.1 1 port RJ45 for redundant ring: CPU9.2 1x RJ45 + 2x LWL (BFOC-(ST)/2.5) optional: FSMA instead of ST

optical wavelength 820..860 nm Types of fibre optics Multi-mode graded index fibre 50/125 µm, 62.5/125 µm Mono-mode step index fibre 9/125 µm

Distance 1 km (max. 41 km for 50/125 µm) Speed 10 / 100 MBit/s

electrical isolation 1.5 kV Remark:

The LAN interface can be used for operation of the protection device by means of the COMM-3 application software.

3.6 Design of the device Constructional details The devices are suitable both for a wall assembly, and for the installation in switchgear cabinets and instrument panels. In terms of surface mounting, the control panel can be directly attached to the central processing unit with optionally available fixing brackets. - Panel surface mounting with separate control panel for installation in door see Appendix 2 - Panel surface mounting with attached control panel see Appendix 3 - Panel flush mounting see Appendix 4 - mounting variant of control unit with variable mounting brackets see Appendix 5 - Terminals: current transformer, securing bolt M5 conductor size ≤ 4 mm²

others, conductor size 0.2 ... 2.5 mm² - Weight Central processing unit approx. 6 kg Control Panel (CP) approx. 1 kg - Degree of protection (EN 60529) Central processing unit without/with cover IP20/IP 40 Front of control panel IP 40/ with seal: IP 51

3.7 Set values and ranges Settings and their value ranges, see Appendix 11 as of page 307. Range of action of inverse time characteristics (current range within which time is current-depending) 1.1...20⋅I/I>

3.8 Performance characteristics - R.m.s. value measurement for current, voltage starts and operating measurands - Direct current offset of r.m.s. values, except thermal replica - Measurand filtering, cut-off frequency of the analogue filter 340 Hz - Sampling rate 1 ms - Reset ratios, I> U> stages, unless selection is possible 0.95 Z, U< stages 1.05 - Resetting ratio frequency protection start 0.02 Hz - Additional angle at the switching limit upon modification of the detected direction 3° - Shortest operating time, distance protection (Z= 0.5⋅Z1, ∠45°= ϕ i) 39 ms - Reset time, current start (τ>70ms, to 10% of the initial amplitude) <30 ms on contact output approx. 35 ms

1 depending on quality and amount of optical connections

Technical data


- Operating time, directional OTP without inrush restraint, Angle of deviation = characteristic angle ±59° < 45 ms Angle of deviation outside of characteristic angle ±59° < 65 ms - Extension of command time, directed OTP with inrush restraint approx. +20 ms - Trip time in case of earth fault following earth fault direction decision in the isolated system tUNE>EF, tTRIP=0 s: approx.70 ms - Time after earth fault detection before issuing the earth fault direction report in the compensated system (after expiry of tUNE>EF) approx. 260 ms - Trip time, earth short-circuit direction in earthed systems approx. 50 ms reset time approx. 40 ms - Pickup time, negative sequence system Ineg approx. 40 ms reset time approx. 45 ms - Frequency protection, pickup and reset time <100 ms - Operating time, overvoltage protection U> approx. 40 ms reset time approx. 45 ms - Operating time, displacement voltage protection UNE> approx. 50 ms reset time approx. 45 ms - Operating time, undervoltage protection U< approx. 75 ms reset time approx. 40 ms - Operating time, power protection P>, Q> approx. 40 ms reset time approx. 40 ms - Time required for change-over of characteristic set approx. 18 ms - Availability of voltage memory after time of occurrence of the fault, f=const max. 5 s

3.8.1 Measuring ranges - IL: 1 digit = 0.005⋅In, peak value: 163.84⋅In (r.m.s value 115⋅In) - Earth current transformer for earth-fault direction decision IE, 20-fold sensitivity: 1 digit = 0.00025⋅In, peak value: 8.192⋅In (r.m.s value 5.79⋅In) - Earth current transformer IE, 2-fold sensitivity: 1 digit = 0.0025⋅In, peak value: 81.92⋅In (r.m.s value 57.5⋅In) - U: 1 digit = 0.006 V, peak value: 196.61 V (r.m.s 139 V) - Bandwidth (among other things for disturbance record) 350 Hz - Frequency measurement 35... 65.53 Hz

3.8.2 Accuracy - Current stages, measured sizes, pickup value ≤ 2.5 %; 0.01⋅In

IE transformer with standard sensitivity ≤ 2.5 %; 0.005⋅In IE High-sensitivity transformer ≤ 2.5 %; 0.0005⋅In

- Impedance measurement, fault location (homogeneous line) in case of Uloop>2 V, 30°<ϕK<90° ≤ 5 % Basic error, secondary

nIAm ⋅Ω±10

- Intermittent earth fault current stage, pickup value Half-wave r.m.s value 5 %; 0.02⋅In - Voltage stages, pickup value ≤ 2.5 %; 0.01⋅Un - calculated currents, voltages

(in case of In, Un of measured variables) ≤ 5 % of the measured variable - Load unbalance protection ≤ 3 % of phase currents - Frequency protection <10 mHz - Power protection ≤ 5 %; 0.0001⋅Un⋅In - Inverse time characteristics with regard to time ≤ 5%, ±30 ms - Direction determination, phase-angle error < 3 ° - Thermal replica with regard to pickup current ≤ 2.5 % with regard to time ≤ 5 %, ±100 ms

Technical data


- Timers quartz biased ≤ 0.5 % ±2 ms

3.8.3 Influencing variables - Temperature (-10° to +55° C) < 1 % - Harmonics, integers (10%) < 1 % - Frequency, 50 Hz ± 5 %

Current, voltage starts ≤ 3 % Operating measurands ≤ 3 % Direction decision ≤ 1 ° R, X - values, fault location ≤ 1 % Thermal replica with regard to time < 7.5 % Inverse time characteristics with regard to time < 5%

- Aperiodic components on current start, switching-on of an inductance with max. aperiodic component (100%)

up to 30 ms after start, τ<50 ms/τ=50...120 ms/τ>120 ms: <17/<10/<5% after expiry of 30 ms, τ<120 ms / τ>120 ms: <10 % / <5%

- Auxiliary voltage in the range Uaux from -20 % to +10 % < 0.1 %

3.9 Operating measurands The following values (primary and secondary values) are displayed on the operating panel in the protection system's main menu: • Currents IL1, IL2, IL3, IEmeasured, IEcalculated, Inegative sequence • Voltage UL1E, UL2E, UL3E, UNE, UL12, UL23, UL31, Unegative sequence, U4 • Three-phase power values P,Q, S • Power values in the phases PL1, QL1, PL2, QL2, PL3, QL3 • cos ϕ • System frequency • if overload protection is used:

• Level of the thermal replica • Remaining time until level has reached 100% (TRIP), assuming a constant current • Duration till enabling of reclosing by the set reclosing lockout

• if temperature acquisition is used • all currently present, configured and arithmetically pre-processed temperatures.

• Earth-fault measurands (in case of earth fault, not in DD 6) • Weighting factors • Active and reactive power of zero phase-sequence system • Displacement voltage and measured earth current

• Synchrocheck measurands (only DDEY 6) • Amplitude and its difference for the two voltages • Absolute value and difference between the two frequencies • Phase difference • Supplementary information

Additionally, selected operating measurands can be displayed in the control menu in the scope of the configuration of the control software. - Accuracy:

IL: in the range up to 2⋅In greater value: 1% of measured value or 0.5% of In U: in the range up to 1.2⋅Un greater value: 1% of measured value or 0.1% of Un P, Q: (at U/Un and I/In=from 0.5 to 1.2 and |cos φ|>0.7) 2% of Sn with Sn=√3 ⋅Un⋅In

The accuracy of the values which are displayed in the protection system menu is not always en-sured due to the restriction to 2 decimal places (secondary). Internally, preciser values are proc-essed.

3.10 Statistic values

Technical data


• Phase-selective display of the primary current total at the time of issue of the TRIP command • Counting the circuit-breaker's opening operations • Counting the circuit-breaker's closing operations

3.11 Event memory - Size 32 kB

Number of average power system fault events > 1024 theoretical max. number of events of min. size 1638

3.12 Disturbance data memory - Sample rate 1 ms - Analogue variables iL1, iL2, iL3, iE (measured), uL1E, uL2E, uL3E, u4 (uNE or uS2 measured) - Tags phase-selective starts L1, L2, L3 and E, general start, starts I, (U-)I; Z<, forward direction, backward direction, assignment to zones Z1, Z1x, Z2, Z3, Z4 General TRIP, Switch-on protection start SOTF Earth fault I>Back-up operation (Em.OTP) Current negative-sequence general start Ineg> (>SOTF), i.e. Ineg>, Ineg>>, Ineg>SOTF Signal transmit, signal received of teleprotection Close by AR, AR not ready Inrush restraint: Starts blocked, I2f/I1f> Inputs PROT DI1, DI2 and DI3, virtual inputs vDI1, vDI2 and vDI3 - On generating the COMTRADE file via COMM-3, the following analogue variables calculated from the mentioned measurands are additionally provided: Instantaneous values iEcalc, iL12, iL23, iL31, uNEcalc, uL12, uL23, uL31 r.m.s values (aperiodic component-corrected) IL1corr, IL2corr, IL3corr, IEcorr, IEcalccorr UL1Ecorr, UL2Ecorr, UL3Ecorr, UNEcalccorr, UL12corr, UL23corr, UL31corr, U4corr (UNEcorr or US2corr) - Recording duration per fault or externally generated recording max. 5 s - Memory depth 15 s - Pre-fault time, adjustable 0 ... 4000 ms - Post-fault time, adjustable 0 ... 500 ms

3.13 Routine and type testing Routine testing All tests according to EN 60255-6 (IEC 60255-6) and VDE 0435 part 303, including - High-voltage test EN 60255-5 (IEC 60255-5) increased: 2.5 kV, 50 Hz, 1 s Exceptions: Power supply to ground 2.83 kV DC - Each device is subjected to an additional 24-hour alternate temperature test while in operation.

Type tests in accordance with EN 60255-6 - Impulse voltage withstand test EN 60255-5 5 kV; 1.2/50 µs; 500 Ω, 0.5J - High-voltage test EN 60255-5 2.5 kV, 50 Hz, 60 s exceptions: Power supply to ground 2.83 kV DC Mechanical and environmental tests - Vibration strain (EN 60255-21-1) - Shocks (EN 60255-21-2) - Earthquakes (EN 60255-21-3) - Heat and cold (IEC 60068-2-1, IEC 60068-2-2) - Moist heat, cyclic, constant (IEC 60068-2-30, IEC 60068-2-78)

Technical data


EMC tests in acc. with EN 60255-26 - EMC Emitted interference, EN 60255-25

Radiated emission (interference field strength) 30 ...1000 MHz Class B Conducted emission (radio interference voltage RIV) 0.15 ... 30 MHz Class B

- EMC immunity RF disturbance test (1MHz Burst), EN 60255-22-1 (2005) 1 kV / 2.5 kV

Transformer cross voltage 2.5 kV Electrostatic discharge (ESD), EN 60255-22-2 6 kV / 8 kV Electromagnetic fields, EN 60255-22-3 10 V/m Fast transients, EN 60255-22-4 Class A, 2/4 kV; 5/20 ns; 5/2.5 kHz Surge voltages, EN 60255-22-5 (2002) 0.5 / 1 / 2 kV RF conducted, EN 60255-22-6 10 V, 0.15..80 MHz, 80% AM 1kHz Line-frequency interference, EN 60255-22-7 Class A, 150 V / 300 V

Design


4 Design

4.1 Mechanical construction The protection module "PROT“ is located in a module rack which comprises as a minimum the power supply module "PS“ and the processor module "CPU“. The design solution using a sepa-rate control panel facilitates installation of the flat and light-weight control panel in doors without bulky supply cables. On the other hand, the central unit (the module rack) can be located in any position of the secondary cell. The compact design enables direct arrangement of the pluggable terminals on the front of the modules. The inputs and outputs accessible for the device's protector are located on the

• power supply module PS (binary inputs: 10xDI, relays: 4xDO, 2xAO) • protection module PROT (measurement inputs: up to 4xI, 4xU, binary inputs: 5xDI, relays:

8xDO) • control panel (LED: 24)

All inputs and outputs existing in addition to these specified ones are not accessible for the pro-tector, in order to achieve extensive hardware isolation between protection device and control unit. The protection module consists of two printed circuit boards, one of which is intended for the in-strument transformer and the other contains the circuit for preprocessing measured variables. For the dimensions of the housings and the fastening versions, please refer to the dimensional diagrams in Appendix 2 to Appendix 5. Appendix 7 shows the terminal arrangement of the mod-ules important for protection.

4.2 Control panel The control panel is connected to the processor module via a serial interface. For the user, the control panel is the most important module. It displays comprehensive informa-tion on various display screens. An important function, from the protector's point of view, is - in addition to the local control facility - accessibility to all settings. This provides future-safety for the case that in 30 years, PCs as they exist today, might be extinct. Appendix 6 shows the front of the panel with membrane keyboard, LED and LCD display.

The button can be used for access to the protection screen page among the individual screens pages. From there, menu-guidance is available through all facilities of the protection de-vice. The settings are password-protected, whereas information can be read by anybody. In addition to three firmly assigned status LEDs “Ready“ (green), “Comm“ (red) and “Local“ (green), 24 freely assignable red LEDs are available for the optical signalling of events and states. An insertable strip can be used to identify the LED assignment.

4.3 Terminals The terminals for the measured variables U and I are located on the protection module PROT. The current terminals (grey terminal housings) are distinguished by their bigger cross-section used for clamping. The voltage transformer terminals are located below the current terminals and are, like the other terminals of the PROT module, reliable, pluggable printed terminals. The auxiliary voltage must be connected to the power supply module PS whose terminal connec-tor X5 has a bigger centreline spacing in order to avoid confusion. The protective earth is con-nected on the underside of the module rack. The PC can be connected to the processor module CPU via a special cable.

Functions


5 Functions

5.1 General function The currents and voltages supplied by the instrument transformers of the system are adapted by the analogue inputs to the internal levels of the device. Apart from the electrical and low-capacitance separation, the analogue inputs are limited to a band width of approx. 340 Hz via fil-ters. Simultaneously sampling 16-bit A/D converters are used for digital measurand collection. Special measures are taken to reduce noise in the converted measured variables. The digitized measurands are pre-processed by a 32 bit microcontroller. This microcontroller only serves for protection and supplies the main processor with all the values and variables required for the various protection modules. An up-to-date real-time operating system on the main proc-essor provides for deterministic processing of all operations and functions. Utilization of a mod-ern multiprocessing philosophy ensures a large degree of independence of all the current soft-ware processes (e.g. protection process, substation control process, HMI process). The protection process covers assessment of the individual protection modules taking account of the digital inputs. The results of the protection modules are retransmitted subsequently to Re-lays, LEDs, display, Event and disturbance data memories and other software processes (substa-tion control process, HMI process).

The control panel uses its own 32 bit microcontroller. It evaluates the keyboard inputs and key lock switch positions and controls the LCD and the LED. The information is exchanged over a in-terference-proof symmetrical serial connection to the main controller of the CPU unit.

The protective settings consisting of up to four Setting Sets, events, statistic values and fault data are saved in a flash memory so that they are preserved in case of failure of the auxiliary supply. The real-time clock is supplied by storage capacitors. If there is no external clock syn-chronization, the device is provided with date and time from this real-time clock on restart.

For connection of a DDx 6 device, the phase currents IL1, IL2, IL3 and the phase-to-earth voltages UL1E, UL2E, UL3E of the object to be protected must be provided. Moreover in DDEx 6, for determi-nation of earth fault direction within the non-earthed system, the zero current IE measured with a cable-type current transformer high sensitivity is required.

The DDEY 6 equipped with a synchronizing module needs for it a reference voltage US2, which is supplied to voltage transformer U4.

An Ethernet LAN interface or serial interfaces at the central unit for connecting a PC allow com-fortable operation of the device by using operating software COMM-3. It enables the user to set all protective configurations, and to read events and fault data from the device. The latter can be represented graphically via a graphic software (SDA2), and analyzed. All settings can be made via the separated Control panel too.

An auxiliary energy supply is required to operate the device. It is transformed within the device to the internal levels by the power supply module, electrically separated and interference-suppressed.

There is a consequently separation of control and protection technology together with approved algorithms of digital signal processing provides security, offers availability and reliability at the highest possible level.

• Separated data model and processes • Separated firmware • Separated passwords • No protection check of the feeder and disconnection in the primary circuit during update

of the control parameters and control firmware necessary Modern technologies prevent mutual effects between tasks whereby as far as possible independ-ence between the applications can be achieved. So for example it is possible to load firmware and data model of the protection independent of the control part. Additionally, the operator faces a clear separation of control and protection, which allows either combined or separated operations of control and protection functions.

Functions


5.2 Switching device On and Off The protection part can be switched on and off by local operation “51300 Device On/Off“. This can be achieved additionally via the substation control if the appropriate command “51634 Cmd Prot. On/Off“ has been enabled.

! Caution:

In OFF condition, no protection modules are processed! In OFF condition, measured values are still acquired and displayed, while communication with the device is also maintained. In the event memory, all active protection modules are entered as “going” apart from being op-erative. A short report saying “Protection dead by operation at device“ or “Protection dead by remote control“ is visible with date and time. The output commands “51171 Protection ready“ and “51172 Protection dead“ can be used to signalize the state of the device via relays or LEDs. Setting: 1. The device is switched ON and OFF under “Setting Set / Setting / Setting Values / General /

Device On/Off”. 2. The substation command "Device On/Off “ is enabled under “Setting Set / Setting / Setting

Values / Comm.+SubstCtrl. / Substation control“. 3. LED outputs are configured under “Setting Set / Setting / LED / General / Device On/Off“,

Relay outputs are configured under “Setting Set / Setting / Relays / General / Device On/Off “ 4. Outputs to virtual inputs vDI are configured under “Setting Set / Setting / Cmd.-Inputs (vDI)/

General / Device On/Off “. Subsequently, setting for further utilization is effected under “Set-ting Set / Setting / Inputs / ...“.

Functions


5.3 Setting of Earth Factor For a correct measuring of the distance protection and the fault location at phase-to-earth faults it is to set the earth factor in the settings under ”System Adaptation”. In the case of system faults with phase-to-earth loops, the earth factor must be taken into con-sideration when calculating the loop impedance. The impedance is then calculated using the earth current corrected by the earth factor. Thus, the earth factor is not only more or less impor-tant for the fault location, but also for the short-circuit direction. In the frequent cases that ZE ≠ ZL, the fault location can be specified more precisely by setting the earth factor in case of phase-to-earth faults. The earth factor is set under “System Adaptation” via “501 Real Part Earth Fact“ and “502 Imag.Part Earth Fact“ Important:

If it is not possible to determine the earth factor, the setting on delivery must be kept for the earth factor (real part = 1, imaginary part = 0). In this case is ZE = ZL.

Setting: The settings can be made in menu “Setting Set / Setting / Setting Values / System Adaptation / System Adaptation”.

5.3.1 Definition of the Earth Factor The following applies to a phase-to-phase fault loop:

ZL

ZL UL1-E

UL2-E

I1

I2

UL1-E - UL2-E = I1ZL - I2ZL

21

21

IIUUZ ELEL

L −−

= −−

5-1: Phase-to-phase loop

The following applies to a phase-to-earth fault loop:

ZE

ZL UL1-E

I1

IE

UL1-E = I1ZL - IEZE = I1ZL - IE(ZE/ZL)ZL With introduction of the earth factor fE = ZE/ZL becomes UL1-E = I1ZL - fEIEZL

EE

ELL IfI

UZ⋅−

= −

1

1

5-2: Phase-to-earth fault loop

In the case of a phase-to-earth loop, the value ZL can be determined by using the earth factor fE despite ZE ≠ ZL. The earth factor can also be derived in a different fashion. Literature assumes that the following fundamental measuring set-up is used as a basis.

∼ UL-E

I’E

Fig. 5.3-1 Measurement of zero impedance

E

EL

IU

Z'00

−=

11

1100

3 ZZZf E ⋅

−= , with

EL ZZZ +⋅=31

00 and

LZZ ⋅=31

11

or

1

10

3 ZZZf E ⋅

−= , whereby Z0=ZL+3ZE and Z1=ZL

5-3: Earth factor

Functions


5.3.2 Calculation of the Earth Factor with given system data 1. Given: ZE=RE+jXE, ZL=RL+jXL

Consequently, the real part and the imaginary part of the earth factor are

22LL

LELEEr XR

XXRRf

+⋅+⋅

= 22LL

LELEEi XR

XRRXf

+⋅−⋅

= 5-4: Earth factor 1

Example: ZE=(8+j12) Ω ZL=(12+j20) Ω

62.02012

201212822 =

+⋅+⋅

=Erf , 03.02012

208121222 −=

+⋅−⋅

=Eif

2. Given: ZE= ZE

∠ϕE, ZL= ZL

∠ϕL

Consequently, the real part and the imaginary part of the earth factor are

( )LEL

EEr Z

Zf ϕϕ −⋅= cos ( )LE

L

EEi Z

Zf ϕϕ −⋅= sin 5-5: Earth factor 2

Example: ZE=14.42∠56.31 ZL=23.32∠59.04

( ) 62.004.5931.56cos32.2342.14

≈−⋅=Erf , ( ) 03.004.5931.56sin62.0 −=−⋅=Eif

3. Given: Z00=R00+jX00, Z11=R11+jX11

As applies ZL= 3⋅Z11 and ZE= Z00-Z11, can 113 R=RL ⋅ and 113 X=XL ⋅

as well as 1100 R=RRE − and 1100 X=XX E −

be determined. These values can be used to determine fEr and fEi as described in 1. Example: Z00=(12+j18.67) Z11=(4+j6.67) RE=12-4=8 and XE=18.67-6.67=12 RL=3⋅4=12 and XE=3⋅6.67=20 . Continue as described 1.

4. Given: Z00= Z00∠ϕ

00 , Z11= Z11∠ϕ

11 With ZL= 3⋅Z11

∠ϕ11 = 3⋅Z11⋅(cos ϕ11+jsin ϕ11) is

1111 cos3 ϕZRL ⋅= and 1111 sin3 ϕZXL ⋅= As well is

11110000 coscos ϕϕ ZZRE −= and 11110000 sinsin ϕϕ ZZX E −= .

With these values fEr und fEi can be determined as described in 1. Example: Z00=22.19∠57.27 Z11=7.78∠59.05 RL=3⋅7.78⋅cos(59.05°)=12 XL=3⋅7.78⋅sin(59.05°)=20 RE=22.19⋅cos(57.27°)-7.78⋅cos(59.05°)=8 XE=22.19⋅sin(57.27°)-7.78⋅sin(59.05°)=12 Continue as described 1.

5. Given: Z0=R0+jX0, Z1=R1+jX1 Because ZL= Z1 and ZE=(Z0 - Z1)/3 is

1=RRL and 1=XXL as well as

( )1031 RR=RE − and ( )103

1 XX=XE −

Thus, the components of ZL and ZE are known, from which fEr and fEi can be calculated as de-scribed in 1. Example: Z0=36+j56 Z1=12+j20 ZL= Z1=12+j20 RE= (36-12)/3=8 XE= (56-20)/3=12

Functions


Continue as described 1.

6. Given: Z0= Z0∠ϕ

0 , Z1= Z1∠ϕ

1 From ZL= Z1=Z1

∠ϕ1 = Z1⋅(cos ϕ1+jsin ϕ1) RL and XL can be calculated. Furthermore, the fol-

lowing holds

( )1100 coscos31 ϕϕ ZZRE −⋅= and ( )1100 sinsin

31 ϕϕ ZZX E −⋅=

Using these values fEr and fEi can be determined as described in 1. Example: Z0=66,57∠57,27 Z1=23,32∠59,05 ZL=23.32⋅(cos59.05°+jsin59.05°)=12+j20 RE=(66.57⋅(cos57.27°-23,32⋅(cos59.05°)/3=8 XE=(66.57⋅(sin57.27°-23,32⋅(sin59.05°)/3=12 Continue as described 1.

5.3.3 Discussion of Earth Factor application The following considerations are based on formula 5-5. Apart from the general case, three spe-cial cases for earth factor setting are considered. Case Earth factor setting in DDx 6 ZE= ZL i.e. absolute value and angle identical

fEr=1 (setting as delivered!) fEi=0

∠ϕE = ∠ϕL; ZE ≠ ZL i.e. angles identical, absolute values different

fEr=ZE/ZL since cos(ϕE -ϕL)=1 fEi=0 since sin(ϕE -ϕL)=0

∠ϕE ≠ ∠ϕL; ZE = ZL

i.e. angles different, absolute values equal fEr= cos(ϕE -ϕL) since ZE/ZL=1 fEi= sin(ϕE -ϕL) since ZE/ZL=1

∠ϕE ≠ ∠ϕL; ZE ≠ ZL

absolute value and angle different (general case) fEr (according to equation) always positive fEi (according to equation) >0 if ϕE>ϕL <0 if ϕE<ϕL

Functions


5.4 Direction Decision The protective function group "Direction Decision" is an essential component of the distance pro-tection with its part "Short Circuit Direction". It delivers the direction of the fault location in case of a pick-up, starting from the protection relay’s installation place. The direction decision is based on the relay installation location. Forward direction means thereby a fault location towards the load, reverse direction towards the busbar. In DDx 6 several direction decisions are possible: 1. Direction decision during short circuit – used in distance module and in directional phase

overcurrent-time module function group “IL> (Emerg.) OTP“ (Emergency=back-up Overcur-rent-Time Protection),

2. Direction decision during earth short-circuit fault in low-resistance earthed power systems, where no phase starting responds (only IE>starting comes) – used in function group “IE> (Emerg.) OTP“ as a back-up protection (see chapter 5.4.3)

3. Direction decision based on calculation of zero power direction in case of a short time low-resistance earthed neutral point – used in “Earth SC Direction” (Earth-Short-Circuit Direction) (see chapter 5.4.3.1)

4. Sensitive Earth-fault direction (see chapter 5.7, not in DD 6). During a starting, a direction change as well as a change-over between zero power and short-circuit direction is possible.

The in-phase connection of the current transformers is essential for the correct direction deci-sion. As the connection diagram Appendix 8 shows, the earthing point (neutral) on the line end is expected as standard. P1 (=K) and S1 (=k) point in the direction of the busbar, S2 (=l) is earthed. If the conduction directions in the current transformers of the system are exchanged (see Fig. 8.2-1, page 254), the transformer adaptation is possible in the “Equipment Adaptation” settings: “331 IL CT Earthing“ and, if exists, “333 IE CT Earthing“ from “Line End“ to “Busbar End“. These settings turn the current phase by 180°.

If the voltage path is disturbed all voltage dependent functions will be deactivated. Therefore no direction decision is made (emergency overcurrent time protection becomes active).

5.4.1 Short-Circuit Direction for distance protection (SCD) In most cases distance protection needs for its work the direction of the fault. Therefore, this function must be enabled (“1900 Short Circ.Direction“). The direction is found out from the measurands fault current and voltage, in which the voltage represents the reference pointer. To ensure a safe direction regulation, voltages which are 90° to the fault loop are used. These are usually voltages influenced by the fault little. In Table 3 on page 60 the measurands of the directional element assigned to the fault loops are indicated in comparison with the distance measuring. The loop for the direction determination is fixed by the loop choice of the distance protection (see 5.5.2.3). In earth current fault loops, the earth current corrected by the earth-fault factor is used for calculations to be able to include an-gle turns by the complex earth impedance. In one single case no voltages sufficing for the direction determination are available: At the three-pole short-line fault. A three-pole short-line fault exists, if the following applies: • three-pole IL>> start (current starting of distance module, see 5.5.1.1.1 and • three-pole ULL < Umem_min. Umem_min is the setting value “1908 Umem if ULL <“. The accompanying output command “1974 3ph. U<Umem min“ reports the underrun of this voltage setting value. In this case the di-rection determination is carried out with the help of the voltage memory. The voltage memory contains differential voltage (uL12 - uL23)hist., a reference quantity derived from the pre-error condi-tion. The fault current iL31 – vertically standing to it – forms together with the voltage memory the loop to be evaluated for fault direction. The direction decision made from the voltage memory once lasts unchanged until end of the general start or cessation of the three-pole short-line fault. If the voltage memory is not usable, then forward direction is set. This concerns mains frequency line at 50 Hz after switching on the

Functions


infeed or outgoing feeder, the first (130..) 150 ms if before with 3 poles IL < Imin (line without current flowing) and 3-pole ULL < Umem_min (line without voltage) was valid. Same applies to the first (130..) 150 ms after ready status of the protective relay. The maximum validity of the voltage memory according to fault entry (begin) can by means of setting value “1911 Validity Umem“ be provided. The choice goes by the local conditions dur-ing a three-pole close-up fault. If the mains frequency remains roughly constant, then a long valid time can be chosen. If it changes more strongly, small values are required. Reference values into dependence of the maximum frequency change speed in the fault case can be gathered from fol-lowing table:

Period of va-lidity Umem

Max. sweep rate in Hz/s for 45° angle error



100 ms 24.7 33 41 200 ms 6.2 8.2 10.3 300 ms 2.75 3.69 4.6 400 ms 1.55 2.07 2.6 500 ms 1 1.33 1.66 600 ms 0.69 0.92 1.15 700 ms 0.5 0.67 0.85 800 ms 0.39 0.52 0.65 900 ms 0.3 0.41 0.51 1000 ms 0.24 0.33 0.41 1100 ms 0.2 0.27 0.34 1200 ms 0.17 0.23 0.28 1300 ms 0.14 0.19 0.24 1400 ms 0.12 0.16 0.21 1500 ms 0.11 0.14 0.18 1600 ms 0.097 0.13 0.16 1700 ms 0.086 0.115 0.143 1800 ms 0.077 0.1 0.128 1900 ms 0.07 0.09 0.115 2000 ms 0.062 0.083 0.104 3000 ms 0.027 0.037 0.046 4000 ms 0.015 0.02 0.026 5000 ms 0.01 0.013 0.016

Fig. 5.4-1 Characteristic curve of direction decision

The characteristic curve of the direction decision is a straight line through zero (location of in-strument transformers) whose angular position is adjustable (Fig. 5.4-1). The “1905 Charact.Angle SCD“ shall allow adaptation to the to the most probable situation of the short circuits in the R-X diagram to achieve a high reliability and speed of the direction deci-sion. Nearby the direction straights (hatched limits) an extended measurement time is required for the rise of the precision. The direction straight stands vertically on the entered characteristic angle. This means character-istic angle ± 90° is the range for a forward direction decision.

Characteristic angle

R

jXforward

reverse

Direction line

Functions


A change of direction at the direction limits from forward to reverse and vice versa features a “release value“ (see 3.8), i.e. for the change of direction an additional angle must be exceeded. Every distance zones Z1,t1 ... Z4,t4 and the directional back-up time t5 a desired direction has to be assigned. The corresponding settings can be found in the protective function group "Dis-tance Module" (chapter 5.5). The direction decision can be signalled together with the appropriate output commands “1971 Short Circ.forward“ und “1972 Short Circ.reverse“. It is possible for special cases (development, test) by means of optocoupler input to block the short circuit direction determination. To this the accompanying input signal "1999 Blockage SCD" has to be used. This blockade signal is in the setting values after announcement of the in-tended connection "1998 Blockage SCD" "connected" at disposal. On the output end, the signal designated in an analogous fashion can be used for signalling pur-poses. At blockade of the direction decision and simultaneously existing starts (general start) these do not lead in the direction-dependent functions to a TRIP. Important:

At a blockade or switching off of the short circuit direction decision the distance protection is not able to trip directionally any more! It will execute only the nondirectionally adjusted stages (e.g. t6 Time Limit). The time stages of the direction-dependent distance zones operate at starts without classification of the impedance.

Setting: 1. The current transformers’ phase relation is selected under “Setting Set / Setting / Setting

Values / Equipment Adaptation / Transf. Adaptation”. 2. Neutral-point connection, setting of earth factor and direction of rotating field are to choose

in “Setting Set / Setting / Setting Values / System Adaptation / System Adaptation”. 3. The direction decision is enabled, the intended connection of a blockage signal is made and

the characteristic angle of the direction decision is set under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Direction Decision”.

4. For blockage, the required optocoupler input must be selected under “Setting Set / Setting / Inputs / Protection Modules / Direction Decision”

5. LED outputs are configured under “Setting Set / Setting / LED / Protection Modules / Direc-tion Decision” those for relays under “Setting Set / Setting / Relays / Protection Modules / Di-rection Decision”.

6. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Direction Decision”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”.

5.4.2 Short-Circuit Direction for Overcurrent-Time Protection OTP Hint:

The main application purpose of the overcurrent time protection will be the backup overcur-rent time protection which can work only nondirectionally in the case of a voltage path fault. As soon as the distance protection module is switched on, a directional operating of the over-current time protection is not possible.

At distance protection disabled (“5800 Dist (U-)I Start“, “5900 Z< Impedance Start“ and “5000 Distance Detection“ switched off) the overcurrent time protection of the protec-tive function groups “IL> (Emerg.)OTP“ (5.6.2.1) and “IE> (Emerg.)OTP“ (5.6.3.1) can work as a directional short-circuit protection. A tripping direction and time can be assigned to every single overcurrent time protection stage. The operation of the short circuit direction determination at distance protection switched off al-ready is largely identically with it in the chapter 5.4.1 described. The difference exists because

Functions


of the inactive loop selection (5.5.2.3) of distance protection. A fix phase preferential treatment becomes effective based on the remaining startings of overcurrent time protection instead. If a phase start of one phase only is present, and in case of multiple starts, the fault loop cannot be determined clearly. Thus, a set of fixed rules must be used. 1. Only single-pole I> starting:

The two phase-to phase loops, which contains the started current, will be examined after the smallest impedance. If the not started current does not reach at least the half of the started in the found loop, then is valid the phase-to earth loop of the started conductor – no deviation to the loop selection of the distance protection.

2. Multiple Current Startings: If multiple current starts exist a cyclic phase priority is used: L3 over L1, L1 over L2, L2 over L3.

Existing current starts Selected loop

IL1-IL2-IL3+EFC L3-E IL1-IL2-IL3 L3-L1 IL1-IL2+EFC L1-E IL2-IL3+EFC L2-E IL1-IL3+EFC L3-E

Table 1 Loop selection at multiple startings of overcurrent-time protection

For detecting of a fault with earth participation the Earth-Fault Criterion – EFC – described in section 5.5.2.1 will be evaluated. Hints:

• For the function module “IE> (Emerg.)OTP“ only the short-circuit direction will be deter-mined at faults with both IL and IE started. Under no circumstances becomes the earth short-circuit direction or earth-fault direction determined according to the watt-metric method!

• At a blockade or switching off of the short-circuit direction decision the overcurrent-time protection is not able to trip directionally any more. Only adjusted nondirectionally stages can trip. In this case the directional time stages belonging to the overcurrent-time protec-tion do not operate.

5.4.3 Earth Short-Circuit Direction ESCD (Zero Power Direction) In earthed systems with earth fault current limitation (low resistance earthing) or in systems in which high resistance earth-faults may occur, the earth short-circuit directional protection (direc-tional zero power time protection) is frequently used as back-up protection. This protective function is available under the one setting group "Direction Decision". It operates if only both starts earth-current IE>(>>>) and displacement voltage UNE> are active. If earth short circuits can be expected whose current intensity does not suffice for a distance start (or overcurrent-time protection phase start IL>), the zero power direction can be found out. This protection module is not available in non-earthed systems. Instead, the earth-fault direction decision must be used in this case (5.7). For zero power, the zero current iE and the displacement voltage uNE are used. Both are calculated variables by default. At the DDEY 6 the voltage instrument transformer U4 may be used to measure UNE by setting in “Equipment Adaptation / Transf. Adaptation” under “336 Usage VT U4“ to “Residual Voltage UNE“. With that “2935 Value for UNE ESCD“ can be set to “measured“, which can lead to a little increased precision of power calculation at small voltages.

The displacement voltage UNE is determined from the phase-to-earth voltages:

33

33 321

00 EEE

NEuuuuuu ++

=⋅=⋅

= 5-6: Definition calculated displacement voltage uNE

32103 LLLE iiiii ++=⋅=− 5-7: Definition calculated earth current iE

Functions


Thus, for UNE, the same values result in case of measurement of an instrument voltage trans-former with earth-fault winding: In the case of full displacement is UNE=Un. Direction calculation is based on evaluation of active and reactive power. The characteristic of the direction decision is a straight crossing zero (installation place) adjustably by its angle posi-tion (Fig. 5.4-1).

With recognizing of • an excessive displacement voltage UNE> “2902 UNEmin ESCD“ (protection module “Di-

rection Decision“) and • an exceeding of “2101 IE> Definite Time“, “2102 IE> Inverse Time“, “2201

IE>>“, “2301 IE>>>“ and/or “2401 IE>>>>“ (protection module “IE> (Emerg.)OTP“) the general start is produced and the direction determination is started.

Hint: Existing of an IE> earth-fault criterion by exceeding of “4901 IE>EFC“ or a fulfilled displace-ment voltage criterion “4905 UNE>EFC“ are no start conditions for zero power direction deci-sion.

In case of all earth-overcurrent stages, the operator can specify whether the appropriate stage is to work with or without direction decision. The corresponding settings are available in protection module “IE> (Emerg.)OTP“ (for more see section 5.6.3.1).

Special attention require the settings under “2137 IE> Start“, “2237 IE>> Start “, “2337 IE>>> Start “, “2437 IE>>>> Start “. For the use of the respective IE> starting to the zero power direction the setting on “not if IL/Dist Start“ makes sense. This prevents tripping by the earth overcurrent-time protection at a distance start.

If for the started IE>(>>>) stage the measured direction is correct and its time stage has passed a TRIP command will be requested. The direction found out can be reported with the ac-companying output commands “2971 Earth-SC forward“, “2972 Earth-SC reverse“. The start of the earth short-circuit direction determination can be signalled by the “2970 IE>,UNE>UNEmin ESCD“ output command, i.e. the existence of displacement voltage and earth current only.

The protection module “Auto-Reclose AR” can be executed if the following prerequisites are complied with:

• Zero-Power Direction decision enabled • At least one of the IE> stages for start-up of ”AR“ is enabled (Fehler! Verweisquelle

konnte nicht gefunden werden.) • This current starting stage has been started and zero power direction is available.

A determined zero power direction can also influence the protection module ”Teleprotection“ (5.12), if the required “19035 Start TP with EF/IE“ was enabled in the teleprotection func-tion.

If necessary, the earth short-circuit direction decision can be blocked via an optocoupler input. After setting “2998 Blockage ESCD” to “connected“, the appropriate input signal “2999 Blockage ESCD" must be configured for the blockage. For signalling purposes the signal desig-nated in an analogous fashion can be used.

The released earth short-circuit direction function can be reported to the outside world with “2990 EarthSCDirectFctOn“.

Important: The earth current transformer available in the DDE(Y) 6 is not used for the protective function "earth short-circuit direction protection" (ESCD).

Functions


Fig. 5.4-2 Active principle of earth short-circuit direction (definite time OTP shown)

Hint: Another helpful protective function in the case of high-impedance fault-to-earth is the dis-placement voltage-time protection, see chapter 5.13.3.

2180 tIE> expired

2170 IE> Start

IE> (Emerg.)OTP: IE>

IE> (Emerg.)OTP: IE>>

IE> (Emerg.)OTP: IE>>>

IE> (Emerg.)OTP: IE>>>>

IE > “2101 IE> Definite Time“ IE 2111 tIE>

&

forward 2131 reverse non-directional

H &

&

≥1

2971 Earth-SC forward

Direction Decision / Earth Short Circuit Direction

2972 Earth-SC reverse

ie

UNE > 2902 UNEmin ESCD

une (∑/√3)

UNE

UNE une

2935 UNE calculated measured 2970 IE>,

UNE>UNEmin ESCD

2900 Earth SC Direction

2999 Blockage ESCD &

2998 Blockage ESCD

H

enabled H

2990 EarthSCDirect FctOn

2999 Blockage ESCD

ESCD ready &

DDx 6

IL start

≥1 Distance start

2137 IE> Start

H

not if IL/Dist Start even if IL/Dist Start

only if IL/Dist Start

&

&

≥1

&

GenTRIP

connected

uL1 uL2 uL3

P, Q (une⋅ie) 2905 Charact. Angle ESCD

&

calculated

Functions


Setting: 1. Method of neutral-point connection is to input in ”Setting Set / Setting / Setting Values /

System Adaptation / System Adaptation”. 2. Release of the earth short-circuit direction determination, the intended use of a blockage sig-

nal, the characteristic angle of ESCD, the displacement voltage value “UNEmin ESCD“ and possibly selection whether UNE will be measured can be set under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Direction Decision”.

3. For blockage, the required optocoupler input must be selected under “Setting Set / Setting / Inputs / Protection Modules / Direction Decision”.

4. LED outputs are configured under “Setting Set / Setting / LED / Protection Modules / Direc-tion Decision” those for relays under “Setting Set / Setting / Relays / Protection Modules / Di-rection Decision”.

5. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Direction Decision”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”

5.4.3.1 SDLRE Automatic within the non-earthed system The special case of a temporarily earthed system is the SDRLE Automatic used in the compen-sated system. This automatic for short-duration low-resistance earthing of the neutral – SDLRE – switches on (in order to increase the active current) a resistor (or impedance) briefly during an earth fault to ensure neutral earthing. The SDLRE automatic often functions such that after a predetermined time (duration sufficient for an earth fault extinction attempt), the location must be determined for an earth fault which remains active. To this effect, the neutral is subsequently earthed briefly via a resistor, so that an increased earth current is flowing. Evaluation during earthing is possible in three ways:

• Distance protection starting with appropriate classification into the zones, • Determination of the "current path" from supply to earth fault by exceeding IE operate

values, • Determination of the zero power direction, if only an IE start is present.

The fault can be determined optimally by distance measurement. If the increase of residual cur-rent does not result in distance protection starting, the two other subsections are the solution of the problem. In case of multilateral supplies, rings have to be split up to find unambiguous current paths with IE>. If the direction information is additionally available, splitting up of rings can be avoided. It should be possible to determine the earth fault location based on the direction arrows entered into the network topology. Remark:

For change-over of the measuring loops to phase-to-earth loops for distance measurement during short-time earthing of the neutral, the earth fault criterion must be fulfilled (5.5.2.1). To this effect“4932 EarthFault if“ “IE> or UNE>EFC+asym“ must be selected, as the displacement voltage requests during neutral earthing are no longer fulfilled in many cases, but IE>EFC is exceeded.

Below, this section describes the backup protection function utilizing the zero power direction.

DDx 6 permits the combination of IE> start and direction decision. During the short-time low-resistance neutral earthing, the zero power direction which indicates the earth fault direction can be determined like in the earthed system. This is useful if the residual current increase does not result in a start of the distance protection function.

To solve this task within the protector, several protective functions must interact. This involves the functions

• Earth fault direction • Direction decision with earth short-circuit detection and • the earth-current starts of the overcurrent-time protection “IE> (Emerg.) OTP“.

Functions


Using the SDLRE automatic “532 SDLRE Automatic“ “connected“ (under “System adapta-tion“), the earth short-circuit direction setting is made accessible under “Direction decision“ and used for the time of resistance earthing (while simultaneously adjusting the earth-fault direction decision).

The earth current IE required for direction decision is calculated from the phase currents, and not measured. When connecting the device, it must be taken into consideration that a cable-type current transformer is not required for the earth fault direction decision and that the current transformer input IN need not be wired; exception: see below under “Remark”. Thus, a DD 6 - which does not have an earth current transformer - can also be used to fulfil this task.

On earth fault occurrence (resistor not switched ON), the displacement voltage set by “7002 UNE>EF“ in the protective function group “Earth fault detection“ must be exceeded, which re-sults in the start of the timer module “7014 tUNE>EF Time f. UNE>“. The timer module “7014 tUNE>EF Time f. UNE>“ of the protection module “Earth fault detection“ must be set to a duration between occurrence of earth fault and use of the SDLRE automatic. It should at least comprise the duration of the reloading procedure which is effected at higher currents. This permits to hide short-time - possibly faulty - direction decisions during the reloading procedures. The earth short-circuit direction decision is not enabled before expiry of tUNE>EF, if the setting in the protection module group “IE> (Emerg.) OTP“ under “2138 IE> Start“ (also “2238 IE>> Start“ “2338 IE>>> Start“ “2438 IE>>>> Start“) “after tUNE>EF“ was left unchanged. In case of the setting “indep. of tUNE>EF“ the zero power direction is determined immedi-ately upon occurrence of the IE start (without further distance protection starting or phase starts) and in case the “2902 UNEmin ESCD“ start is exceeded. This setting should be applied if no IE start can occur on occurrence of an earth fault or if the appropriate tIE> timer module has a suffi-ciently long setting.

Switching on the earth resistance must result in IE>(>>>) start of the DDx 6 in the protection module “IE> (Emerg.) OTP“. This start, together with the displacement voltage start “2902 UN-Emin ESCD“ (protection module group “Direction decision“) initiates the zero power direction de-cision. As the displacement voltage becomes smaller on start of earthing than in case of earth fault, the setting “2902 UNEmin ESCD“ must be exceeded; the setting “7002 UNE>EF“ is no longer complied with. Important:

On selection of IE start to “after tUNE>EF“ (“2x38 IE>.. start“) both settings “2902 UNEmin ESCD“ and “7002 UNE>EF“ should be set to the value expected when the resistor is switched ON.

The settings under “2137 IE> Start“, “2237 IE>> Start“, “2337 IE>>> Start“, “2437 IE>>>> Start“ require particular attention. Using the appropriate IE> stage for zero power di-rection requires the setting “not if IL/Dist Start“. This prevents tripping by the earth over-current-time protection in the presence of distance starting.

The determined direction can be signalled together with the appropriate output commands: “2971 Earth-SC forward“,“2972 Earth-SC reverse“. Moreover, the "start" of the earth short-circuit direction decision can be signalled via the output command “2970 IE>,UNE>UNEmin ESCD“.

Functions


Fig. 5.4-3 Active principle Earth short-circuit direction and SDLRE automatic (DT of OTP shown)

2971 Earth SC forward

&

IE > “2101 IE> Definite Time“

&

≥1

IE 2111 tIE>

Direction Decision / Earth Short Circuit Direction

&H

forward 2131 reverse non-directional

H &

&

UNE > “7002 UNE>EF“ UNE 7014 tUNE>EF

532 SDLRE Automatic

H

2972 Earth SC reverse

&

& 2930

SDLRE:TRIP by IE Dir

H

7070 Earthfault

2180 tIE> expired

2170 IE> Start

Earth-Fault Direction

IE> (Emerg.)OTP: IE >

IE> (Emerg.)OTP: IE >>

IE> (Emerg.)OTP: IE >>>

IE> (Emerg.)OTP: IE>>>>

7073 UNE>EF

Earthfault De-tection

UL1 UL2 UL3

7081 Earthfault L1

7083 Earthfault L3

7082 Earthfault L2

ie

UNE > 2902 UNEmin ESCD

une (∑/√3)

UNE

UNE une

2935 UNE calculated measured

≥1

connected

not connected

&

2138 IE> Start after tUNE>EF indep. of tUNE>ES

2970 IE>, UNE>UNEmin ESCD

P, Q (une⋅ie) 2905 Charact. Angle ESCD

&

ESCD ready

DDx 6

IL Start

≥1Distance Start

2137 IE> Start

H

not if IL/Dist Start even if IL/Dist Start


&

&

≥1

GenTRIP

uL1 uL2 uL3

IL Start

≥1Distance start

&

calculated

Functions


If a TRIP command is required by this direction decision upon expiry of the time assigned to the started IE> stage, the “2930 SDLRE:TRIP by IE Dir“ in the protection module group “Direc-tion decision“ must be enabled. This requires further settings in the protection module “IE> (Emerg.) OTP“. The direction decision (“2131 IE> Direction“,“2231..“,“2331..“,“2431..“) must be assigned to the required earth overcurrent-time protection stage, and the time “2111 tIE> Time“ (“2112..“, “2211..“, “2311..“, “2411..“) must be selected. If the correct direc-tion is available for the started stage and its timer has elapsed, a TRIP command is requested. Remarks:

If the earth current occurring during the SDLRE in the compensated system is within the measuring range of the earth current transformer of DDE(Y) 6, utilization of the “532 SDLRE Automatic“ can also be waived via adjustment - setting: “not connected“. The protection module “Earthfault Detection“ (5.7.1) will assume direction determination based on the meas-ured earth current. The earth fault can be hidden until connection of the resistor via the power setting “7001 P> resp. Q> pickup“.

Setting: 1. The device must be informed about the presence of a SDLRE automatic when using the earth

short-circuit direction decision under “Setting Set / Setting / Setting Values / System Adapta-tion / System Adaptation“.

2. The pickup value of the displacement voltage during earth fault 7002 UNE>EF and the ap-propriate timer module tUNE>EF are set in the menu “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Earthfault Detection“ upon enabling the earth-fault de-tection.

3. The start value of the earth fault current stage IE>(>>>) - like the answer to the question whether tUNE>EF must have expired for the earth fault current start and, in case of a TRIP command, for which direction the stage is to be active - can be found in the settings of the IE> overcurrent time protection “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / IE> (Emerg.) OTP“.

4. Enabling of the earth short-circuit direction decision, the intended connection of a blockage signal, the characteristic angle of the direction decision, the displacement voltage value dur-ing earthing 2902 UNEmin ESCD and a required TRIP command must be selected under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Direction De-cision“.

5. For a blockage, the required optocoupler input must be configured under “Setting Set / Set-ting / Inputs / Protection Modules / Direction Decision“.

6. The outputs to LEDs must be selected under “Setting Set / Setting / LED / Protection Mod-ules / Direction Decision“, “.../ IE> (Emerg.) OTP“ or “.../ Earthfault Detection“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Direction Deci-sion“, “.../ IE> (Emerg.) OTP“ or. “.../ EarthfaultDetection“.

7. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Direction Decision“, “.../ IE> (Emerg.) OTP“ or “.../ EarthfaultDetection“. Subsequently, setting of their further utilization is effected under "Setting Set / Setting / Inputs /..“

Functions


5.5 Distance Protection The distance protection is the main function of this multifunctional protective relay. It is a short-circuit protection with the components starting ((U-)I, Z<), loop determination, direction deci-sion, distance stages (zones) with their tripping time stages. Important:

• It is a must to use a backup protection for the case of a voltage instrument transformer fault (for instance a fuse failure), which will be detected by the measurand check module – see section 5.6.1.

• The use of the distance protection function of the DDx 6 at terminal connection of only two voltage instrument transformers in V-connection is not possible.

5.5.1 Startings of Distance Protection The distance protection function is a short-circuit protection. The DDx 6 works traditionally with startings. An existing start is the prerequisite of the output of a TRIP command. At use of the nondirectional limit time stage every start being longer than the adjusted time limit t6 leads to a TRIP command. This points to the necessity of a startings setting characterizing a fault condition in the protec-tion object. Since there are power systems in which fault conditions (short circuits) can not be separated from normal load statuses by current measurement miscellaneous startings are available.

Hint: For the emergency overcurrent-time protection (Emergency OTP = back-up OTP) separate current startings are used. The distance protection startings are ineffective at active emer-gency overcurrent-time protection.

Important:

At use of the distance protection function at least one starting must be enabled! The dis-tance protection does not work without a starting.

5.5.1.1 Current Starting, Voltage Dependent Current Starting (U-) I Startings have the task to distinguish between faults (short circuits) from normal load condition. Based on the recognized startings different loops are selected and be provided for the direction decision and the distance measuring. The start of the distance time stages is per default carried out at the same time. The (voltage dependent) current starting as an essential basis of the distance protection must be enabled with setting “5800 Dist (U-)I Start“.

Fig. 5.5-1 Characteristic of current starting (U-) I

I>> I>

ULL(I>)

ULL(I>>)

ULL / Un

I / In

Load range

Fault range

circle (Z=const)

ULE(I>)

ULE(I>>)

ULE⋅√3 / Un

1

Functions


The characteristic shows a voltage dependent (I> >) and a voltage independent (I > I>>) part. The voltage dependent range allows different settings for phase-to-earth faults. With setting “5830 (U-)I Start Program“ the starting’s operate modus is chosen. Among others voltage dependency can be switched off. The features are explained separated subsequent after a voltage independent and voltage-dependent starting

When required this starting can be blocked by means of input signal “5899 Blockage(U-)I Start“ after the intended use of the blockade input was registered with “5898 Blockage(U-)I Start“ ”connected”. For reporting purposes the signal marked uniformly is available.

5.5.1.1.1 Current Starting I>> The phase selective current starting “I>>“ is the most important starting for the distance pro-tection. The great advantage of the classic current starting is

• clear, high-speed and sure detection of short circuits • simple determination of the setting from short-circuit current computings

With setting “5830 (U-)I Start Program“ to “voltage independent“ only the tripping range is active for currents larger than I>> in Fig. 5.5-1. Setting value “5811 I>>“is the voltage independent current starting of the distance protection. The three-phase transgression of this value is besides three-phase U < Umem a characteristic for the three-pole short-line circuit ( Besides the three-phase U < Umem (“1908 Umem if ULL <“) the three-phase exceedance of this value will be used as a characteristic of the three-pole short-line fault (this then requires the use of the voltage memory for the direction determination). The current pick-up value “5811 I>>“ is set in the setting menu as secondary current referred to the secondary transformer rated current In: I>> = I/In. It must be determined from the primary current Ipr as follows (Isn and Ipn are the instrument transformer rated currents secondary and primary):

InIIprII

pn

sn

⋅⋅

>>=

If normally Isn=In (secondary rated current of instrument transformer = rated current of the de-vice chosen by terminal connection) applies the equation then simplifies:

pn

prim

II

I >>= 5-8: Current setting values

The choice of the setting value is carried out under the point of view, that it represents a short circuit obviously in the system. It must be different from load currents. To avoid wrong startings in earthed-neutral systems an I>> start can alternatively be made de-pendent on meeting the condition IL > 2/3⋅ILmax by using the setting “5831 I>> Dist Start“. In Fig. 5.5-2 a) one can use this at protection location A, in b) at both sides.

Functions


Fig. 5.5-2 Earth short circuits in systems with a not earthed neutral point

Hint: At use of the protection at place B in Fig. 5.5-2 a) the voltage-dependent starting (or Z < starting) is required to detect the faulty phase by its lower phase-to-earth voltage.

Together with a possible detection of a short circuit with earth participation (the earth-fault crite-rion is met) the started Phases form the base for the loop determination. Hint:

If a sure short circuit detection is possibly already with use of the voltage independent start-ing I >>, the more sensitive startings (U-I and Z <) should not be used.

Setting: See under following section 5.5.1.1.2

5.5.1.1.2 Voltage Dependent Current Starting U-I To detect short-circuits with currents, which cannot be distinguished from load currents (for ex-ample: very high load current and large distance to the fault or a high-resistance fault), the volt-age-dependent current starting can be used. It uses together with the current the 1.1. accompa-nying loop voltage in the range of smaller currents than the above mentioned I>>. For a current starting its loop voltage must fall below a voltage setting value – Fig. 5.5-1. In addition for a starting the measured phase current must have exceeded the adjusted value I > as prerequisite.

Fig. 5.5-3 Characteristic of voltage-dependent current starting in impedance plane

The voltage-dependent starting allows an expansion of the starting range opposite a circular Z < starting (Z=const, see following chapter). This “additional” starting range is in Fig. 5.5-1 the yel-low (darker) range above the straight line for the circle. In Fig. 5.5-3 this is the voltage-dependent hatched drawn area. Prerequisite of the range enlargement is the choice of the setting

jX

R

>>

=I

IUZ LL )(

Voltage-dependent starting

Load range >>

>>=

IIUZ LL )(

safe start (voltage independent)

Starting range

A B A B

a) b)

infeed

Functions


Z(I>) > Z(I>>) (with >>

=>IIUIZ )()( and

>>>>

=>>IIUIZ )()( ).

Setting with Z(I>) = Z(I>>) produces exactly one circle in the impedance plane. The choice Z(I>) < Z(I>>) reduces the tripping range opposite a circle in the impedance plane, however, should not have a meaning. In the aforementioned formulae the setting values “5801 I>“ stand for I>, “5811 I>>“ for I>>, “5802 ULL(I>)“ as well as “5803 ULE(I>)“ for U(I>) and both “5812 ULL(I>>)“ and “5813 ULE(I>>)“ for U(I>>). The input of voltage values “5802 ULL(I>)“, “5803 ULE(I>)“, “5812 ULL(I>>)“, “5813 ULL(I>>)“ in the setting menu is to make referred to the rated voltage: ULL> = U/Un.

For ULE applies the reference n

LELE U

UIU 3)( ⋅=> , so that for ULE=Un/√3 the value is 1.

With it voltages must be determined from the primary voltage Uprim as follows (Usn and Upn are the instrument transformer rated voltages secondary and primary)

npn

snprim UU

UUIU 1)( ⋅⋅=>

If normally Usn=Un (secondary rated voltage of instrument transformer = with setting “334 Un VT sec.“ chosen rated voltage of the device) applies the equation then simplifies:

nU

prim

pn

prim

UrU

UU

IU 1)( ⋅==> 5-9: Voltage setting values

The right side of the equation applies to the computing with the voltage transformation ratio rU.

The choice of setting value “5811 I>>“ is, that it represents a short circuit obviously in the power system. It must be different from load currents. In not solidly earthed systems take into account that the load current can enlarge because of voltage rise in healthy phases.

On the other hand “5801 I>“ is to adjust to the lowest possible short-circuit current or a little bit less. It must not be different from load currents. The distinction load-/ short-circuit current is carried out via the accompanying voltage. This must always be smaller than the voltage occur-ring at maximum operating (load) current and at smallest possible nominal voltage.

Hints: • If possible prefer a setting with roughly Z=const (starting circle for demarcation of load

range), since unwanted startings can be prevented better at faults in adjacent outgoing feeders.

• In high loaded low resistance earthed systems the voltage rise and with it higher load cur-rents at single or double pole phase-to-earth faults can be compensated in the starting characteristic by choice of a voltage > Un/√3 for “5813 ULE(I>>)“. Such a setting is not allowed in not earthed systems if “5830 (U-) I Start Program“ is chosen to “LL:ULL LE:ULL“.

For the U-I starting the fundamental behaviour can be adjusted by means of the setting “5830 (U-) I Start Program“. It is to fix whether – and if yes – which loop voltages are used for classification of an actual current value in to the characteristic (Fig. 5.5-1):

1. “voltage independent“ cause starting at I > I>> – see section 5.5.1.1.1 2. “LL:ULL LE:ULE“ uses

o for phase-to-phase (LL) faults ULL loop voltages with their operate values “5802 ULL(I>)“, “5802 ULL(I>)“ as well as

o for phase-to-earth (LE) faults ULE loop voltages with their operate values “5803 ULE(I>)“, “5813 ULE(I>>)“.

The loop voltage will switch over into dependence of the earth-fault detection. This al-lows the highest possible sensitivity for all fault types. It depends on the correct setting of the earth-fault criterion (under “Loop Determination”), most of all in not earthed sys-

Functions


tems. At a single earth fault the earth-fault criterion may not pick-up and switch over to use LE voltages (ULE≈0, which would lead to a start and a TRIP command).

3. “LL:ULL LE:ULL“ uses for faults with and without earth participation always ULL loop voltages. The earth-fault criterion does not play a role here. This setting is permitted in not earthed systems since startings by single-pole earth faults are excluded. Double pole earth faults are not always included and treated correctly. (Distance measuring of the base points requires measuring of LE loops; in the case of only one “visible“ base point the starting can be missing.)

4. “LL:ULE LE:ULE“ uses for faults with and without earth participation always ULE loop voltages. The assessment of the LE voltages be distinguished by sensitivity at earth short circuits and therefore is advisable in earthed systems. If LE voltages are exclusively evaluated it should be guaranteed that at LL faults the I>> stage operates.

5. “LL:I>> LE:ULE“ uses o for phase-to-phase faults the voltage independent current starting I>> (“5811

I>>“) as well as o for phase-to-earth faults ULE-loop voltages with their operate values “5803

ULE(I>)“, “5813 ULE(I>>)“. Only for the treatment of earth faults in low impedance earthed systems the use of the voltage dependent starting can be wished. LL faults shall be detected alone by the volt-age-independent overcurrent starting I>>.

In the following table are loop voltages assigned to currents according to chosen setting for the U-I starting:

U-I Start program Power system Earth

fault Phases with

I > I> Used

voltage Reported starts

IL1 > I>> - L1, E IL2 > I>> - L2, E

yes

IL3 > I>> - L3, E IL1 > I>> - L1 IL2 > I>> - L2

1. voltage in-dependent

only I>>

any no

IL3 > I>> - L3 L1 UL1E L1, E L2 UL2E L2, E

yes

L3 UL3E L3, E L1 UL12, UL31 L1 L2 UL23, UL12 L2

2. LL: ULL LE: ULE

any no

L3 UL31, UL23 L3 L1 UL12, UL31 L1 L2 UL23, UL12 L2

yes

L3 UL31, UL23 L3 L1 UL12, UL31 L1 L2 UL23, UL12 L2

3. LL: ULL LE: ULL

not earthed (for earthed neu-trals not recom-

mended) no L3 UL31, UL23 L3 L1 UL1E L1, E L2 UL2E L2, E

yes

L3 UL3E L3, E L1 UL1E L1 L2 UL2E L2

4. LL: ULE LE: ULE

earthed (for not earthed

not recom-mended)

no

L3 UL3E L3 L1 UL1E L1, E L2 UL2E L2, E

yes

L3 UL3E L3, E I> < ILx > - no U-I start

IL1 > I>> - L1 IL2 > I>> - L2

5. LE: ULE LL: I>>

earthed

(for not earthed not recom-mended)

no IL3 > I>> - L3

Table 2 Start programs of U-I starting

Special case: to 2., and 3.: Only a single reported start ILx leads to use of the loop voltage ULxy that led to the start as the basis for the loop to be used further.

Functions


Hints: • The correct detection of a fault with earth participation is essential for the function of the

distance protection. The accompanying settings can be found in the protection module “Loop Determination“, chapter 5.5.2.1.

• The setting “5802 ULL(I>)“ or “5803 ULE(I>)“ should always be chosen ≤ “5812 ULL(I>>)“ or “5813 ULL(I>>)“.

• For “5812 ULL(I>>)“ normally the value 0.85∙Unmin (lowest voltage in a healthy sys-tem) should not be exceeded to prevent a wrong starting of a phase not concerned at two-pole faults in the neighbour outgoing feeder or bus bar area. (A better maximum value for the not faulty phase-to-phase voltages can be determined by short circuit computing. Use this computed value instead of 0.85)

Setting: Prerequisite for settings of the protection functions are the settings of “Equipment Adaptation” and “System Adaptation”. Most important are shown in 1. and 2. 1. The per terminal connection chosen rated current of the current transformers (CT) and the

existing secondary rated voltage are to input under “Setting Set / Setting / Setting Values / Equipment Adaptation / Transf. Adaptation” Also the primary rated quantities of the instru-ment transformers can be selected for a correct measurands display.

2. Neutral-point connection and direction of rotating field are to choose in “Setting Set / Setting / Setting Values / System Adaptation / System Adaptation”.

3. The release of (U-) I starting, the intended connection of a blockage signal, the selection of a start program and possibly the fulfilment of the 2/3 current criterion as well as setting of op-erate values is made under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Dist (U-) I Start”.

4. For blockage, the required optocoupler input must be selected under “Setting Set / Setting / Inputs / Protection Modules / Dist (U-) I Start”.

5. LED outputs are configured under “Setting Set / Setting / LED / Protection Modules / Dist (U-) I Start” those for relays under “Setting Set / Setting / Relays / Protection Modules / Dist (U-) I Start”.

6. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Dist (U-) I Start”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”.

Important settings of the earth-fault criterion are described under 5.5.2 “Loop Determination”.

Functions


5.5.1.2 Angular-Dependent Polygonal Impedance Starting (Z<)

Fig. 5.5-4 Characteristic of polygonal impedance starting Z<

The angular-dependent polygonal impedance starting is more sensitive and more selective than a current starting. While currents are in the operating range of the protection object it recognizes faults because of its impedance and angle position in the area of the line’s impedance straight – outside the load range. At careful setting of the Z < - characteristic high selectivity of the starting can be reached. Particularly to the protection of long lines at which the voltage-dependent current starting is not selective sufficiently use of the angular-dependent Z< starting makes sense. As well far-reaching back-up gradings are practicable.

The impedance starting permanently supervises at most six loops (three phase-to-phase and three phase-to-earth).

Z< starting is to enable with the setting switch “5900 Z< Impedance Start“.

Its characteristic resembles a propeller of approximately vertical position. All loop impedances within the coloured (grey) “propeller” area lead to a start. The circular characteristic part delimits the load range. The impedance operate value “5901 Zs*In/A“ – related to In and Un - deter-mines the radius of the circle around the origin. It is calculated from the primary impedance Zprim and instrument transformer rated quantities – secondary Isn, Usn, primary Ipn, Upn – or the trans-formation ratios of current and voltage transformers:

AIn

rrZ

AIn

II

UUZZ

U

Iprim

sn

pn

pn

snprims ⋅⋅=⋅⋅⋅=

At a (normally existing) matching of rated currents between protection device In and secondary rated current of instrument transformers Isn the formula is simplified:

AIn

rrZ

AI

UUZZ

U

Iprim

pn

pn

snprims ⋅⋅=⋅⋅= 5-10: Setting value Zs

rI, and rU stands for transformation ratios sn

pnI I

Ir = ;

sn

pnU U

Ur =

The propeller blades are particularly (however not only) suitable for the back-up protection zone.

5901 Zs*In/A

Xr

ϕ1

Xv

RmaxLE

L-L loops L-E loops

Load range

Load range

ϕ4 ϕ2

ϕ3 RmaxLL

5904 Imin Z< at operating voltage

R

jX

Xv: “5902 Xs*In/A forward“ Xr: “5903 Xs*In/A reverse“ RmaxLL: “5909 RsmaxLL*In/A Resist.“ RmaxLE: “5919 RsmaxLE*In/A Resist.“

RmaxLE RmaxLL

Functions


Its two setting values of the reactance axis “5902 Xs*In/A forward“ and “5903 Xs*In/A reverse“ determine themselves from the primary values:

AIn

rrX

AI

UUXX

U

Iprim

pn

pn

snprims ⋅⋅=⋅⋅= 5-11: Setting value Xs

with XPrim: primary reactance (for the single line length without return line)

Unlike the X values the R operate values “5909 RsmaxLL*In/A“ and “5919 RsmaxLE*In/A“ are symmetrically to the reactance axis. They allow different settings for phase-to phase (LL) and phase-to-earth (LE) faults. Equation 5-11 applies analogously to the determination of the R set-ting value from primary quantities. The angular data are measured according to Fig. 5.5-4 from the real axis each. There are sepa-rated angular settings for phase-to-phase and phase-to-earth loops:

• “5905 Angle ZLL I.Quadr.“, “5915 Angle ZLE I.Quadr.“ in 1st quadrant • “5906 Angle ZLL II.Quadr.“, “5916 Angle ZLE II.Quadr.“ 2nd quadrant • “5907 Angle ZLL III.Quadr.“, “5917 Angle ZLE III.Quadr.“ 3rd quadrant • “5908 Angle ZLL IV.Quadr.“, “5918 Angle ZLE IV.Quadr.“ 4th quadrant.

In case of phase-to-earth loops, the arcing reserve (outside the part of the circular-arc curve) can be influenced by it.

Hint: At a numeric distance protection equipment always only the single length is to take into ac-count for the distance details (Z, R, X) and not in addition the return line

The operate value “5904 Imin Z<“ releases the impedance starting at higher currents. Both cur-rents of a loop must exceed this value. This setting value has to be chosen smaller than the smallest possible short-circuit current. It appears to be circle for the area of the permitted operat-ing voltages around the origin in the R-X plane (outer circle in Fig. 5.5-4) and therefore has to be coordinated with the corners of the polygonal Z< characteristic. That means there are settings possible at which the corners of the polyline could lie outside the starting range which is limited by “Imin Z<“.

With “5930 Z< Monitoring of:“ can be adjusted, which loops ate checked. The choice in-sists

1. “LL+LE loops“ phase-to-phase and phase to-earth loops This is the most sensitive start setting for all system neutral treatments. In dependence of a short-circuit detection with earth participation or a double-earth fault (in not earthed systems) phase-to-earth loops will be allowed. However, this presupposes primarily the correct setting of the earth fault detection in the not earthed net. The setting for this can be found under “Loop Determination”. At a sin-gle earth fault the earth-fault criterion may not operate und with it allowing LE loops (ULE≈0, which would lead to a start and TRIP). Phase to phase loops are unrestricted able to start.

2. “only LL loops “ This setting is appropriately utilizable in not earthed systems. Ground faults cannot create a loop start. Double earth faults are not always included and treated correctly, though (distance measuring of the base points require measurement of phase-to-earth loops if earth participation exists. In case of only one visible base point a start is missing.)

3. “only LE loops“ The only supervision of LE loops can be advisable in an earthed system if the earth cur-rent is limited (low impedance earthing). Phase-to-earth faults can be detected sensi-tively. For the recognition of phase-to-phase faults the current starting I>> is responsi-ble at this selection. For phase-to-earth faults, which shall be detected by the Z< start-ing, the earth-fault criterion has to be fulfilled (setting under “Loop Determination”). This has to be taken into account at the setting.

Since loop currents and voltages are evaluated regarding the impedance, it comes as a result of short circuits to interferences of also healthy loops. Their impedance gets just as smaller and can get into the start range.

Functions


To exclude these “seeming loops”, all loop impedances are checked for underrun of the value provided with 1.5·Zmin. Zmin is the smallest fault impedance found out. If the loop impedances are greater, they are excluded.

After releasing “5998 Blockage Z<“ with “connected” it is possible by means of binary input to block the impedance starting Z<. The input signal “5999 Blockage Z<“ has to be used for it. The output command with the same name is used for reporting purposes. With the output command “5990 Z< Start FctOn“ an unlocked impedance starting is sig-nalled. Setting: Prerequisite for settings of the protection functions are the settings of “Equipment Adaptation” and “System Adaptation”. Most important are shown in 1. and 2. 1. The per terminal connection chosen rated current of the current transformers (CT) and the

existing secondary rated voltage are to input under “Setting Set / Setting / Setting Values / Equipment Adaptation / Transf. Adaptation” Also the primary rated quantities of the instru-ment transformers can be selected for a correct measurands display.

2. Neutral-point connection and direction of rotating field are to choose in “Setting Set / Setting / Setting Values / System Adaptation / System Adaptation”.

3. The release of Z< starting, the intended connection of a blockage signal, the selection of the loops to be supervised, the minimum current Imin for a start as well as setting of the charac-teristic/operate values is made under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Z< Start”.

4. For blockage, the required optocoupler input must be selected under “Setting Set / Setting / Inputs / Protection Modules / Z< Start”.

5. LED outputs are configured under “Setting Set / Setting / LED / Protection Modules / Z< Start” those for relays under “Setting Set / Setting / Relays / Protection Modules / Z< Start”.

6. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Z< Start”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”

Important settings of the earth-fault criterion are described under 5.5.2 “Loop Determination”.

Functions


5.5.2 Loop Determination The protection function group "Loop Determination" accomplishes three important tasks for the distance protection:

1. Determination of an existing earth short circuit (short circuit with earth participation, double earth fault) by fulfilment of the earth fault criterion and with that control of the distance protection startings

2. Prevention of a single-pole start during the begin of an earth fault by means of time stage “t1p”

3. At several started fault loops selection of the loop to be measured for direction decision, distance determination and fault locator – loop selection.

The individual functions are described in the following sections.

5.5.2.1 Earth Short Circuit Detection – Earth Fault Criterion (EFC) For the correct impedance determination of the short circuit location it is essential to recognize whether a fault is with ground participation or not. In dependence of it

• starting and tripping characteristics will switch to phase-to-earth faults, • fault loops will be determined – LL or LE loops, • it will be distinguished between earth fault and double earth fault.

For the detection of an earth fault exists • earth current starting (can be disabled by “4900 IE>EarthFaultCrit.“) and • Displacement voltage starting (can be disabled by “4930 UNE>EarthFaultCrit.“)

5.5.2.1.1 Earth-Current Starting IE>EFC In the earth-current starting of the earth-fault criterion (EFC) the effective value of the earth cur-rent, which is calculated as a geometrical sum of the three phases, is checked on transgression of the adjusted value “4901 IE>EFC“. The operate value can be biased against spurious starts that is able to occur because of instru-ment transformer errors, for example. The resetting ratio is adjustable - “4904 Reset Ratio IE>EFC“ – and refers to the biased op-erate value IE’>EFC. At a potentially possible transformer saturation (high short-circuit currents, high burden) a release of this important starting can be prevented.

To bias this earth-current starting the operate value will be increased depending on the sum of the phase currents which have exceeded the pickup value “4902 Bias.IE>EFC from IL“. With this setting has to be safeguarded that the biasing begins only in current ranges in which an enlargement of the transformer errors can be expected. The sensitivity at smaller phase currents remains unchanged fully.

All three phase currents have exceeded the value “4902 Bias.IE>EFC from IL“ then is:

IE'>EFC = IE>EFC + ks ∙ (IL1 + IL2 + IL3 - 3∙Ibias) 5-12: Biasing IE>EFC a)

If only two phase currents have exceeded the value biasing is reduced:

IE'>EFC = IE>EFC + ks ∙ (ILX + ILY - 2∙Ibias) 5-13: Biasing IE>EFC b)

One phase current has exceeded the value:

IE'>EFC = IE>EFC + ks ∙ (ILX – Ibias) 5-14: Biasing IE>EFC c)

with IE'>EFC : biased operate value of the earth-fault current stage IE>EFC : set operate value of the earth-fault current stage “4901 IE>EFC“ ks : Setting of biasing factor “4903 Bias.Factor IE>EFC“ IL1,IL2,IL3,ILx,ILy : r.m.s. value of phase currents, x,y=[1,2,3]

Functions


Ibias : Setting “4902 Bias.IE>EFC from IL“ The biasing effect is thus most intense for 3-pole short-circuits. This is desirable, as different aperiodic components in the transformers may give rise to various transformer faults. Hints for setting of the biasing factor and of IE>EFC: If a single-pole short-circuit exists, a short-circuit current of x times the r.m.s. value of the set-ting Ibias is present and in this context, the pickup value IE’>EFC shall be increased to y times its setting then chose:

( )( ) bias

E

IxEFCIyks

⋅−>⋅−

=1

1

The most straightforward case exists if the pickup value IE>EFC is to increase by the same ratio as the short-circuit current changes with reference to the setting Ibias. Whereby y=x:

bias

E

IEFCIks >

= .

The earth-current starting IE>EFC has to be adjusted a little below the earth currents be ex-pected at least in the system at short circuits. The setting of the operate value IE>EFC makes sense in isolated/compensated systems on values which occur in the double earth-fault case. To the report of an earth current start IE>EFC the output command “4970 IE>EFC Start“ can be used.

When required the IE earth-fault criterion can be blocked by means of input signal “4999 Block-age IE>EFC“ after the intended use of the blockade input was registered with “4998 Blockage IE>EFC“ ”connected”. To the output the signal marked uniformly is available for reporting pur-poses. With the output command “4990 IE>EFC FctOn“ an unlocked IE>EFC function is signalled. Hints:

• The integrated earth-current transformer of the DDE(Y) 6 is not used for this function. The earth-current starting IE>EFC works with calculated current generally.

• An earth-current start IE>EFC alone, i.e. without further phase-current starts does not cause general start and is judged as an error in the current path (measurand supervision)

Setting: Prerequisite for settings of the protection functions are the settings of “Equipment Adaptation” and “System Adaptation”. 1. An inhibition of the earth-fault criterion based on the earth fault, the intended use of a block-

ing signal, operate value, biasing factor as well as resetting ration may be done under “Set-ting Set / Setting / Setting Values / Protection Modules / Character. setx / Loop Determina-tion”.

2. For blockage, the required optocoupler input must be selected under “Setting Set / Setting / Inputs / Protection Modules / Loop Determination”.

3. The surely seldom required outputs on LED are configured under “Setting Set / Setting / LED / Protection Modules / Loop Determination” those for relays under “Setting Set / Setting / Re-lays / Protection Modules / Loop Determination”

4. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Loop Determination”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”

Functions


Biasing - IL1 = IL2 = IL3 > Ibias

0

5

10

15

20

25

30

0 2 4 6 8 10 12 14 16 18 20 I

IE' >

Parameter: ks

IE>

Ibias

0.5

0.4

0.3

0.2

0.1

0.05

0

Fig. 5.5-5 Earth-current biasing if three-pole IL > Ibias

Functions


Biasing – dependent on number of phases with I > Ibias

0

5

10

15

20

25

0 2 4 6 8 10 12 14 16 18 20 I

IE’ >

ks=0

ks=0,4; 3 phases started

ks=0,4; 2 phases started

ks=0.4; 1 phase started

ks=0.1; 3 phases started

ks=0.1; 2 phases started

ks=0.1; 1 phase started

IE>

Ibias

Fig. 5.5-6 Earth-current biasing, comparison one, two and three-phase IL > Ibias

Functions


5.5.2.1.2 Displacement Voltage Starting UNE>EFC The displacement voltage UNE of DDx 6 devices will be calculated from the three phase-to-earth voltages (5-6):

33

33 321

00 EEE

NEuuu

UU

U++

=⋅=⋅

=

With this definition of the UNE the equal values result as in case of measuring at an earth-fault voltage transformer (e.g. 100/3 winding): At full displacement is UNE=Un (rated voltage).

This displacement voltage starting is an important additional bin for the detection of a fault with earth participation. Its operate value is to set with “4905 UNE>EFC“.

In cases in which the earth current sufficiently for certain represents the earth-fault criterion (e.g. earthed system) the displacement voltage starting “4930 UNE>EarthFaultCrit.“ may be switched off.

In dependence of the treatment of system neutral there are different favourable combinations to-gether with the earth-current starting IE>EFC to achieve a sure and reliable detection of earth short circuits (even double earth faults). These combinations are configurable with the switch “4931 EarthFault if“ in earthed systems or “4932 EarthFault if“ in not earthed sys-tems.

Earthed neutral Not earthed neutral a) IE>EFC or UNE>EFC IE>and UNE>EFC+asym b) IE>EFC and UNE>EFC IE> and UNE>EFC c) ⎯ IE> or UNE>EFC+asym

Settings a) are the default settings which make sure the earth-fault detection in most cases.

A fault-to-earth is always identifiable in the earthed system at recognizing an IE>EFC starting or the UNE>EFC starting.

At low impedance earth neutral systems the being of both exceeding simultaneously b) can be used which is an increased requirement. An IE> start created by error currents (transducer error, saturation) does not suffice to evaluate phase-to-earth loops.

In the not earthed system it is important that single pole earth faults do not produce the earth-fault criterion. Otherwise this could switchover on assessment of the phase-to-earth loops and with an ULE ≈ 0 this causes the unwanted tripping of the distance protection.

However, the earth-fault message shall come in the case of double earth faults most to be able to execute the double earth-fault treatment. As a differentiator between earth-fault and double earth-fault is

• the unbalance of the phase-to-phase voltages at the latter utilizable. • Another ULE must in addition have a voltage rise, i.e. it must be at least 0.6-fold of the

maximum measured ULL.

If in the double earth-fault case the voltage unbalance is distinctive too little at the protection in-stallation place (low-impedance feeding), the unbalance requirement on the voltage can with the setting b) be switched off.

The choice of the alternative setting c) is even more sensitive. It allows the starting alone by the displacement voltage at double earth-faults with small earth currents which do not suffice for the IE>EFC start. Is an automatic short time (duration) low resistance earthing (SDLRE) used in the unearthed neu-tral system select “IE> or UNE>EFC+asym“ because the displacement voltage requirements are not fulfilled in many cases during duration of the neutrals resistance earthing. The IE>EFC will exist. The required unbalance, which is an important distinction between the symmetrical ULL voltage system at a single earth fault and the asymmetrical at a double earth fault, is to choose with the

Functions


setting “4906 ULLmax/ULLmin asym.“. With that operational voltage unbalance can be taken into account so that it cannot lead to starts.

The output command “4971 UNE>EFC Start“ can be used to the report of a displacement volt-age start.

If necessary, the UNE earth-fault criterion can be blocked via an optocoupler input. After setting “4996 Blockage UNE>EFC“ to “connected“, the appropriate input signal “4997 Blockage UNE>EFC“ must be configured for the blockage. For signalling purposes the signal designated in an analogous fashion can be used.

The released UNE>EFC function can be reported to the outside world with “4991 UNE>EFC FctOn“.

Hints: • Also with choice “336 Usage VT4“ as “Residual Voltage UNE“ in the “Transformer Ad-

aptation” the UNE will be calculated for this function always. • Voltage transformers in V-connection are not allowed for distance protection. • In this distance protection there are several differently used UNE> startings and their accom-

panying reports (UNE>Check, UNE>, UNE>>, UNE>EF, UNEmin ESCD). The UNE of the earth-fault criterion is marked as “UNE>EFC“.

Setting: Prerequisite for settings of the protection functions are the settings of “Equipment Adaptation” and “System Adaptation”. 1. An inhibition of the earth-fault criterion based on displacement voltage, the intended connec-

tion of a blockage signal, adjusting the operate value, the kind of IE>EFC with UNE>EFC combination as well as the setting of voltage asymmetry characterizing a double earth fault is made under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Loop Determination”.

2. For blockage, the required optocoupler input must be selected under “Setting Set / Setting / Inputs / Protection Modules / Loop Determination”.

3. LED outputs are configured under “Setting Set / Setting / LED / Protection Modules / Loop Determination” those for relays under “Setting Set / Setting / Relays / Protection Modules / Loop Determination”.

4. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Loop Determination”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”.

5.5.2.2 Suppression of Single-Pole Starts at Begin of an Earth Fault – t1p In isolated or resonant-earthed systems (setting “531 System Neutral“) a timer “4911 t1p at 1pole Start“ is used. During its running time this has the task to suppress a distance pro-tection start due to exceeding the operate values of

• only one phase start of (U-)I or • only one phase-to-earth loop of Z<.

During this time such starts are not reported. This delay can be used to "skip“ the distance start due to the starting threshold being exceeded for a short time in case of a beginning earth fault. The timer “t1p“ is cancelled immediately as soon as another phase current start is detected or an earth fault is signalled. It is not started if an earth fault had been signalled previously by the function “Earthfault Detection”. According to the duration of the transients in the real system causing the start, the time t1p has to be adjusted and as short as possible. The earth-fault recognition time “tUNE>EF Time f. UNE>“ should be as adjusted longer than t1p to avoid races.

Functions


Fig. 5.5-7 Effect of timer t1p on distance protection starting

Setting: Timer “4911 t1p at 1pole Start“ is to adjust under “Setting Set / Setting / Setting Val-ues / Protection Modules / Character. setx / Loop Determination.

5.5.2.3 Loop Selection The released distance module startings – (U-) I start and Z< – determine the started loops or phases. The fault loop to be measured and the loop for the direction decision (90° wiring) must be se-lected into dependence of the existing starts. The measurands used for the direction determina-tion and the distance calculation are compared at predefined loops in Table 3 For the distance determination the fault loop is always selected. The direction decision uses third voltages (not involved with the fault). Loop Distance determination Direction decision L1-E iL1E and uL1E iL1E and uL23 L2-E iL2E and uL2E iL2E and uL31 L3-E iL3E and uL3E iL3E and uL12 L1-L2 iL12 and uL12 iL12 and (uL23 - uL31) L2-L3 iL23 and uL23 iL23 and (uL31 - uL12) L3-L1, short-line fault iL31 and uL31 iL31 and (uL12 - uL23)

Table 3 Assignment of loops to measurands for distance and direction determination

If a phase start of one phase only is present without a filled earth-fault criterion, and in case of multiple starts, the fault loop cannot be determined clearly. Thus, a set of fixed rules must be used: 1. Only single-pole (U-) I start without earth participation:

The protective relay is looking for the loop seeming the most probable automatically. The both phase-to-phase loops containing the stated current are examined after the smallest impedance Zmin. If in the found loop the not started current does not reach at least the half of started cur-rent, then the phase-to–earth loop of the started current is valid.

2. Multiple starts: The choice of the fault loop is carried out according to the chosen setting after a selection program or the conductor loop with the smallest impedance is selected (more in the following chapters 5.5.2.3.1 and 5.5.2.3.2).

Starts of distance module

(U-) I

Z<

j

iL1 iL2 iL3

4911 t1p

1

531 System Neutral: earthed

&n

&

uL1 uL2 uL3

only 1x L-E loop and no earth fault before?

j

n

uL12 uL23 uL31 Release starts

IL> single pole and no earth fault before?

DDx 6

Functions


The advantage of firm selection programs is that the distance relay working on the other side of the line chooses the same loop. This makes sense at use oft he functions automatic reclos-ing (AR) and teleprotection (signal comparison).

3. Three pole short-line fault In the case of the three-pole short-line fault the loop L3-L1 is selected for the distance deter-mination generally. For the direction decision the voltage memory will be used (see Table 3). A three pole short-line fault is characterized by the start of all three I>> startings or all loop startings together with the collapse of all phase-to-phase voltages below “1908 Umem if ULL <“ (module “Direction Decision”).

When required the loop chosen by the protection can be made visible on LED or be put on other outputs by means of the output commands “4981 loop selection 1E“ ... “4986 loop se-lection 31“.

Hint: The distance relays at each end of the line to be protected should have the same loop selec-tion settings.

Setting: Prerequisite for settings of the protection functions are the settings of “Equipment Adaptation” and “System Adaptation”. 1. The phase preference for two and three-pole faults can be chosen under “Setting Set / Set-

ting / Setting Values / Protection Modules / Character. setx / Loop Determination”. 2. Desired outputs of the selected loop on LED are configured under “Setting Set / Setting / LED

/ Protection Modules / Loop Determination” those for relays under “Setting Set / Setting / Re-lays / Protection Modules / Loop Determination”.

3. Perhaps desired outputs on the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Loop Determination”. Subsequently, setting for further utilization is effected under “Setting Set / Setting / Inputs / ..”.

5.5.2.3.1 Selection Programs for Earthed Neutral Systems For two-pole phase-to-earth faults “4933 Loop 2pol.+E“ and three-pole faults “4934 Loop 3pol.“ a separate setting of the selection program can be carried out. The default setting “Smallest Impedance“ selects the loop with the smallest impedance for calculation of the fault. If there is no obviously smallest impedance (differences < 10%), then the loop is chosen with the smallest loop number (L1-L2 before L2-L3 before L3-L1, or at earth faults L1-E before L2-E before L3-E). The possible loop selections are listed in Table 4 and Table 5. The cases mentioned already are not contained in it:

• Setting “Smallest Impedance“ and • three-pole short-line fault at which the loop L3-L1 is assigned generally.

Existing two-pole starts LL-loop LE-loop leading

LE-loop lagging

L1-L2, L2-L3 Zmin Zmin Zmin L2-L3, L3-L1 Zmin Zmin Zmin L3-L1, L1-L2 Zmin Zmin Zmin L1-L2-E or L1-E, L2-E (L1-L2) L1-L2 L1-E L2-E L2-L3-E or L2-E, L3-E (L2-L3) L2-L3 L2-E L3-E L1-L3-E or L3-E, L1-E (L3-L1) L3-L1 L3-E L1-E

Table 4 Loop selection for two-pole faults in earthed neutral systems

Table 4 contains preferential treatments that is selected with “4933 Loop 2pol.+E“, while Table 5 describes the setting variants of “4934 Loop 3pol.“.

Functions


Existing three-pole starts Always L3-L1

3xLE:L1-E otherwise

L3-L1

3xLE:L3-E otherwise

L3-L1 L1-L2-L3-E or L1-E, L2-E, L3-E (L1-L2, L2-L3, L3-L1) L3-L1 L1-E L3-E L1-L2-L3 or L1-L2, L2-L3, L3-L1 L3-L1 L3-L1 L3-L1

Table 5 Loop selection for three-pole faults in earthed neutral systems

5.5.2.3.2 Selection Programs for Not Earthed Neutral Systems There are two fundamental selection program types for determining the loop at multipole starts in isolated or resonant earthed neutral systems: • cyclical phase selection • acyclical phase selection. The choice of the programme is carried out for bipolar faults with “4935 Loop 2pol.“ and for three-pole faults with “4936 Loop 3pol.“.

At the cyclical phase preferential treatment the phases to be selected remain in their cyclical or-der (leading, lagging). By setting one can decide at multipole starts between the variants L1 be-fore L3, L3 before L2, L2 before L1 and L3 before L1, L1 before L2, L2 before L3.

The choice of loops depending on the recognized starts is represented in Table 6. Existing starts L1-L3-L2-L1 L3-L1-L2-L3 L1-L2-L3-E or L1-E, L2-E, L3-E (L1-L2, L2-L3, L3-L1) L1-E L3-E L1-L2-L3 or L1-L2, L2-L3, L3-L1 L3-L1 L3-L1 L1-L2, L2-L3 L1-L2 L2-L3 L2-L3, L3-L1 L3-L1 L2-L3 L3-L1, L1-L2 L3-L1 L3-L1 L1-L2-E or L1-E, L2-E (L1-L2) L2-E L1-E L2-L3-E or L2-E, L3-E (L2-L3) L3-E L2-E L1-L3-E or L3-E, L1-E (L3-L1) L1-E L3-E

Table 6 Loop selection at cyclical phase preferential

At the acyclic phase preferential treatment the conductors to be selected are determined by dif-ferent selectable rules independently of their cyclical order. The acyclic loop selection offers three fundamental programmes into dependence of the phase to be preferred: • preferential phase is L3 • preferential phase is L2 • preferential phase is L1 The respectively further preferential treatment order, clockwise or anti-clockwise phase se-quence, is selectable with “4935 Loop 2pol.“ per phase.

1. Acyclic loop selection, L1 preferred It can be decided at multi-pole starts between the preferential treatment versions L1-L2-L3 and L1-L3-L2. This results in loop selection shown in Table 7.

Functions


Existing starts L1-L2-L3 L1-L3-L2 L1-L2-L3-E or L1-E, L2-E, L3-E (L1-L2, L2-L3, L3-L1) L1-E L1-E L1-L2-L3 or L1-L2, L2-L3, L3-L1 L1-L2 L3-L1 L1-L2, L2-L3 L1-L2 L1-L2 L2-L3, L3-L1 L3-L1 L3-L1 L3-L1, L1-L2 L1-L2 L3-L1 L1-L2-E or L1-E, L2-E (L1-L2) L1-E L1-E L2-L3-E or L2-E, L3-E (L2-L3) L2-E L3-E L1-L3-E or L3-E, L1-E (L3-L1) L1-E L1-E

Table 7 Loop selection at acyclical phase preferential of phase L1







Functions


5.5.3 Distance Module The main task of the distance module is to evaluate the impedance of the selected loop and to classify it into a distance zone. After classification and passing of the distance zone’s time stage a TRIP command will be requested. The following grading stages exist: • grading stage Z1,t1 • overreach stage Z1x,t1x • grading stages Z2,t2, Z3,t3 and Z4,t4 • directional backup time stage t5 and • time limit t6. Each distance stage can be switched on or off separate (“5100 Zone Z1,t1“, “5200 ..“ , “5300 ..“ , “5400 ..“ , “5500 ..“ , “5600 ..“ , “5700 ..“. All distance stages can be switched off together with the switch “5000 Distance Detection“. With the exception of the nondirectional time limit stage t6 for any enabled grading stage it can be selected by using “5131 Direction Z1,t1“, “5231 Direction Z1x,t1x“, “5331 Di-rection Z2,t2“, “5431 Direction Z3,t3“, “5531 Direction Z4,t4“, “5631 Direction t5“ whether it shall measure in forward direction (in direction of the load) or in reverse direction (in direction of busbar) or in both directions (nondirectionally). If necessary, each distance stage can be blocked via an optocoupler input. After setting “5198 Blockage Z1,t1“, “5298 Blockage Z1x,t1x“, “5398 Blockage Z2,t2“, “5498 Blockage Z3,t3“, “5598 Blockage Z4,t4“, “5698 Blockage t5“ or “5798 Blockage t6“ to “en-abled“, the appropriate input signal “5199 Blockage Z1,t1“ (“5299 ..“, “5399 ..“, “5499 ..“, “5599 ..“, “5699 ..“, “5799 ..“) must be configured for the blockage. For signalling purposes the signal designated in an analogous fashion can be used. Hints: • The shortest operate time for tripping (within a 50 Hz period) is possible by using the phase

overcurrent-time module (chapter Fehler! Verweisquelle konnte nicht gefunden werden.). Prerequisite is that the chosen current operate value can be exceeded only in case of short circuits in the <100% protected area and in addition not at faults in reverse direction.

• With recognizing an error in the voltage path the distance protection gets inactive and the backup (emergency) overcurrent-time protection activates (if enabled).

Procedure of the classification into grading stages When a distance start comes the time stages of all enabled grading stages will run presupposed setting “5030 Time Start“ is “with General Start“ (default setting). The start of the zone time stage can alternatively be carried out with classification of the impedance into the zone. A distance start must of course exist also for this. The distance module requests a TRIP command if a valid classification of the measured imped-ance into the distance zone exists and the zone time stage has passed. At observation of an im-pedance within a zone whose time stage has already passed the TRIP command is immediately requested. Exception: setting “5030 Time Start“ to “with Zone Start“ since with imped-ance classification into a zone its timer is started new. Hint:

It is recommended to use an additional further reaching back-up stage at setting “5030 Time Start“ “with Zone Start“. In the case of a fault with impedance at the zone border it can come to multiple change between classification and leaving the distance zone again, which always restarts the zone time stage. In the extreme case this stage would never trip. How-ever, a back-up distance zone always has the time stage run.

Functions


Fig. 5.5-8 Comparison of zone times start settings at zone changes of measured impedance

5.5.3.1 Distance zones Z1,t1; Z2,t2 to Z4,t4 Zone Z1,t1 is provided for the use as the first and most important distance zone having the short-est tripping time t1 = “5111 t1 Time Zone Z1“. The other distance zones Z2,t2, Z3,t3 and Z4,t4 are used for back-up grading most. A grading in forward and reverse direction with use of several stages (zones) is possible. To this the desired direction or also "nondirectionally" can be selected (“5131 Direction Z1,t1“, “5331 Direction Z2,t2“, “5431 Direction Z3,t3“, “5531 Direction Z4,t4“).

5.5.3.2 Distance zone Z1x,t1x The distance zone Z1x,t1x is used as an overreach zone principally, however, it also can when re-quired be used as a grading zone. Its time stage “5211 t1 Time Zone Z1x“ has to be adjusted according to the intended use. As an overreach zone Z1x,t1x can be used for • Automatic reclosing AR, • distance dependent “Switch-On Protection” with setting ”8430 TRIP SOTF undelayed” “if

Z in Z1x“, • Teleprotection (signal comparison) or • Combination from AR and teleprotection. The use of the overreach zone is controlled by the respective function. Corresponding setting notes for the time t1x can be found in the respective function. A short-time or also permanent activation of this zone is possibly additional by means of the in-put signal “5260 Signal Z1x,t1x“. For example at an open circuit breaker of the opposite side overreaching can be activated with that, what leads to a measuring of 100% Line length. After setting “5230 Signal Z1x,t1x“ to “connected“, the appropriate the physical input can be assigned to signal “5260 Signal Z1x,t1x“. At a permanent activation the zone is usable like a grading zone. The constant activation can be made by configuring of an unused virtual binary input (vDI) negated (N) to the signal “5260 Signal Z1x,t1x“. Of course the physical input of an optocoupler also can be used for control-ling this signal instead of the vDI. Hint:

When during an automatic reclosing cycle the “5260 Signal Z1x,t1x“ becomes active this does not have influence on the process of the AR.

Z3

Z2

TRIP

TRIP

t GS

t3

t3

t2

t2

Time passed Time not passed

Z3

Z2

TRIP

TRIP

t GS

t3

t3

t2

t2

Start t with zone classification

Start t with general start

Start t with general start

Start t with zone classification

Z1 Z1

Behaviour in the border area GS: general start

Functions


A signal “5260 Signal Z1x,t1x“ arriving before the AR cycle starts and a corresponding fault leads to the definite TRIP command in Z1x,t1x without starting the automatic reclosing. In this case Z1x, t1x even works parallel to the other protection modules that use Z1x, t1x as an overreach zone (Switch-On Protection, Teleprotection). This signal should not be used at application of “Auto Reclose” and “Teleprotection”.

5.5.3.3 Directional Backup Time t5 and Time Limit t6 The grading condition of the directional back-up time stage is fulfilled, if – after expiry of the grading time t5 “5611 t5 Dir.Backup Time“ – the measured direction decision corresponds to the set one. The grading condition of the time limit is fulfilled after expiration of the grading time t6 “5711 t6 Time Limit“ and still exists a start of the distance module.

5.5.3.4 Characteristic of the Distance Zones The distance zones have a characteristic curve as shown in Fig. 5.5-9. As collective setting values of all distance zones have effect: • Characteristic (interior) angle ϕ i “1905 Charact.Angle SCD“ of the short-circuit direction

decision to define the position of direction straight line. The direction straight separates for-ward from reverse direction and stands vertically on the entered characteristic angle ϕ i (see 5.4.1).

• Angle of inclination α of polygons “5001 Inclin.Angle Polygon“. Each distance zone Zx has following setting values: • Secondary reactance X (“5101 X1s*In/A Reactance“, “5201 X1xs*In/A Reactance“,

“5301 X2s*In/A Reactance“, “5401 X3s*In/A Reactance“, “5501 X4s*In/A Reac-tance“)

• Secondary resistance R with separate values for phase-to-phase loops (“5102 R1sLL*In/A Resist.“, “5202 R1xsLL*In/A Resist.“, “5302 R2sLL*In/A Resist.“, “5402 R3sLL*In/A Resist.“, “5502 R4sLL*In/A Re-sist.“) and phase-to-earth loops for an additional resistance tolerance (“5103 R1sLE*In/A Resist.“, “5203 R1xsLE*In/A Resist.“, “5303 R2sLE*In/A Resist.“, “5403 R3sLE*In/A Re-sist.“, “5503 R4sLE*In/A Resist.“).

Zones Z1 and Z1x have an additional setting value with the zone reduction angle σ “5002 Red.AnglePolygonZ1(x)“, that is valid for both the forward and reverse direction.

Fig. 5.5-9 Characteristic of distance zones (for reverse direction dotted)

The setting value X defines the maximum reactance value of the parallelogram. The value on the positive or negative X-axis operates according to the stipulated measuring direction of the rele-vant distance zone. In addition to the X value and the lateral limitations by the parallelograms, the direction line acts as a lower (or, in case of reverse direction, as upper) limit.

jX

R

forward

Direction line

X

-X

5002 σ

reverse

RLL

jX

5001 α

R

forward X

-X

1905

ϕi

reverse

RLL RLE

Z1, Z1x Z2 .. Z4

5001 α ϕi

α

RLE

Functions


Theoretically, setting also involves special cases (small X, big R) in which the limitation of the tripping surface by the direction lines would permit areas which would be greater than the amount of the setting X. In these cases, the setting value -X (or +X) acts additionally as limit. The setting Xs referred to the nominal current In and valid for the nominal frequency (on account of X=2π∙f∙L) is determined as follows:

AI

rrX

AUIU

XX n

U

Iprim

pn

pnsnprims ⋅⋅=⋅

⋅⋅=

1 5-15: Distance zones: X

with Xprim Primary reactance (for single length, without return) Ipn, Upn Primary current or voltage transformer rating Usn Secondary voltage transformer rating rI Transformation ratio - system current transformer rU Transformation ratio - system voltage transformer In Nominal current of DDx 6 selected via terminal assignment A Unit of measurement Ampere, used to make In dimensionless

The setting values RLL for phase-to-phase loops and RLE for phase-to-earth loops are calculated as follows:

AI

rrR

AUIU

RR n

U

Iprim

pn

pnsnprims ⋅⋅=⋅

⋅⋅=

1 5-16: Distance zones: R

with Rprim: primary resistance (for single length, without return) The reactance X is the most important setting criterion for the fault distance / range. Usually Xs will not be adjusted up to 100% of the line length XLine but somewhat shorter, for example 0.85⋅XLine. This is to prevent safely unintended tripping (due to measuring errors) outside of the protection range. The possibility to set the resistances represents the "trip reserve" in the case of earth contact resistances (e. g. electric arc, especially in the case of overhead lines). An arc resistance is reflected by the setting only with half its value, as the other half belongs to the re-turn. Its maximum value is determined at the lowest short-circuit current (R=UB/I; UB≈2.5kV/m). The polygonal angle α is set to the line impedance angle. This takes the line's resistance into ac-count. The characteristic angle φi of the short-circuit direction need not be adapted necessarily to the line impedance angle. Only the longer time required for verification in the range φi + 60°...90° and φi - 60°...90° must be taken into consideration.

In the event memory, the measured secondary values R and X, referred to the rated current, are indicated upon distance module tripping, for example R: 2.207 X: 1.641 Ohm. The specified X is, in analogy to the setting, the value applicable for 50 Hz and thus comparable with the setting (the actual physical value X would be frequency-related – 2∙π∙f). Primary values can be determined through rearranging of the equations 5-16 and 5-15 in acc. with Rprim as well as Xprim. By contrast, the reactance statement in the report and fault location (value with measurement unit Ohm) is a primary value - example: fault location: +0.53Ohm 6.2km 172.6% Remark:

• The measuring results of distance measurement are frequency-related, as they are based on the determination of R and L (inductance).

• Accuracy is reduced in case of backup distance modules in whose measuring ranges further supplies are located.

Setting:

1. All settings of the distance modules (function switch and values) are made under “Set-ting Set / Setting / Setting Values / Protection Modules / Character. setx / Distance Mod-ule“.

Functions


2. The required binary input DI for the signal to activate stage Z1x,t1x and blockages must be configured under “Setting Set / Setting / Inputs / Protection Modules / Distance Module“.

3. Required outputs of the distance modules to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Distance Module“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Distance Module“.

4. Virtual inputs vDI can thus be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Distance Module“. Subsequently, setting of their further utili-zation is effected under “Setting Set / Setting / Inputs /..“

Functions


5.6 Overcurrent Time Protection (Emergency-)OTP/IDMT The overcurrent time protection is capable of fulfilling two tasks simultaneously:

• emergency overcurrent time protection in the case of a fault in the voltage path • overcurrent time protection operating parallel to the distance protection

It is subdivided into two parts: • IL> (Emerg.) OTP for phase current monitoring and • IE> (Emerg.) OTP for earth current monitoring

The overcurrent time protection works non-directionally as long as the distance zone and its starts are enabled. If the distance protection is disabled, but the direction decision enabled, the overcurrent time protection can optionally also work in directional mode, using the DDx 6 as di-rected overcurrent time protection instead of distance protection. An exception is the earth overcurrent time protection which can represent additionally a directed backup protection, together with the zero power direction. For further details, refer to Chapters 5.4.3 (Earth short-circuit fault direction) and 5.6.3 (earth overcurrent time protection). An overcurrent time protection has the task to monitor the current start values for overshoots and to start the appropriate timer module once starting has been detected. Once the delay has expired and the conditions then existing have been evaluated, the system decides upon the issue of a TRIP command. To this effect, the presence of the trip conditions is checked; the TRIP command must not be prevented by an external blockage. If the overcurrent time protection works in directional mode with the distance stages switched OFF, it performs transfer of the phases involved to the function group “Direction decision“ and starts the direction decision. With the direction available and the current start remaining present while the timer module has expired, TRIP is requested.

Consequently, the overcurrent time protection consists of the following components: • Current start IL>(>>>), IE>(>>>), • Time modules tIL>(>>>), tIE>(>>>)

The current starts except the intermitting earth fault current stage use d.c. corrected r.m.s. cur-rent values. Thus, switching operations which generate aperiodic components in the transform-ers, switchgear and device transformers influence start and reset of start only to a minor extent.

The overload protection can be provided upstream of the overcurrent time protection so that a characteristic consisting of several parts is generated.

10-2

0.1

1

10

102

103

104

1 10 100 I / In

ta /s

Fig. 5.6-1 Possible characteristic of overcurrent time protection

Functions


! Important:

• It is a must to use the OTP backup protection for the case of a voltage instrument trans-former fault (for instance a fuse failure), which will be detected by the measurand check module

• When setting the trip times and the pickup values of the current stages, make sure that the device current transformers are not subject to thermal overload by an excessively long short-circuit (see 3.3, page 20).

5.6.1 Emergency overcurrent time protection (OTP) In case of • a faulty voltage path detected by the measurand check or • if the fuse voltage transformer has reacted (signal via input “360 FuseVoltageTransf.“) and if appropriate settings have been made, an automatic change-over to the up to four-stage emergency overcurrent time protection is effected, as the direction decision and the distance de-termination are not possible. The TRIP command can be issued by the non-directional current time protection. The current starts effective for this case, incl. their appropriate time module, must be determined via setting under “IL> (Emerg.) OTP“ (phase currents) and “IE> (Emerg.) OTP“ (zero current). The setting which is flexible for each current starting stage (“1136 IL>+ErrorUPath/EOTP“, “1236 ...“, “1336 ...“, “1436 ...“, “2136 IE>+ ErrorU-Path/EOTP“, “2236 ...“, “2336 ...“, “2436 ...“) • “not if error U path“, .e. stage is not active in case of voltage path faults, • “even if error U path“ or • “only ifErrorU path“ enables the special setting of a grading for the case of a voltage path fault. In case of voltage failure, a more sensitive and shorter grading is mostly required as in case of an overcurrent time protection working in parallel to the distance protection. If “only ifErrorU path“ is selected, the setting can differ considerably from the setting of the OTP which is working in parallel. If all the stages enabled are set to “only ifErrorU path“, the overcurrent time protection works purely as emergency overcurrent time protection.

Once the time pertaining to the enabled start has expired, a non-directional TRIP is requested while starting is still present. Utilization of the emergency overcurrent time protection in the earth current circuit permits, in the case of phase-to-earth faults, a shorter tripping time via the IE timer modules, which are started simultaneously with the timer modules of phase starting. Starting of IE only results in TRIP upon expiry of the timer module.

Remarks: • The fault location cannot be determined. • The direction setting of an IE> stage if “even if error U path“ is selected in the

earthed system is not considered in the case of the voltage path error. Tripping is effected non-directionally.

• In the same way, the direction setting (distance stages blocked) of an IL> stage is not considered in the case of a voltage path fault provided that “even if error U path“ is selected.

Setting: The settings are limited to the selection of the current start stage(s) which are to be effective in case of emergency. To this effect, for phase current starting, the selection must be made under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / IL> (Emerg.) OTP“ and for the earth current starts under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / IE> (Emerg.) OTP“. The other overcurrent time protection settings are described under Fehler! Verweisquelle konnte nicht gefunden werden. and 5.6.3.

Functions


5.6.2 Phase overcurrent time protection Remark:

The shortest-possible trip time (below a power-supply period) is possible by utilization of the phase overcurrent time protection. Prerequisite: the selected current start value can only be reached in case of short-circuits in the 100% protection area and, moreover, not in case of faults in the reverse direction.

Fig. 5.6-2 Active principle Phase overcurrent time protection IL>

1101 IL> Definite

Time j

1100 IL> Start

1190 IL> Start FctOn

≥1

Error U Path

&

forward

reverse

non-directional

&

&

1131 IL> Direction

1199 Blockage IL> &

1198 Blockage IL>

H

enabled H

1199 Blockage IL>

1171 I1> Start

1172 I2> Start

1173 I3> Start

IL1 IL2 IL3

1132 IL> Timer Module

H

Definite Time

longtime inverse

inverse

very inverse

extremely inverse

1111 tIL>

&

1104 Reset Ratio

IL>

1112 tL> Time Factor

1113 tIL>max Time Delay

&

1102 IL> Inverse

Time

1104 Reset Ratio

IL>

GS

1180 tIL> expired

≥1

H

Direction forward

Direction reverse

≥1

H

not if error U path

even if error U path

only ifErrorU path

1136 IL>+ErrorUPath/EOTP &

&

H

≥1

≥1

t=f (I)

1115 t1p

IL> 1 pole ? ≥1

531 System Neutral: earthed

&n

1134 ILx> Phase Start

H

ILx> > 2/3 Imax

ILx>

≥1

&

Independent of Imax only if ILx>=2/3Imax

ILx> > 2/3 Imax

ILx>

≥1

&

&

&

&

&

&

&

5000 Distance Decision: enabled

DDx 6

GenTRIP

connected

Functions


Contrary to the represented phase current stages, the IDMT characteristic and the time stage t1p are not available for the phase current stages IL>>, IL>>> and IL>>>>. The switched-on (enabled) overcurrent time protection stages with the output commands “1190 IL> Start FctOn“, “1290 IL>> Start FctOn“, “1390 IL>>> Start FctOn“, “1490 IL>>>> Start FctOn“ can be signalled, as required, via LED or relays. If necessary, the binary input permits individual blocking of the phase current starts upon com-munication of the envisaged connector ("1198 Blockage IL>","1298 ...IL>>", "1398 ...IL>>>", "1498 ...IL>>>>"). To this effect, the appropriate input signal "1199 Blockage IL>", "1299 ...IL>>", "1399 ...IL>>>" or "1499 ...IL>>>>" must be used for the block-age. On the output end, the signal designated in an analogous fashion can be used for signalling pur-poses.

5.6.2.1 Current starts IL>, IL>>, IL>>> and IL>>>> The phase current start of the overcurrent time protection is designed in four stages. Each stage can be enabled and set separately. The current is measured in each phase in a phase-selective fashion and compared to the common setting IL> (“1101 IL> Definite Time“ or “1102 IL> Inverse Time“) to IL>>>> (“1201 IL>>“, “1301 IL>>>“, “1401 IL>>>“). When at least one pickup value is exceeded, the general start of the protector is generated. The phases which have exceeded the pickup value are signalled. The general starting starts the rela-tive time for entry of subevents to this main event "power system fault“. The phase-selective signals of current starts can be programmed as output commands to LEDs or relays, thus being available for external evaluation. The resetting ratio of all overcurrent stages is adjustable (“1104 Reset Ratio IL>“, “1204 ...IL>>“, “1304 ...IL>>>“, “1404 ...IL>>>>“). This is important in the case of current starts set to high levels, if there is a risk of transformer saturation. Otherwise, in case of exces-sively high resetting rates, the start would be reset once saturation occurs. If saturation must be expected in the case of currents in the range of the setting, the resetting ratio should thus be re-duced. If the distance protection is activated, the overcurrent time protection operates non-directionally. In case a fault has been detected within the voltage path, the starts function non-directionally and the settings for emergency overcurrent time protection apply; see chapter 5.6.1. How to handle special cases: • Timer module t1p of the overcurrent time protection (separate from distance protection)

In isolated-neutral, or compensated systems, a timer “1115 t1p at 1pole IL>“ is used. During its operating time it shall prevent the starting message in case the pickup value IL> of only one phase current is exceeded. This delay can be used to “skip“ the general start due to the starting threshold IL>-being exceeded for a short time in case of earth faults. This timer “t1p“ is cancelled immediately as soon as another phase current start of the overcurrent time protection is detected or an earth fault is signalled. It is not started if an earth-fault has been signalled before by the "earth-fault detection" function.

• Switching the distance stages or all distance starts OFF The distance protection turns into a directional protection. A tripping direction (non-directional, forward or reverse) can be assigned to each starting module (“1131 IL> Di-rection“, “1231 IL>> Direction “, “1331 IL>>> Direction “, “1431 IL>>>> Di-rection “). This enables grading on both sides in forward and reverse direction to be real-ized.

Functions


The current pickup value IL>(>>>) is entered in the setting menu as secondary current referred to the secondary transformer nominal current: IL>(>>>) = I/In. It must be determined from the primary current Ipr as shown in equation 5-8 (section 5.5.1.1). Overcurrent time protection starts can be signalled separately for each phase via the LEDs, relays by means of the output commands “1171 I1> Start“, “1172 I2> Start“, “1173 I3> Start“.

Remark:

• The time “1115 t1p at 1pole IL>“ must be set to a value which is as short as possi-ble, in any case, however, shorter than the time “7014 tUNE>EF Time f. UNE>“.

5.6.2.2 Timers tIL>, tIL>>, tIL>>>, tIL>>>>, tL> The DDx 6 permits: • to use up to four "independent“ (OTP) timer modules, identified as "tIL>(>>>) time“, or • to use the first IL> timer module as "dependent“ (IDMT), with the time factor “1112 tL>

Time Factor“, and the other ones as OTP.

While the delay is independent of the current intensity in case of the “Definite Time” (OTP - in-dependent maximum current time protection) characteristic, the delay is determined by the cur-rent intensity in case of the dependent characteristic. In case of multipole starting, the highest current intensity is selected for determination of the trip time. The trip time of the “Inverse Time” (IDMT – inverse definite minimum current time protection) is determined according to the following formulas (IEC 60255-3 or British Standard BS 142). Four characteristic types are available, the maximum trip time tamax being the setting “1113 tIL>max Time Delay“ to be specified.

1. Long time inverse with the longest delay (see Fig. 5.6-3)

>⋅

−⎟⎟⎠

⎞⎜⎜⎝

⎛>

=≥> L

L

aIL t

II

tt

1

120max

5-17: long-term inverse, trip time

2. inverse, type A (see Fig. 5.6-4):

>⋅

−⎟⎟⎠

⎞⎜⎜⎝

⎛>

=≥> L

L

aIL t

II

tt

1

14.002.0max

5-18: inverse, trip time

3. very inverse, type B (see Fig. 5.6-5):

>⋅

−⎟⎟⎠

⎞⎜⎜⎝

⎛>

=≥> L

L

aIL t

II

tt

1

5.13max

5-19: very inverse, trip time

4. extremely inverse, type C, with the shortest delay time (see Fig. 5.6-6):

>⋅

−⎟⎟⎠

⎞⎜⎜⎝

⎛>

=≥> L

L

aIL t

II

tt

1

802max

5-20: extremely inverse, trip time

with ta: trip time tIL>max: maximum trip time (setting) tL>: setting time factor I: measured current IL>: setting current Important:

In case of the dependent characteristics, it must be taken into consideration that starting only takes place as of 1.1 times the current setting (IL>). The resetting ratio also refers to this value. In the case of currents which exceed the range of action of the dependent characteristic (see page 24), the trip time is used for the highest current within the range of action. The release time is as short as for the OTP stages.

Functions


When phase and earth fault starting exist simultaneously, the first timer to expire tIL>(>>>) or tIE>(>>>) determines the delay. For both an independent and the dependent timer, the protection relay operating time must be added to the set or theoretical times in order to enable determination of the total time (from the time of occurrence of the fault to closing of the relay contact). It is composed of the time

• for detection of start, • possibly the time for loop selection and direction determination and • the time to close the contacts of the output relay.

Signalling the expiry of a timer can be programmed as output command “1180 tIL> expired“, “1280 tIL>> ..“, “1380 tIL>>> ..“ or “1480 tIL>>>> ..“ to LED or relay, thus being available for external evaluation. Setting: The prerequisite for the settings of the protection modules are the settings regarding "Equipment adaptation" and "System adaptation"; the most important settings have been listed here under items 1. and 2.

1. The nominal current of the phase current transformers selected via terminal connection can be set under “Setting Set / Setting / Setting Values / Equipment Adaptation / Transf. Adaptation“. In the same way, the primary nominal current of the switchgear transformer can be selected here to enable correct indication of the primary values.

2. The method of neutral connection and the phase rotation must be entered in “Setting Set / Setting / Setting Values / System Adaptation / System Adaptation“.

3. The enabling of the phase current starts, the intended conclusion of a blockage signal, selection of the characteristic, the required direction, if applicable compliance with the 2/3 current criterion as well as the setting of the pickup and reset values and timer modules can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / IL> (Emerg.) OTP“.

4. For blockage, the required binary input must be configured under “Setting Set / Setting / Inputs / Protection Modules / IL> (Emerg.) OTP“.

5. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / IL> (Emerg.) OTP“, those to relays under “Setting Set / Setting / Relays / Pro-tection Modules / IL> (Emerg.) OTP“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / IL> (Emerg.) OTP“. Subsequently, set-ting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


Fig. 5.6-3 IDMT characteristic, long time inverse (example with “tIL>max Delay time“=600 s)

0.1

1

10

100

1000

1 10 100I / IL>

ta /s

0.2

0.4

0.6

1

1.5

2

long-time inverse

Parameter: t>

0.05

0.1

0.15

3.5

tIL>max

1.1

Functions


Fig. 5.6-4 IDMT characteristic, type A, normally inverse

0.1

1

10

100

1000

1 10 100I / IL>

ta /s

0.2

0.4

0.6

1

1.5

2

normally inverse

Parameter: t>

0.05

0.1

0.15

3.5

1.1

Functions


Fig. 5.6-5 IDMT characteristic, type B, very inverse

0.01

0.1

1

10

100

1000

1 10 100I / IL>

ta /s

0.2

0.4

0.6

1

1.5

2

very inverse

Parameter: t>

0.05

0.1

0.15

3.5

1.1

Functions


Fig. 5.6-6 IDMT characteristic, type C, extremely inverse

0.01

0.1

1

10

100

1000

1 10 100I / IL>

ta /s

0.2

0.4

0.6

1

1.5 2

extremely inverse

Parameter: t>

0.05

0.1

0.15

3.5

tIL>max

1.1

Functions


5.6.3 Earth overcurrent time protection

Fig. 5.6-7 Basic principle, earth overcurrent time protection IE>

The IDMT characteristic shown is deleted for the earth current stages IE>>, IE>>> and IE>>>>.

2109 Bias. IE> Start IL

IE

2100 IE> Start 2190 IE> Start FctOn

≥1

Error U path

&

forward

reverse

non-directional

&

& 2131 IE> Direction

2199 Blockage IE> &

2198 Blockage IE>

H

enabled H

2199 Blockage IE>

2170 IE> Start

2132 IE> Timer Module

H

Definite Time

longtime inverse

inverse

very inverse

extremely inverse

2111 tIE>

& 2101 IE> DefiniteTime

2104 Reset Ratio IE>

& 2102 IE> In-verse Time

2104 Reset Ratio IE>

GS

2180 tIE> expired

≥1

H

Direction forward

Direction reverse

H

not if error U path

even if error U path

only if ErrorU path

2136 IE>+ErrorUPath/EOTP &

&

H

≥1

≥1

2112 tE> Time Factor

2113 tIE>max

t=f (I)

2107 Biasing Factor IE>

IL Start

& 2133 value for IE> iL1 iL2 iL3

∑ rms calculated

measured

only at insensitive IE-transformer

2900 Earth SC Direction: enabled

5000 Distance Detection: enabled

&

&

≥1

&

≥1 Distance Start

DDx 6

2137 IE> Start

H

not if IL/Dist Start even if IL/DistStart


&

&

≥1

IL1 IL2 IL3

GenTRIP

connected

Functions


Short-circuits involving the earth and double earth faults which are recognized by their current in-tensity can be detected by this protection module independently of the system type. In contrast, the protection module “Earthfault detection“ treats earth faults without phase current starting in the non-earthed system.

If the earth short-circuit direction is used in the earthed system (“2900 Earth SC Direction“ enabled), the earth overcurrent time protection provides the pickup values and the timer modules for IE and the setting of the requested trip direction. For further details, refer to section 5.4.3.

If the setting “532 SDLRE Automatic“ “connected“ is used in a non-earthed system, earth currents IE are expected, during short-time system earthing, which can be evaluated with this protection module or together with the earth short-circuit direction decision, unless distance starting takes place. For further details on the SDLRE automatic, refer to section 5.4.3.1. The settings under “2137 IE> Start“, “2237 IE>> Start“, “2337 IE>>> Start“, “2437 IE>>>> Start“ require particular attention. Using the appropriate IE> stage tripping of the zero power direction or IE> requires the setting “not if IL/Dist Start“. This prevents tripping by the earth overcurrent time protection in the presence of distance starting. Important:

In case of IE stages, it must be ensured that they are set for distance protection as "not au-thorized to trigger starting".

If the distance protection is enabled without utilization of the earth short-circuit direction, the earth overcurrent time protection operates non-directionally. If the distance protection is switched OFF or if a SDLRE automatic is used, the determined direction is available for evalua-tion. The switched-on (enabled) overcurrent time protection stages with the output commands “2190 IE> Start FctOn“, “2290 IE>> Start FctOn“, “2390 IE>>> Start FctOn“, “2490 IE>>>> Start FctOn“ can be signalled, as required, via LED or relays. If necessary, the binary input permits individual blocking of the phase current starts upon com-munication of the envisaged connector ("2198 Blockage IE>","2298 ...IE>>", "2398 ...IE>>>", "2498 ...IE>>>>"). To this effect, the appropriate input signal"2199 Blockage IE>", "2299 ...IE>>", "2399 ...IE>>>" or "2499 ...IE>>>>" must be used for the block-age. On the output end, the signal designated in an analogous fashion can be used for signalling pur-poses.

Remark: Another useful protection module in the case of high-resistance earth faults is the displace-ment voltage time protection, see chapter 5.13.3

5.6.3.1 Earth fault starts IE>, IE>>, IE>>>, IE>>>> In DDx 6 without or with a sensitive earth current transformer, the r.m.s. value of the earth cur-rent (current of the zero system) is calculated on the basis of the three phase currents (equation 5-7) and checked for exceeding the settings IE> to IE>>>>. The calculated earth current is better suited for short-circuit fault consideration than the current measured with a high sensitiv-ity which might enter its range limits. If a device with insensitive transformer is present, the change-over to "measured" can be ef-fected by the setting“2133 Value for IE>“ (“2233 ..IE>>“, “2333 ..IE>>>“, “2433 ..IE>>>>“). This not only increases accuracy when this transformer is connected to a cable-type current transformer, but also has the advantage of ruling out error currents (biasing meas-ures can be omitted). The earth current start is designed in four stages to permit various applications. Thus, stages can

Functions


• be effective, in case of emergency overcurrent time protection, on power failure (5.6.1) by means of “2136 IE>+ ErrorUPath/EOTP“ “only ifErrorU path “ (or “even if error U path“) or

• form a zero power direction protection (5.4.3) in terms of backup protection together with the determined earth short-circuit direction (“2900 Earth SC Direction“ en-abled).

• The third application variant is a non-directional earth current time protection operating in parallel to the distance protection.

The starting capacity of the IE stage concerned, and consequently the enable to generate a TRIP command, can be influenced with the settings under “2137 IE> Start“, “2237 IE>> Start“, “2337 IE>>> Start“, “2437 IE>>>> Start“. Normally, IE starting alone does not authorize to trigger starting in the distance protection. The setting option was created

• to realise the earth short-circuit direction protection (“not if IL/Dist Start“) or • for any overcurrent time protection working in parallel to the distance protection (“only

if IL/Dist Start“) or • for switched-off distance stages as well as directional stages.

The current pickup values IE>(>>>) are entered in the setting menu with reference to the nominal current: IE>(>>>) = IE / In – in analogy to equation 5-8. As the earth current is calculated normally, the nominal current In is the value set for the phase current transformers in "Equipment adaptation". In the measured earth current, the selected nominal current of the earth current transformer shall apply.

The pickup value IE> is biased versus faulty tripping; to this effect, refer to the following sec-tion. The further earth heavy-current stages IE>>...IE>>>> are non-biased.

The resetting ratio is adjustable and refers, in case of stage IE>, to the biased pickup value IE’>.

In case a fault has been detected within the voltage path, the starts function non-directionally and the settings for emergency overcurrent time protection apply; see chapter 5.6.1.

Special case: If “5000 Distance Detection“, is switched off, which creates a directed overcurrent time protection, a tripping direction (non-directional, forward or reverse) can be assigned to each starting module. This enables grading on both sides in forward and reverse direction to be real-ized.

Remark: The integrated sensitive earth current transformer of the DDx 6 is used only for the wattmet-ric earth-fault direction decision. The earth current starts using calculated currents.

5.6.3.2 Biasing IE> start The earth current calculated from the three phase currents or the summation current obtained from the phase current transformers on the secondary side comprises faults of the individual phase current transformers. This is recognized, in the case of big phase currents, by a sum de-viation from 0. This is even more dramatic in case of transformer saturation. With the function "earth current biasing", the increase of the pickup value of the OTP earth overcurrent stage IE> is realized in dependence of the amount of the sum of those phase cur-rents that have exceeded the setting“2109 Bias.IE> from IL“. Thus, undesired IE> starts can be prevented. The following applies in analogy to the description regarding the earth short-circuit detection (5.5.2.1.1), if all three phase currents have exceeded the value “2109 Bias.IE> from IL“:

IE'> = IE> + ks ⋅ (IL1 + IL2 + IL3 - 3 ⋅ Ian) 5-21: Bias IE> a)

If only two phase currents exceed the value, biasing is reduced:

IE'> = IE> + ks ⋅ (ILX + ILY - 2 ⋅ Ian) 5-22: Bias IE> b)

Functions


If only one phase current pickup is exceeded, the following remains:

IE'> = IE> + ks ⋅ (ILX – Ian) 5-23: Bias IE> c)

with IE'>: biased real pickup value of the earth fault current stage IE>: set pickup value of the OTP earth current stage IE> “2101 IE> Definite

Time“ ks: setting of biasing factor “2107 Biasing Factor IE>“ IL1,IL2,IL3,ILX,ILY: RMS value of phase currents, x,y=[1,2,3] Ian: setting “2109 Bias.IE> from IL“ The biasing effect is the strongest for three-pole shorts. This is desirable, as different aperiodic components in the transformers may give rise to various transformer faults. The biased earth current starting is reset with the biased pickup value IE’> multiplied by the re-set ratio. When the earth current is measured via the cable-type current transformer, biasing is not re-quired. The biasing factor must be set to 0. For information regarding setting of ks and characteristics, refer to section 5.5.2.1.1.

5.6.3.3 Earth fault current timers tIE>, tIE>>, tIE>>>, tIE>>>>, tE> The DDx 6 permits: • up to four "independent“ (OTP) timer modules, identified as "tIE>(>>>) time“, or • to use the first IE> timer module as "dependent“ (IDMT), with the time factor “1112 tL>

Time Factor“, and the other ones as OTP. The earth current timer module used in each case depends on starting. An OTP - IE> start uses the tIE> timer module “2111 tIE> Time“, whereas in case of an IE>> start, the appropriate “2211 tIE>> Time“ is evaluated etc. (“2311 tIE>>> Time“, “2411 tIE>>>> Time“). When phase and earth fault starting exist simultaneously, the first timer to expire tIL>(>>>) or tIE>(>>>) determines the delay.

While the delay is independent of the current intensity in case of the “OTP” characteristic, the delay is determined by the current intensity in case of the dependent characteristic. The trip time of the IDMT is determined in accordance with the formulas 5-17 to 5-20 in section Phase current timer modules 5.6.2.2. The characteristics listed there are available for earth cur-rent starting IE>. To identify the settings, an "E“ is used here, versus the "L“ for phase current start – "IE>“ instead of "IL>“ and "tE>“ instead of "tL>“. The maximum trip time tamax must also be specified here as setting “2113 tIE>max Time Delay“.

Signalling the expiry of a timer can be programmed as output command “2180 tIE> expired“, “2280 tIE>> ..“, “2380 tIE>>> ..“ or “2480 tIE>>>> ..“ to LED or relay, thus being available for external evaluation. Setting: The prerequisite for the settings of the protection modules are the settings regarding "Equipment adaptation" and "System adaptation"; the most important settings have been listed here under items 1. and 2. 1. When the measured earth current is used, its nominal current selected via terminal connec-

tion must be set under “Setting Set / Setting / Setting Values / Equipment Adaptation / Transf. Adaptation“. In the same way, the primary nominal current of the switchgear trans-former can be selected here to enable correct indication of the primary values.

2. The method of neutral connection and the phase rotation must be entered in “Setting Set / Setting / Setting Values / System Adaptation / System Adaptation“.

3. The enabling of the earth current starts, the intended conclusion of a blockage signal, selec-tion of the characteristic, the required direction, as well as the setting of the pickup and reset values and timer modules can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / IE> (Emerg.) OTP“.

4. For blockage, the required binary input must be configured under “Setting Set / Setting / In-puts / Protection Modules / IE> (Emerg.) OTP“.

Functions


5. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / IE> (Emerg.) OTP“, those to relays under “Setting Set / Setting / Relays / Protection Mod-ules / IE> (Emerg.) OTP“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / IE> (Emerg.) OTP“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

5.6.3.4 Treatment of Intermitting Earth-faults Earth faults occurring for a short time in low-resistance earthed, or even isolated systems may not be detected in all cases via the "normal" earth current start, as reset is performed before ex-piry of the timer module. If such short-time earth faults occur several times within time intervals to be specified, selection shut-down of the switchgear may make sense. Otherwise, the neutral earthing transformer might be endangered by such loads.

Fig. 5.6-8 Basic principle of intermittent earth-fault protection IE>int

The solution integrated in the DDx 6 has a specially equipped protection module for intermittent earth short-circuit faults, i.e. "IE>int“. The setting “2801 IE>int“ or “2803 or 2805 IE>int sensitive“ is used for the start detection. To detect very short overshoots of the pickup value (even lower than a half-wave), non-d.c. corrected half-cycle r.m.s. values are used. The module has the following task:

• summing up all IE>int fault times within the time to be specified by “2817 tIE>intSumReset Time“.

• To this effect, each new IE>int start re-starts this time on start reset. • To achieve the selectivity in time depending on the location of the protection device (e.g.

a transformer outgoing feeder should switch OFF in this context after the line outgoing feeders), the starting duration IE>int is extended by the adjustable value “2816 IE> intProlong. Time“ (in the example, the time for the line outgoing feeders would have to be adjusted to a higher value).

• In case of IE>int starting, the summed-up time is compared to the preset “2811 tIE>int Time“ trip time (normal grading time step, suitable for grading line compo-nents). If the sum exceeds this IE>int trip time while an IE>int start exists, TRIP is re-quested.

IE

2800 IE>int,interm. fault 2890 IE>int Start FctOn

2899 Blockage IE>int &

2898 Blockage IE>int

H

enabled H

2899 Blockage IE>int

2870 IE>int Start

GS

2880 tIE>int expired 2833 Value for IE>int

iL1 iL2 iL3 ∑

rms calculated measured

≥1

DDx 6

GenTRIP

connected

2816 tIE>int Prolong. Time

2817 tIE>int SumReset Time S

R

Suppress event

2861 Reset tIE>int

& 2801 IE>int

2804 Reset Ratio

IE>int 2808 IE>int

EntryCounter

2811 tIE>int

∑(Δt)

R

2879 IE>int Cycle

&

Reset tIE>int from

control

51640 Cmd Reset tIE>int

H enabled

& 2861 Reset tIE>int

Functions


• The summation time is set to 0 when the “2817 tIE>intSumReset Time“ expires or a TRIP command is issued for any reason.

Appropriate measures have been taken to prevent the event memory from being filled exces-sively in case of frequent occurrences of IE>int starts. By means of the setting “2808 IE>int EntryCounter“ the number of IE>int starts to be entered completely can be determined. All the other starts are not entered. The fault number is not incremented either. The number of IE>int starts and the value reached for the summation time are not entered until a TRIP is issued by the intermitting earth fault current stage or expiry of the “2817 tIE>intSumReset Time" Faults involving overshoots of the phase current stages (IL>(>>>)) remain unaffected thereby and continue to be signalled - in this case including the earth current starts.

To signal a start or tripping by this stage, the output commands “2870 IE>int Start“, “2880 tIE>int expired“ are available. A currently running IEint cycle can be signalled with “2879 IE>int Cycle“.

The currently existing summation time can be reset via an optocoupler input, assigned with “2861 Reset tIE>int“, or by means of a substation control command. As for all substation control commands, the command needs to be enabled with “51640 Cmd Reset tIE>int“ here, too. This setting is made under “Com.+SubstCtrl / Substation Control“.

This function can be blocked by means of the input signal "2899 Blockage IE>int". On the output end, the signal designated in an analogous fashion can be used for signalling purposes.

If a DDx 6 with insensitive earthing transformer is provided, a change-over to "measured" can be achieved by the setting “2833 Value for IE>int“. The advantage, in case of connection to a cable-type current transformer, is that wrong currents are ruled out.

Remark: A set biasing of the IE> stage does not become effective for this protection module! This re-quires, in the case of simultaneous use of both modules (biased IE> and IE>int), the longer time setting for “tIE>Int Time“ versus the “tIE> Time“ to avoid unintended tripping by this protection module.

Setting: Setting the protection modules requires that the settings for "equipment adaptation" have been made; the important settings are specified under item 1.

1. When the measured earth current is used, its nominal current selected via terminal con-nection must be set under “Setting Set / Setting / Setting Values / System Adaptation / Transf. Adaptation“. In the same way, the primary nominal current of the switchgear transformer can be selected here to enable correct indication of the primary operating measurands.

2. Enabling of the intermittent earth current start “2800 IE>int, interm. fault“, the in-tended connection of a blockage signal, the setting whether IE is to be measured or calcu-lated, as well as the setting of the pickup and reset values and timer modules is possible under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / IE> (Emerg.) OTP“.

3. For blockage or the reset of the summation time, the required optocoupler input must be configured under “Setting Set / Setting / Inputs / Protection Modules / IE> (Emerg.) OTP“.

4. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / IE> (Emerg.) OTP“, those to relays under “Setting Set / Setting / Relays / Pro-tection Modules/ IE> (Emerg.) OTP“.

5. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules/ IE> (Emerg.) OTP“. Subsequently, set-ting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

6. If the summation time is to be reset by a substation control command, this command is enabled under “Setting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“

Functions

SPRECO

N-E-Pxx-D

Dx6 U

ser Manual Protection 5601/B

85

Sprecher A

utomation D

eutschland Gm

bH

Fig. 5.6-9 Operating principle of the IE>int stage

Behaviour without simultaneous phase current starts: left-hand with tripping; right-hand without tripping

IE>int-Start, General Start

Event memory: General start, Disturbance record

TRIP command

2817 tIE>int SumResetTime

Sum time

2816 tIE>intProlong.Time tIE>int Time exceeded

IE>intSumResetTime exceeded

iLx

iE

2801 IE>int

2 3 m n=1 2 4 3

IL>

2811 tIE>int

IE>int Cycle runs for Relays, LED

Fault number X+1 X+2 X+3 X+4

Example for 2808 IE>int

EntryCounter n=3

Reset time

X+1 X+2 X+3

Additional entry: tsum, counter = m “IE>int Cycle goes“

Entry: tsum, counter = 3 “IE>int Cycle goes“

5 m-1

2816 tIE>intProlong.Time

Entry: “IE>int Cycle comes“, disturbance record, no GS entry


n=1

Functions

SPRECO

N-E-Pxx-D

Dx6 U


86

Sprecher A

utomation D

eutschland Gm

bH

Fig. 5.6-10 Operating principle of the IE>int stage

With other starts authorized to perform general starts: left-hand with tripping; right-hand without tripping

Event memory: General start, Disturbance record

TRIP command

Sum time

2816 tIE>intProlong.Time tIE>int Time exceeded

IE>intSumResetTime exceeded

iLx

iE

2801IE>int

2 3 m 2 4 3

IL>

2811 tIE>int

IE>int Cycle runs for Relays, LED

Fault number X+1 X+2 X+3 X+5

Example for n=3

Reset time

X+1 X+2 X+3

Entry: tsum, counter = 3 “IE>int Cycle goes“

X+4 X+4 X+5

5

IE>int-Start, General Start

2816 tIE>intProlong.Time


Additional entry: tsum, counter = m “IE>int Cycle goes“


2817 IE>int SumResetZeit

n=1 m-1 n=1

no IE start, but General start

Functions


5.6.4 Behaviour with the distance protection OFF / direction deci-sions OFF Behaviour with the distance detection OFF (“5000 Distance Detection“): With the distance stage OFF and the direction decision active, the non-directional overcurrent time protection – Protection Modules “IL> (Emerg.) OTP“ and “IE> (Emerg.) OTP“ – is turned into a directed overcurrent time protection. Directions can be assigned to the individual IL and IE stages (“1131 IL> Direction “, “1231 IL>> ..“ , “1331 IL>>> ..“, “1431 IL>>>> ..“, “2131 IE> Direction “, “2231 IE>> ..“ , “2331 IE>>> ..“, “2431 IE>>>> ..“). For further information, refer to section 5.4.2. In systems with earthed neutral, a supplementary criterion can be selected for multiphase starts in order to select the correct loop for the direction decision. Within earthed systems, a single-pole fault (single-pole earth short-circuit fault) can lead to multi-pole starts due to the current distribution. This occurs if the supply features a non-earthed neu-tral and the consumer an earthed neutral (Fig. 5.5-2). For this case, pickup of a phase current start is only possible if the phase current amounts to min. 2/3 of the max. phase current “...ILx Start“ “only if ILx >2/3Imax“. If a direction decision is not envisaged, this 2/3 supplementary criterion does not have to be used.

Remark: The appropriate settings must be selected in the phase short-circuit stage “1134 ILx> Phase Start“, “1234 ILx>> Phase Start“ “1334 ILx>>> Phase Start“ “1434 ILx>>>> Phase Start“ and for the switch-on protection “8134 ILx> SOTF Phase Start“.

The settings authorizing starting of the IE> stages (“2137 IE> Start“, “2237 IE>> ..“, “2337 IE>>> ..“, “2437 IE>>>> ..“) must be selected in accordance with the new require-ments. In the non-earthed system, an IE> start will normally require a simultaneous IL> start. The settings in case of use of the earth short-circuit fault direction or SDLRE remain as de-scribed. When phase and earth fault starting exist simultaneously, the first timer to expire tIL>(>>>) or tIE>(>>>) determines the delay. Behaviour with the direction decision switched OFF (“1900 Short Circ.Direction“): For the special case that the short-circuit and earth short-circuit fault direction decision or earth fault direction decision are blocked, the device acts as a non-directional overcurrent time protec-tion with the following changes versus mere distance protection tripping: • It is possible to utilize even the sensitive earth current transformer for IE starting. To this ef-

fect, the option “Value for IE>..“ can be set from “calculated“ to “measured“. In this case, the earth current transformer’s values entered in the equipment adaptation are considered as reference variables.

• If the IE start “even if IL/DistStart“ has been selected and one ore stages set to “measured“, measurement of any other connected current is possible. However, the meas-urand check in the current path must be switched off additionally “18102 Isum>“.

Important for measured IE in case of insensitive earth current transformer (optional equipment):

The setting range of the IE starts is greater than the earth current transformer’s admissi-ble continuous current. Appropriate measures must be taken to ensure that the admissi-ble continuous current is never exceeded!

5.6.4.1 Behaviour in earthed systems The behaviour is to be demonstrated based on possible settings.

Functions


1. Non-directional overcurrent time protection by switching OFF “1900 Short Circ.Direction“, however with earth short-circuit direction, low-resistance earthed power systems (NOSPE) This special case occurs if the short-circuit direction is blocked and the zero power direction decision is enabled. Below, please find the possible starting conditions and their TRIP com-mand delay times. In the table, “IL>(>)“ represents any stage and number of phase current

starts. This applies analogously to the specified timer.

2. Directed overcurrent time protection without earth short-circuit direction, in solidly earthed systems In solidly earthed systems, the zero power direction decision will not be used (it must be blocked). Normally, the short-circuit direction decision is enabled. The various starting cases

are treated as follows:

3. Directed overcurrent time protection with earth short-circuit direction, in low-resistance earthed systems This case, which is standard in low-resistant earthed systems, uses both direction decision variants available. The starting cases are treated as follows:

5.6.4.2 Behaviour within the compensated or isolated system In the non-earthed system, the earth fault current timers tIE>(>>>) are only used to detect earth fault currents and double earth faults. The protection module "Earth fault detection" treats single-pole earth faults and uses a timer of its own, if necessary, to delay the TRIP command re-quest. For further information, refer to section 5.7.

An exception to this is the use of the SDLRE automatic. In case of the setting “532 SDLRE Automatic“ “connected“, it is not the measured earth current that is used, but the calculated one, and thus also the earth current timer modules – see sect. 5.4.3.1. The device behaves as described in the above section under item 3.

Start TRIP request after Remark

IL>(>) tIL>(>)

IL>(>)+IE>(>) tIL>(>)

IL>(>)+IE>(>)+UNE> tIL>(>) or tIE>(>)

IE>(>) alone (without IL>, UNE>) −

results, after expiry of the timer “18111 tI Time Malf. I Path“ in “I Path disturbed“

IE>(>)+UNE> tIE>(>) , if direction correct Earth short-circuit direction decision determines direction


IL>(>) tIL>(>), if direction correct Earth short-circuit direction decision determines direction

IL>(>)+IE>(>) tIL>(>) or tIE>(>),

if direction correct Earth short-circuit direction decision determines direction

IE>(>) alone (without IL>, UNE>) −

results, after expiry of the timer “18111 tI Time Malf. I Path“ in “I Path disturbed“


IL>(>) tIL>(>), if direction correct Earth short-circuit direction decision determines direction

IL>(>)+IE>(>) tIL>(>) or tIE>(>),

if direction correct Earth short-circuit direction decision determines direction

IE>(>) alone (without IL>, UNE>) − results in “I Path disturbed“

IE>(>)+UNE> tIE>(>) , if direction correct Earth short-circuit direction decision determines direction

Functions


5.7 Earth-fault detection (EF) In isolated-neutral and compensated systems, earth-fault detection serves to indicate the earth-faulted phase for a single-pole earth fault. As special feature, in case of earth fault, devices DDEx6 may be given a TRIP command at choice while a "weighted" power value is available si-multaneously, or without supplementary condition. Moreover, the earth fault direction can be determined after the appropriate function has been en-abled. Important:

In this manual, the term “earth fault” designates generally a single-pole earth fault within a non-earthed system. Multi-pole earth faults are short-circuits and are handled within the relay by the short-circuit stages and not by the earth fault detection.

Fig. 5.7-1 Active principle Earth fault detection

Method of functioning of earth-fault detection: It is based on monitoring the displacement voltage UNE (definition, see equation 5-6, page 38) for exceeding the setting “7002 UNE>EF”. The displacement voltage is calculated as standard, but it can also be measured - if necessary - with the fourth voltage transformer in the DDEY 6 – “336 Usage VT4 ““Residual Voltage UNE“ and “7035 Value for UNE EF“ “measured“.

7014 tUNE>EF

7030 TRIP at Earthfault H

Earthfault Detection

L1 L2 L3

Earthfault

7081 Earthfault L1

7083 Earthfault L3

7082 Earthfault L2

UNE > 7002 UNE>EF

7073 UNE>EF

7000 Earthfault Detection

7099 Block. Earthf.Det. &

7098 Blockage Earthf.Det.

H

enabled H

7090 EFDetect. FctOn

7099 Block. Earthf.Det.

EF Detection ready &

DDx 6

7033 TRIP at Earthfault

H

indep. of power only if P>/fb o. Q>/fb

&

&

&

&

&

≥1 7070 Earthfault

&

&

&

7001 P> resp. Q> pickup

& DD 6 7011 tTRIP if

Earthfault

&

≥1 enabled

7061 EarthFlt. forw.ext

7062 EarthFlt. rev. ext

DD 6 7071 EarthFlt. forw.

7072 EarthFlt. rev.

connected

7034 Earthf.Direct. ERER

H

GenTRIP

connected

7080 tTRIP EF expired

P0, Q0, fb

ie

une (∑/√3)

UNE

UNE une

7035 Value for UNE EF (only DDEY6)

uL1 uL2 uL3

ULL min / max

ULE

measured

Earthfault forward

Earthfault reverse

Earthfault

Functions


Additionally, this voltage excess must still be present when the simultaneously started timer “7014 tUNE>EF Time f. UNE>“ (abbreviation: tUNE>), i.e. the acknowledgement time of an earth fault, expires. At the same time, it is checked whether one of the other two phases which are not subject to an earth fault has an excessive phase-to-earth voltage: ULE=0.6·ULLmax. Here, ULLmax is the highest phase-to-phase voltage which may occur. Moreover, the minimum line-to-line voltage in case of earth faults must be ULLmin=0.75·Un. The phase that shows the smallest phase-to-earth voltage is the one subject to an earth fault. A TRIP command can be issued in case of earth fault. To this effect “7030 TRIP at Earth-fault“ must be enabled. The TRIP command can be issued dependent on the supplementary condition which can be selected under “7033 TRIP at Earthfault“: simultaneous exceeding of the weighted earth-fault power “only if P>/fb o. Q>/fb“ is required. The so-called weighting factor “fb“ contained in the term "P>/fb“ or "Q>/fb“ is explained in the following sections (equation 5-25). ). At this point, it should only be mentioned that it adapts the pickup threshold to the currently existing earth fault properties. The power setting “7001 P> resp. Q> pickup“ “ must be entered as secondary value normal-ized by nominal current and nominal voltage. The setting is simplified due to the weighting factor fb described in the sections 5.7.2 and 5.7.3. For the setting, only the earth current relevant for an earth fault resistance of 0 Ω and thus the full displacement voltage need to be entered. Higher earth contact resistances are corrected within the relevant displacement voltage range. Within the compensated system, fb, moreover, causes the value to increase in case of a high active power component.

nIE

prim

n IrI

IIP

⋅==> sec 5-24: Power setting P> or Q>

with In: chosen rated current of the DDE(Y) 6's earth-current transformer IN

Isec: secondary earth current Iprim: primary earth current rIE: transformer ratio of cable-type transformer (Ipn/In)

Remark: • The pickup threshold must be verified taking the effect of the weighting factor fb into con-

sideration. In general, checking should be effected at the full displacement voltage UNE=Un this is effected by fU=1. In isolated systems, thus fb=1. If merely active power is present in compensated systems (Q=0), a total factor fb of 4.0 is created, from which results a pickup value in accordance with the equation 5-25 as follows:

4>

=PPstart

.

• The power required for a TRIP command is determined from the calculated displacement voltage and the measurement of the current via the sensitive earth current transformer.

• In the distance protection, there are several UNE> starting modules used in various fashions, and the appropriate signals (UNE>EFC, UNE>, UNE>>, UNE>Check, UNEmin ESCD). The UNE of the earth fault detection has the identifier ”UNE>EF“.

If the conditions for the TRIP command are satisfied, a general start is created and the timer module “7011 tTRIP if Earthfault“ used for the TRIP delay. The overall tripping time, calculated from the time when the setting value UNE> is exceeded, is determined from the total of the times tUNE> and tTRIP>. The timer module tTRIP is not started until the earth fault has been confirmed, i. e. upon expiry of tUNE>. Thus, the total of the two times can be explained as trip time. The times for recognizing the earth fault and operating the output relay are not contained at this overall tripping time. Moreover, a TRIP command can be issued additionally taking the determined earth fault direction in the isolated system into account – to this effect, refer to the following chapters 5.7.2, 5.7.3.

Functions


If necessary, the earth fault detection can be blocked individually via the optocoupler input. To this effect, the appropriate input signal "7099 Block. Earth.Det." must be used for the blockage. This blockage signal is available after specifying the intended connection “7098 Blockage Earthf.Det.“ “connected “ in the settings. On the output end, the signal designated in an analogous fashion can be used for signalling pur-poses. Important:

• Once the TRIP command has been permitted, the trip time results essentially from the sum of the times tTRIP and tUNE>.

• The time “7014 tUNE>EF Time f. UNE>“ be set to a value shorter than the timer module “18211 tU Time Malf. U Path“ to permit earth fault detection before detecting “Mal-function U path“.

Setting: 1. The transformer data of the cable-type current transformer connected to the IN transformer

must be entered in the menu “Setting Set / Setting / Setting Values / System Adaptation / Transf. Adaptation“.

2. The enable of the earth fault detection, the intended connection of a blockage signal, the en-able of an OFF command and its supplementary condition and the enable of the earth fault di-rection decision (together with the required direction) as well as setting the timer tUNE>, the pickup value of the power P>/Q> and the timer tTRIP can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Earthfault Detection“. This also applies for the intended connection of an external earth fault directional relay, e.g. ERER3.

3. The important pickup value of the displacement voltage UNE> can be found under “Setting Set / Setting / Protection Modules / Character. setx / Measurand Check“ appropriate signal in “Setting Set / Setting / Relays (or LED or Cmd.->Inputs (vDI)) / Protection Modules / Meas-urand Check“.

4. For a blockage or receipt of the external direction decision, the required optocoupler input must be configured under “Setting Set / Setting / Inputs / Protection Modules / Earthfault De-tection“.

5. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Earthfault Detection“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Earthfault Detection“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Earthfault Detection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

5.7.1 Connecting an external earth-fault directional relay The direction reports of the external relay (e.g. ERER 3 of Sprecher Automation Deutschland GmbH) are "integrated“ in the distance protection, if “7034 Earthf.Direct. ERER“ “con-nected“ and the binary inputs have been assigned to the function concerned “7061 EarthFlt. forw.ext“ or “7062 EarthFlt. rev. ext“. This means that the earth fault direction report is integrated with date and time into the event memory, thus enabling further processing of the decision. Subsequently, output is possible via LEDs, signalling relays (output commands of the same name “7061 EarthFlt. forw.ext“, “7062 EarthFlt. rev. ext“) and the substation control system, separately from the internal earth fault direction decision.

5.7.2 Wattmetric earth fault direction decision, compensated system (not DD6) The direction decision requires that an earth fault has been detected as described under 5.7, i.e. UNE> has been exceeded, a voltage overshoot is present and tUNE> has expired. Moreover “7031 EarthFaultDirection“ must have been enabled.

Functions


If necessary, a TRIP command can also be output by the earth fault direction decision. To this ef-fect, the “7030 TRIP at Earthfault“ must be enabled and the required direction must be de-termined via “7032 TRIP at Earthfault“ for forward, reverse or non-directional modes.

Fig. 5.7-2 Active principle Earth fault direction

The DDE(Y) 6 has an innovative earth-fault direction decision, which is based on assessment of the active and reactive power. For this, the displacement voltage is calculated normally from the three line-to-earth voltages, and the current provided by the earth current transformer IN and fil-tered for fundamental waves is used. The earth-current transformer IN is intended for the con-nection to a cable-type transformer. Important: • The correct connection to the cable-type current transformer represents an essential factor

for the success of the direction decision procedure. Thus, the cable screen may not be grounded until returning through the transformer to eliminate cable screen currents from the measurement current.

• The neutral point of the three voltage transformers must be earthed. • Connection in V arrangement is inadmissible in case of connection on the voltage end. The traditional wattmetric earth-fault direction decision has to fight relatively big difficulties, for example: • that the active power amounts only to a few percent of the reactive power, which results in

a high sensitivity versus phase-angle errors (transformer, ...). • In the case of digital relays, after analogue to digital converting, only few digits are available

for measuring very low currents, especially in the case of relays located at a greater distance. Any digit error (at least ±1) may have a negative effect.

• Earth faults with earth contact resistances enhance the difficulties. In order to reduce the influence of the problems, corresponding measures were realized. The first measure takes the characteristic of the system into account according to which the shunt inductor compensates the capacitive reactive current of the system at the earth-fault loca-tion. This compensation process does not only confine itself to the earth-fault location, but also affects the line leading to the earth-fault location. Thus, for the protection equipment at this line, a considerably higher ratio of active (P0) to reactive power (Q0) in contrast to lines is not subject to earth faults. This is used for the formation of a "power-ratio dependent weighting factor” fP.

This factor fP has the quality of being set in a certain ratio ||||

0

0

QP to 1 and increasing, along with

the continued increase of this ratio, up to its maximum value 4. The ratio was chosen so that earth faults on the relevant line lead to an fP of ≥1. In contrast, lines not subject to earth faults

7030 TRIP at Earthfault H

ie

EF Detection ready

D... 6

7032 TRIP at Earthfault

H forward reverse

une

Earth-fault di-rection P0, Q0, fb 7001 P> resp. Q> pickup

&7011 tTRIP if

Earthfault

&

≥1 enabled

7071 Earthflt. forw.

7072 Earthflt. rev.

non-directional

&

7031 EarthFaultDirection H enabled

GenTRIP

7080 tTRIP EF expired

Earth-fault

Earth-fault forward

Earth-fault reverse

Functions


result in fP<1. due to this ratio being lower. A high factor fP means high reliability of the direc-tion decision made! We use a strongly simplified equivalent circuit diagram of an earth fault for better understanding.

Here, in the case of the compensation of capacitive reactive current by the inductive current of compensation coil in the system, the parallel circuit of LN and Cgrid has an impedance of → ∞.

RF is the earth-fault resistance and RN the resistance of the system rw

nomN I

UR 0= . Irw is the resistive

residual current of the system.

Thus, the following applies: FN

N

nom

meas

RRR

UU

+=

0

0 .

The result of this equation is that for example with a UNEmeas=0.2⋅UNEnom=20 V (and complete compensation) a maximum fault resistance of approximately 4⋅RN could be recorded. However, in this case, the powers to be evaluated from the protection devices only amount to 1/25 compared with their measuring value at RF=0 (UNEmeas and UNEnom are secondary values). A voltage-dependent factor fU is introduced in order to cover also faults with higher RF. This fac-tor increases as the actually measured displacement voltage UNEmeas decreases. It is restricted to the maximum value 16 and is equal to 1 at UNEmeas=UNEnom=100 V:

2

⎟⎟⎠

⎞⎜⎜⎝

⎛=

NEmeas

NEnomU U

Uf

The DDE(Y) 6 only issues the earth fault direction if the weighted active power is higher than the setting “7001 P> resp. Q> pickup“; in compensated systems, P> applies as follows:

P0meas ⋅ fP ⋅ fU > Psetting = P>

UP

meas ffPP

⋅>

=0 5-25: Earth-fault direction operate value

In a nutshell • the factor fP increases the active power component in case of a favourable phase-angle or

reduces it in the case of an unfavourable phase-angle; • the factor fU ensures in a certain range that the sensitivity limit of the relay remains more in-

dependent of the contact resistance in the earth-fault location. Beside the above-mentioned software measures, a sensitive earth current measurement has been realized via the IN transformer. A high measuring accuracy is also reached at earth fault currents far below the nominal current. This transformer is intended for connection to cable-type current transformers that in turn avoid wrong currents due to their design principle. DDE(Y) 6 has the capability to adapt its sensitivity optimally in dependence of the earth fault lo-cation and the earth fault resistance. With this special wattmetric earth-fault direction detection, the user gets close to the target to obtain direction displays only in the surroundings of the earth-fault location. All anyway unsafe direction details in the wider surroundings are suppressed. How is the forward direction defined? The direction decision is based on the following definition:

RF

RN ~ nomsubst UU 0= U0measCgridLN

Functions


If the relay recognizes the output of active power (in the direction of the line), then "forward di-rection" has to be specified. This applies in all cases in which an active power (P) is recognized with a positive sign. The sign of the reactive power is of no importance for the direction. The conditions are represented in the vector diagram for U and I (Fig. 5.7-3).

U=0°

90°

I (act ive) I

I (reactive) I

P>0 Q<0

P>0 Q>0

P<0 Q<0

P<0 Q>0

Fig. 5.7-3 Representation of the relations U and I as well as P and Q in the coordinate system

Which settings have to be carried out? If a lower active power has been measured in comparison to the setting, the factors f=fU · fP en-able a direction output to be made even if the decision is very sure (fP > 1). This considerably defuses the problem of choice of the setting P >. The following is required:

1. The minimum active power component P0 of the compensated system existing in case of the most unfavourable system configuration. It has to be indicated for a displacement voltage of 100%, i.e. without fault resistance. The resistive residual current is also sufficient without consideration of fault resistance, as can be seen from the following.

2. The level of the displacement voltage UNE as of which a direction decision is to take place.

3. The duration up to achieving the steady earth-fault state for certain. The setting for the active power of the compensated system has to be entered normalized for rated current and rated voltage:

nn

s

UIPP⋅

=> 0

with P0s: secondary power downstream of the system transformers In: chosen rated current of the DDE(Y) 6's earth-current transformer IN Un: nominal voltage of DDE(Y) 6 (“334 Un VT sec.“ (or, if UNE is measured: “337 Un VT sec. U4“)

It is recommended to choose the setting value P > as follows:

nIE

rwp

n

rws

nn

rws

IrI

II

UIP

P⋅

⋅=⋅=⋅

⋅≈> ___0 5.05.05.0 5-26: Earth-fault direction, setting value P>

with P0s_rw: secondary active residual power downstream the system transformers

for UNE=Un (Rfault=0 Ω) Is_rw: secondary resistive residual current Ip_rw: primary resistive residual current rIE: transformer ratio of cable-type current transformer Ip/In

In the equation, the requirement mentioned in the beginning was assumed, i.e. that P0s_rw was

determined for UNE=Un. Thus, the following applies: n

rws

nn

rwsn

nn

rws

II

UIIU

UIP ___0 =

⋅

⋅=

⋅. The detour via a

Functions


power determination is not necessary but only the secondary resistive residual current in Amps is relevantly for the input. If there is e.g. a resistive current component of 2% in the earth-fault current IE of the system, P> can be selected as follows

nIE

Ep

n

Es

n

Es

IrI

II

IIP

⋅⋅=⋅=

⋅⋅≈> 01.001.002.05.0

IEs: secondary earth-fault current IEp: primary earth-fault current

The pickup value of the displacement voltage “7002 UNE>EF“ is decisive for the release of the protection function "Earth-fault detection" (see a previous chapter). It should be set to a value higher than a displacement voltage occurring during normal operation under sound net condi-tions, but as far as possible not below 25 V. The earth-fault recognition time “7014 tUNE>EF Time f. UNE>“ must be definitely set to a value longer than the time of the transient phenomena (e.g. magnetic reversal of reactance coil) occurring in case of earth faults in the compensated system. This is to guarantee the stationary state for the direction decision. Transient phenomena represent a considerable source of errors for the wattmetric earth-fault direction decision in the compensated system! Sufficient time is available in most cases in the compensated system for the direction determination, as hazards are reduced strongly due to low earth fault currents. Remarks:

• In case of UNE>EF setting values of < 25 V, the earth-fault detection is not secured suf-ficiently in the compensated system; thus, a higher pickup value should be selected.

• If the earth current occurring during SDLRE (5.4.3.1) is within the measuring range of the earth current transformer of DDE(Y) 6, utilization of the “532 SDLRE Automatic“ can also be waived via adjustment - setting: “not connected“. Thus, the protection module "Earth fault detection" will perform the direction decision based on the measured earth current.

• With the non-directional “7032 TRIP at Earthfault“ enabled, the timer tTRIP is to be set to values > 0.25 s when the earth fault direction is to be signalled simultaneously.

Output of TRIP command For the compensated-neutral system, in addition to the direction report, the possibility to issue a direction-dependent TRIP command is provided. To this effect, "7030 TRIP at Earthfault" must be enabled. The TRIP command can be issued dependent on the supplementary condition which can be selected under "7032 TRIP at Earthfault". Simultaneous exceeding of the weighted earth fault power – P>/fb – is also required for TRIP, like for the direction decision. On principle, the direction decision is started upon detection of the status "earth fault", i.e. after expiry of the timer module "7014 tUNE>EF Time f. UNE>". After determination of the direc-tion (time need see 3.8), it is issued as output command, and general starting and the timer tTRIP ("7011 tTRIP if Earthfault") are started. This timer determines the additional delay of out-put of the TRIP command. If there is a distance protection or an IL>(>>>) start simultaneously with the earth fault, the earth fault treatment is finished and the system switches over to short-circuit treatment. Outputs of the earth-fault direction decision In addition to the earth current IE measured via the earth current transformer IN, the current value of the displacement voltage UNE can be monitored. In most cases, access to the display of the protection device will not be possible during an earth fault. Thus, the set of measured values available on the first direction decision, incl. the active and reactive power, the weighting factor components fP and fU, is saved in the event memory.

Functions


Regarding the evaluation, the factor fP is especially relevant, as it is a measure for the reliability of the direction statement – a factor greater than 1 means a considerably higher reliability than a factor lower than 1. The following simple equation applies to determine the total factor fb, by which the measured power is multiplied prior to the comparison with the preset pickup value, from factors fP and fU:

UPb fff ⋅= 5-27: Determination of the total factor fb

Output commands regarding the earth fault direction report “7071 EarthFlt. forw.“ “7072 EarthFlt. rev.“ are available to be configured freely to relays, LEDs and virtual inputs.

5.7.3 Wattmetric earth fault direction decision, isolated system (not DD6) A prerequisite of the direction determination is the detection of an earth fault as explained under item 5.7. Also in the isolated system, the displacement voltage from the three phase-to-earth voltages and the current provided by the earth current transformer IN is used. The earth current transformer IN is intended for connection to a cable-type current transformer. Important: • The correct connection to the cable-type current transformer represents an essential factor

for the success of the direction decision procedure. Thus, the cable screen may not be grounded until returning through the transformer to eliminate cable screen currents from the measurement current.

• On the voltage side, V-connection is not admissible. • The neutral point of the three voltage transformers must be earthed. In the compensated system, there is relatively much time to determine the earth fault direction; normally, it is not necessary to issue immediately a TRIP command by the protector. In some iso-lated systems, there may be a hazard due to higher earth fault currents, so that tripping must be possible within a short time. This may result, amongst other things, in the differences in the method of action for direction determination in compensated systems, as explained below. In the case of isolated-neutral systems, the earth-fault direction is determined with the help of the reactive power Q. The measured reactive power is increased by the voltage-dependent factor fU described in the previous section, in order to compensate earth contact resistance (within cer-tain limits). The factor fU may increase up to a maximum value of 16. A direction decision takes place if the presented power Q * Factor fU > setting “7001 P> resp. Q> pickup“, in this case Q>. The active power does not affect the weighting. How is the forward direction defined? The direction decision in isolated-neutral systems is based on the following definition: If the relay recognizes the output of a capacitive reactive power (in the direction of the line), then forward direction has to be set. This applies to cases when a reactive power is recognized with a negative sign. The sign of the active power is of no importance for the direction. The conditions for U and I are represented in the vector diagram (Fig. 5.7-3). Which settings have to be carried out? The following is required:

1. the minimum reactive power Q0 of the isolated-neutral system, which is existing at the most unfavourable system configuration. It has to be indicated for a displacement voltage of 100%, i.e. without fault resistance. As pointed out in the previous section, the current ICE (without consideration the fault resistance) is also sufficient.

2. The level of the displacement voltage UNE as of which a direction decision is to take place.

Functions


The reactive power setting value (Q >) for operation of the direction decision is a secondary power value

nn

s

UIQ

Q⋅

=> 0 .

with Q0s: secondary power downstream of the system transformers

In: chosen rated current connection of the DDE(Y) 6's earth-current transformer I Un: nominal voltage of DDE(Y) 6 (“334 Un VT sec.“ (or, if UNE is measured: “337 Un VT sec. U4“)

The setting value Q> can be chosen as follows:

nIE

Cep

n

Ces

nn

s

IrI

II

UIQQ

⋅⋅=⋅=

⋅⋅≈> 5.05.05.0 0 5-28: Earth-fault direction setting value Q>

with Q0s: secondary reactive power for UNE=Un (RFault=0 Ω)

ICes: secondary capacitive reactive current ICep: primary capacitive reactive current rIE: transformer ratio of cable-type current transformer Ip/In

Remark:

In case the reactive power applied to the protection device is considerably higher than the up-per adjustable value for Q>, the connector 1n=5A of earth current transformer can be used instead of In=1A. The power provided for the DDE(Y) 6 is thus reduced to 1/5.

The pickup value of the displacement voltage “7002 UNE>EF“ is decisive for enabling the protec-tion function "Earth-fault detection". It should be set higher than to a displacement voltage that is occurring during operation in normal sound systems. Output of TRIP command For the isolated-neutral system, the DDE(Y) 6 provides, in addition to the direction report, the possibility to issue a direction-dependent TRIP command. To this effect, “7030 TRIP at Earthfault“ must be enabled. The TRIP command can be issued depending on the direction which can be selected under “7032 TRIP at Earthfault“. Simultaneous exceeding of the weighted earth-fault power – Q>/fb – is also required for TRIP, like for the direction decision. On principle, the direction decision is started upon detection of the status "earth fault", i.e. after expiry of the timer module “7014 tUNE>EF Time f. UNE>“. After determination of the direc-tion it is issued as output command, and general starting and the timer tTRIP (“7011 tTRIP if Earthfault“) are started. This timer determines the delay of output of the TRIP command. In case of time settings of the two timers to 0 s, the trip time specified under 3.8 is reached. If there is a distance protection or an IL>(>>>) start simultaneously with the earth fault, the earth fault treatment is finished and the system switches over to short-circuit treatment. Outputs of the earth-fault direction decision In addition to the earth current IE measured via the earth current transformer IN, the current value of the displacement voltage UNE can be monitored. In most cases, access to the display of the protection device will not be possible during an earth fault. Thus, the set of measured values available on the first direction decision, incl. the active and reactive powers and the weighting factor component fU, is saved in the event memory.

Output commands regarding the earth fault direction report “7071 EarthFlt. forw.“, “7072 EarthFlt. rev.“ are available to be configured freely to relays, LEDs and virtual inputs. Important:

Functions


• The earth fault start IE>(>>>) is irrelevant for the start of the direction decision; only the pickup value Q> of the earth fault power must have been exceeded if an earth fault has been detected.

• For the choice of the sum-current transformer of the installation the maximum measure-ment range of the earth current transformer input IN also has to be taken into account for the earth-fault direction decision, see 3.8.1.

• The timer tUNE> must be set to "0 s" in the isolated-neutral system, in addition to tTRIP, if the shortest trip times (sum from tUNE>, tTRIP and time for direction decision) are required.

Application of the AR The AR can be used for resetting earth faults or for selection of the system part subject to an earth fault. The application of the AR in case of an earth fault in the isolated-neutral system re-quires enabling of the TRIP command for the earth fault direction: “7030 TRIP at Earth-fault“. In the protection function menu "AR", the setting “9942 Earthfault AR Start“ be used to select whether

• the AR is to be started, • it is started, depending on the presence of the earth fault direction "forward", or - in case

an earth fault is present - if the direction decision is blocked, or • whether the AR is to be started after a TRIP by the earth fault detection.

For further details regarding the AR, see section 5.11. Application in conjunction with the teleprotection system The teleprotection procedures (5.12) provide distance- and direction-related modes of operation. The earth fault direction decision in the isolated-neutral system can ensure the required coopera-tion in which the general start is generated and the determined direction transmitted. The applicability is based on the enabling of the TRIP command for the earth fault direction: “7030 TRIP at Earthfault“ and the enabling of “7031 EarthFaultDirection“. In the pro-tection module "Teleprotection system“, the influence of the determined earth fault direction on signal comparison can be activated by enabling the start of teleprotection “19035 Start TP with EF/IE“.

Functions


5.8 Switch-On Protection (SOP) The switch-on protection within the distance protection is to treat essentially the switching on of an outgoing feeder following a short-circuit (shunt fault), and is consequently called short-circuit switch-on protection. This function is explained in the following section 5.8.1. Moreover, in case that starts of “IL> (Emerg.) OTP“, “IE> (Emerg.) OTP“ or the negative-sequence protection are used, an extended functionality is available; see section 5.8.2. As basic condition for the switch-on protection, the setting which has been selected on delivery “430 Sig. CB Manual Close“ “available“ in “Equipment Adaptation / CB Adaptation“ must be unchanged. This enables the switch-on protection to be used. The CB manual CLOSED signal is the characteristic for connection of the protected object. The physical CB Manual CLOSE signal can be communicated to the function in two ways:

• CB CLOSE signal communicated internally by the substation control part (“51638 CB Close from SCADA“) Note:

This signal can only be activated by the CB with the smallest node number (e.g. Q0 01.-01) in the control system setting.

Or / and • input signal “460 CB closed manually“.

In case of direct connection to the CLOSE coil of the switch, the input signal “460 CB closed manually“ can also signal closing operations that are not routed via the control module of the DDx 6.

The period of time for which the switch-on protection is to be active must be defined via the timer “8005 top Operat.Time SOTF“ (hereinafter: topSOTF). This timer is started with the active edge of the CB Manual CLOSE signal. Upon expiry of the operating time, the protective function Switch-On Protection is terminated.

The switch-on protection can be blocked upon enabling in the settings “8098 Blockage SOTF“ “connected“ via the input signal “8099 Blockage SOTF“. The enabled protection module Switch-On Protection and a blockage can be signalled via the output commands “8090 SOTF FctOn“ and “8099 Blockage SOTF“.

5.8.1 Switch-On Protection in the case of use of distance starts An enhanced error probability exists on connecting outgoing feeders. Thus, short response times are required on detection of a short-circuit within a connection period. The switch-on to fault protection (SOTF) is effective after a CB Manual CLOSE input signal for the preset time topSOTF. Its task consists in detecting connection following a short-circuit and in requesting an undelayed TRIP command once the prerequisites have been complied with. The following conditions can be selected for requesting the TRIP command “8430 TRIP SOTF undelayed“: • “if Distance Start“, i.e. at least one (U-)I or Z< start is present • “if Z in Z1“, the measured fault impedance Z is within the zone Z1 • “if Z in Z1x“, the measured fault impedance Z is within the zone Z1x • “if Z in Z2“, the measured fault impedance Z is within the zone Z2. The prerequisite for cooperation of the switch-on protection with the distance protection is ena-bling of “8400 Distance TRIP SOTF“. The shortest trip time is naturally reached with the condition TRIP in case of “if Distance Start“. However, this variant operates non-directionally. If a distance zone is selected as trip condition, the preset direction of this zone is also taken into account.

Functions


Fig. 5.8-1 Switch-onto fault protection with distance starts

Remark: In case of distance-dependent settings, the case of fault of connection with the earthing switches engaged in the remote station must also be taken into account in most cases. This case would not be treated in the instantaneous zone with the setting “if Z in Z1“. Utiliza-tion of the overreach zone “if Z in Z1x“ or, if not enabled, by “if Z in Z2“, is benefi-cial.

The TRIP command generated by the short-circuit switch-on protection together with the dis-tance stage can be signalled via the output command “8480 SOTF Distance“ as well as a run-ning operating time, with “8079 top SOTF runs“. In the case of the voltage path fault and the earth short-circuit direction decision, the switch-on protection can also cooperate in a meaningful fashion with the (emergency) overcurrent time pro-tection, see 5.8.2. Important:

In the case of voltage transformers on the line end, no voltage memory is available for the di-rection decision on switching ON; a three-pole short-line fault is switched off by definition with "preferred direction“, i.e. in this case, a distance zone is considered as "non-directional“.

5.8.2 Switch-on protection in case of use of the overcurrent time protection In case of

• switched-off distance protection or • utilization of the (emergency) overcurrent time protection or the negative sequence protec-

tion in parallel with the distance protection, e.g. in case of faults in the voltage path,

8000 Switch-On Protection

8099 Blockage SOTF &

8098 Blockage SOTF

H

H

8090 SOTF FctOn

8099 Blockage SOTF

SOTF ready &

8400 Distance TRIP SOTF H

enabled disabled

enabled disabled

H

8430 TRIP SOTF undelayed if Distance Start

if Z in Z1 if Z in Z1x if Z in Z2

&

8005 top Operat. Time SOTF

0...60 s

D R

H

8490 Dist. SOTF FctOn

&(U-)I or Z< Start

&

&

&

≥1Z < Z1

Z < Z1x

Z < Z2

8480 SOTF Distance

8079 top SOTF runs

DDx 6

GenTRIP

460 CB closed manually

≥1 CB Close from control

51638 CB Close from SCADA

H yes

&

connected

Functions


an enhanced functionality of the switch-on protection is provided. Remark:

The suppression of starts or TRIP commands described below does not apply to the distance starts (U-) I, Z< and the TRIP of the distance stage.

The switch-on protection for overcurrent time protection functions has the following tasks,

• detection of switching on to short-circuit and generating a final TRIP command, and, on the other hand,

• in case of switching on an initially high load (motor, transformer), blocking a TRIP com-mand or optionally a start by IL>(>>>) and / or IE>(>>>), IEint and Ineg>(>) for the con-figurable operation time of the switch-on protection topSOTF.

In addition to tripping in case of switch-on to short-circuit, suppression of switch-on effects for the overcurrent time protection and the load unbalance protection (negative sequence system) is possible. Depending on the setting, suppression of the starting signals due to the switch-on cur-rents of inductive operating equipment is possible. Contrary to inrush restraint, this function can also be used to handle switch-on procedures without increased harmonic contents. Due to the required utilization of the input signal "CB closed manually“, its effect remains limited in time to the switch-on procedure, whereas the harmonic evaluation of the inrush restraint is effected in-variably.

Functions


Fig. 5.8-2 Active principle Switch-On Protection

(Phase overcurrent time protection IL> shown, earth overcurrent time protection IE> and nega-tive sequence system Ineg in analogy)

The switch-on protection has its own current settings for phase overcurrent “8101 IL>SOTF“, earth overcurrent “8201 IE>SOTF“ as well as for negative sequence current “8301 Ineg> SOTF“. In addition, the appropriate reset ratios can also be adapted as required: “8104 Reset Ratio IL>SOTF“, “8204 Reset Ratio IE>SOTF“ and “8304 Reset Ratio Ineg>SOTF“.

If the switch-on protection is to work with the earth overcurrent starting, devices with a fourth current transformer (IN) permit to decide between measurement or calculation of the IE with the setting “8233 Value for IE>SOTF“. The advantage of a direct earth current measurement (cable-type current transformer) versus the calculation is its higher accuracy (no wrong currents).

&8005 Top Operat. Time SOTF

8030 I SOTF: Sup-pression Start by I> TRIP by I>

8111 tIL>SOTF

Time

8171 IL1>SOTF Start

8172 IL2>SOTF Start

8101 IL>SOTF

8104 Reset Ratio

IL>SOTF IL1>SOTF

IL2> SOTFIL3> SOTF

8173 IL3>SOTF Start

8180 tIL>SOTF expired

&

&

&

D R

H

“1101 IL>“ ≤ “8101 IL>SOTF“

1111 tIL>

&

&

IL1 IL2 IL3

not if error U path

H

&

1101 IL>-Definite Time

IL1 IL2 IL3 Blockage IL>

8136 IL>SOTF if ErrorUPath

8079 top SOTF runs

&

enabled disabled

8100 IL>SOTF Start

H

&8190 IL>SOTF FctOn

Error U Path

≥1

SOTF ready

even if error U path only if error U path

&

&

DDx 6

IL> (Emerg.) OTP: IL>

IL> (Emerg.) OTP: IL>>

IL> (Emerg.) OTP: IL>>>

IL> (Emerg.) OTP: IL>>>>

Switch-On Protection

GenTRIP

GenTRIP

460 CB closed manually

≥1 CB Close from control

51638 CB Close from SCADA

H yes

&

Functions


Another setting regarding the effectiveness of the IL>SOTF and the IE>SOTF starts in conjunction with a recognized fault in the voltage path can be effected via “8136 IL> SOTF if ErrorUPath“ and “8236 IE>SOTF if ErrorUPath“:

• “not if error U path“ • “even if error U path“ • “only ifErrorU path“

This enables the behaviour of the switch-on protection to be controlled in the case of voltage path faults and consequently of switched-off direction and distance determination. The function requires the following timers:

• “8005 top Operat.Time SOTF“ operating time of switch-off protection following a CB Manual CLOSE signal

• tI>SOTF trip delay time of the switch-on protection, subdivided into the phase current trip time “8111 tIL>SOTF Time“, the earth current trip time “8211 tIE>SOTF Time“ and the negative sequence trip time “8311 tIneg>SOTF Time“. All timers operate inde-pendently of the current.

To detect switching on, the signal “CB closed manually“ - must be used. The SOTF acts for the duration of topSOTF as of the starting edge of the CB Manual CLOSE binary signal.

The starting modules of the overcurrent time protection IL>, IL>>, IL>>>, IL>>>>, IE>, IE>>, IE>>>, IE>>>> and the negative sequence I, i.e. Ineg>, Ineg>> are only influenced by the switch-on protection if their pickup value is lower than or equal to the module IL>SOTF, IE>SOTF or Ineg>SOTF of the switch-on protection (and, in special cases, with the distance protection switched off, the selected direction corresponds to the direction of the switch-on protection). All current stages IL, IE and Ineg which are set higher than the appropriate current value of the switch-on protection I>SOTF, are not affected.

The behaviour of the overcurrent time protection and negative sequence protection starting mod-ules during the current operating time topSOTF can be selected using the function switch “8030 ISOTF: Suppression“ jointly for all current stages: • using “TRIP by I>“ the IL>, IL>>, IL>>>, IL>>>>, IE>, IE>>, IE>>>, IE>>>>,

Ineg>, Ineg>> starts influenced by the switch-on protection are admitted, but their TRIP command at the end of their respective stage times blocked pending expiry of topSOTF. If the specific stage time is lower than the operation time, the TRIP is generated on expiry of topSOTF when a start is present, if it is greater, the TRIP is created upon expiry of the specific stage time. All messages, event entries and the disturbance data logging are performed.

• using “Start by I>“ the IL>, IL>>, IL>>>, IL>>>>, IE>, IE>>, IE>>>, IE>>>>, Ineg>, Ineg>> starts influenced by the switch-on protection are blocked. Any exceeding which is already present during the current operating time is not recognized before expiry of topSOTF and the measurements, event entries, disturbance data logging and the start of the appropriate stage time are not effected before such recognition. Thus, tripping is delayed by another topSOTF.

Fig. 5.8-3 shows the method of action and the possibilities of switch-on protection together with two current starts and timer modules recorded as an example.

Functions


IL>>

IL>SOTF

IL>

tIL>> tIL>SOTF tIL> TopSOTF

Switching on of transformer

short circuit at the line

short ciruit on remote line

weak current fall

Fig. 5.8-3 Example: application of the switch-on protection

If the parameterization is correct, switch-on procedures with increased current can be distin-guished from switching on following a short-circuit and normal overcurrent starting. Operational sequence (Fig. 5.8-3):

1. Start of timer topSOTF (operating time of switch-on protection after Manual Close) with re-ceipt of the active edge of the “CB closed manually“ signal.

2. Only within the current time topSOTF • a general start and TRIP decision are made, delayed by tI>SOTF, when I > “I>SOTF“.

If “I>>“ has also been exceeded, its time tI>> is also started and the shorter of both issues the TRIP.

• If only "I>SOTF“ > I > "I>“, the operations depend on the selected setting “8030 ISOTF: Suppression“ of “Trip by I>“ or “Start by I>“.

o If the suppression of “Trip by I>“ was selected, the general start is sig-nalled in addition to the I> start, and the appropriate timing module tI> started. However, the TRIP command is blocked until the timer topSOTF expires.

o If suppression of the “Start by I>“ has been selected, the current start, general starting and consequently TRIP are blocked during the time topSOTF for this current stage.

3. After expiry of the operating time topSOTF and • continuing presence of the I> start,

o the blockage of the TRIP command is suppressed if suppression “Trip by I>“ is set. After expiry of timer tI> which has already been initiated on start-ing, the TRIP is issued. The trip time is determined by the longer time topSOTF or the stage time tI>.

o the blockage of the I> stages is suppressed if suppression “Start by I>“ is set. This results in general start and the stages start their time sequence un-impeded. As trip time, the sum of topSOTF and the stage time tI> is used.

• without I> start, the effect of the switch-on function ends.

Remarks: - Regarding Inverse Time characteristics, it must be taken into consideration that the starting

limit thereof is 1.1 times their setting. The current starts “I>SOTF“ and I> are set equally in the Inverse Time module, if: “I>SOTF“=1,1⋅”I>“.

- If phase starts and earth starts exist, their appropriate timers have been started. Tripping will be performed by the shortest one.

Extended properties of the earth fault current stage: The starting capacity of the IE>SOTF stage and consequently the enabling for generation of a TRIP command can be influenced in analogy to the "IE> (Emerg.) OTP“ protection (5.6.3) with the

Functions


settings under “8237 IE> SOTF Start“. Normally, IE starting alone does not authorize to trig-ger starting in the distance protection. The setting option was created

• to realise the earth short-circuit direction protection(“not if IL/Dist Start“) or • for any overcurrent time protection working in parallel to the distance protection (“only

if IL/Dist Start“) or • for switched-off distance stages as well as directional stages.

In addition, in case of the enabled earth short-circuit direction decision within the earthed sys-tem, a directed tripping by the switch-on protection can be achieved if the prerequisites for direc-tion determination (5.4.3) exist during the switching-on process. To this effect, the required trip-ping direction can be selected with “8231 IE>SOTF Direction“.

Special case: switched-off distance protection and enabled direction: • Within the earthed system, the 2/3 criterion can be activated for phase current activation

(see in 5.6.4). • For the effectiveness of the phase current stage IL>SOTF and the earth current stage

IE>SOTF, the forward direction or even "non-direction" can be specified separately “8131 IL> SOTF Direction“ “8231 IE>SOTF Direction“.

• Remark: The setting “Suppress“ “Start“ prevents phase starting while the operating time top-

SOTF is running. If there is a UNE> start in the non-earthed system simultaneously with the phase starts during expiry of the topSOTF, an earth fault treatment is performed due to the suppressed phase start. This effect must be taken into consideration if used for non-earthed systems.

The TRIP command generated by the switch-on protection together with the distance starts can be signalled via the output command “8180 tIL> SOTF expired“, “8280 tIE>SOTF ex-pired“, “8380 tIneg>SOTF expired“ as well as a running operating time, with “8079 top SOTF runs“. Phase-specific start signals are available with the output commands “8171 IL1> SOTF Start“, “8172 IL2> SOTF Start“, “8173 IL3> SOTF Start“ and “8270 IE> SOTF Start“. Further start signals are “8370 Ineg> SOTF Start“ and the comprehensive “8070 SOTF general Start“. Important:

• A Manual Close signal must be provided as a prerequisite for this function “430 Sig. CB Manual Close“ “available“ and be supplied physically either via the substation con-trol or an optocoupler input.

• The time “8005 top Operat.Time SOTF“ must be set to a value longer than the switch-on protection times “8111 tIL> SOTF Time“,“8211 tIE>SOTF Time“ and “8311 tIneg>SOTF Time“ and longer than the inrush process, if the latter is to be con-trolled.

• If, in a special case, I> and I>SOTF are set to identical values, the switch-on protection only operates as a short-circuit switch-on protection, i.e. it is tripped after tI>SOTF in case I> is exceeded.

Setting: 1. The availability of the CB manual CLOSE signal “430 Sig. CB Manual Close“ must be

communicated in the menu “Setting Set / Setting / Setting Values / Equipment Adaptation / CB Adaptation“.

2. Enabling of the switch-on protection, the envisaged connection of a blockage signal, enabling in case of distance TRIP and the appropriate condition, activation of starting modules, the behaviour in case of a voltage path fault, the effect of the switch-on protection and the set-ting of the pickup and reset values and timers, as well as any direction specification and compliance with the 2/3 current criterion can be performed under “Setting Set / Setting / Set-ting Values / Protection Modules / Character. setx / Switch-On Protection“.

Functions


3. If the “CB closed manually“ is issued by substation control, utilization thereof under “Setting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“ “51638 CB Close from SCADA“ must be confirmed with "yes”. If the “460 CB closed manually“ signal reaches the device via an optocoupler, the re-quired optocoupler input must be assigned under “Setting Set / Setting / Inputs / Equipment Adaptation / CB Adaptation“.

4. If a blockage is intended, the required binary input must be configured under “Setting Set / Setting / Inputs / Protection Modules / Switch-On Protection“.

5. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Switch-On Protection“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Switch-On Protection“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Switch-On Protection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.9 Monitoring of negative sequence I (load unbalance, unbalance) The negative sequence protection is used for monitoring of the • balance of the power consumed by an object to be protected. The negative sequence com-

ponent of a natural system informs about the extent of the present unbalance. This function is especially important to protect machines which are subject to a thermal load by this com-ponent.

• Likewise, asymmetric faults (single-pole, double-pole short-circuits) can be detected, if their current is lower than the maximum load current.

• A phase break can also be detected via a current unbalance. • This function is excellently suited, for initial operation, to detect interchanged current trans-

former terminals (phase sequence monitoring in the current circuit).

Fig. 5.9-1 Active principle, negative sequence protection I, stage Ineg> shown

After enabling this protection function with “3100 Ineg> Start“ or “3200 Ineg>> Start“, up to two stages are available. The characteristic of the first of these stages is selectable “3132 Ineg> Timer Module“. Besides the current-independent characteristic, the dependent charac-teristics treated under the timer modules of the phase overcurrent time protection are available (5.6.2.2). The r.m.s values of the negative sequence component are used for stating. When the pickup value “3101 Ineg> Definite Time“, “3102 Ineg> Inverse Time“ or “3201 Ineg>>“ is exceeded, the timer modules concerned are started (“3111 tIneg> Time“, “3112 tIneg> Time Factor“, “3211 tIneg>> Time“), commands set and events signalled. If the reset value is undercut (“3104 Reset Ratio Ineg>““3204 Reset Ratio Ineg>>“) the timer module and the commands are reset and the signals are set to "outgoing". “9280 TRIP final“ is generated and signalled on expiry of the timer module.

3101 Ineg> Definite

Time

3100 Ineg> Start 3190 Ineg> Start FctOn

3199 Blockage Ineg> &

3198 Blockage Ineg>

H

H

3199 Blockage Ineg>

3170 Ineg> Start

IL1 IL2 IL3

3132 Ineg> Timer Module

H

Definite Time

longtime inverse

inverse

very inverse

extreme inverse

3111 tIneg

&

3104 Reset Ratio

Ineg>

3112 tIneg> Time Factor

3113 tI-neg>max Time

Delay

&

3102 Ineg> Inverse

Time

3104 Reset Ratio

Ineg>

GS

3180 tIneg> expired

t=f (I)

≥1

D... 6

≥1

&

enabled

3275 Ineg gen. Start ≥1

Ineg>> Start

GenTRIP

connected

Functions


In addition to the comprehensive start command “3275 Ineg gen. Start“, the individual stage commands “3170 Ineg> Start“, “3270 Ineg>> Start“ are available to signal negative sequence I starts (load unbalance). The expired timer module can be signalled with “3180 tI-neg> expired“ or “3280 tIneg>> expired“.

If the IDMT characteristic is selected - which makes sense, e.g. for the protection of motors - a maximum time for tripping is defined as in case of the IDMT overcurrent time protection stages: “3113 tIneg>max Time Delay“. In case of the dependent characteristics, it must be taken into consideration that starting only takes place as of 1.1 times the current setting (Ineg>). The resetting ratio also refers to this value. Important:

The function is only active for phase currents<4⋅In (ILmax <4⋅In). The negative sequence protection can be biased against inrush operations. The second harmonic (100 Hz) of an inrush current represents a negative sequence. Thus, the protection module "In-rush restraint“ (5.10) provides for a corresponding setting: “6840 Inrushstab. Ineg>“ and “6841 Inrushstab. Ineg>>“ in case of inrush detection in the phase currents. In the protection module "Switch-on protection“ (5.8) settings can be used for its operating time to increase the pickup value “8301 Ineg>SOTF“, time adaptations “8311 tIneg>SOTF Time“ when “8300 Ineg> SOTF Start“ are enabled accordingly. The negative sequence stages can be blocked individually “3198 Blockage Ineg>“,“3298 Blockage Ineg>>“. To this effect, the appropriate input signal “3199 Blockage Ineg>“, “3299 Blockage Ineg>>“ must be used. The signal designated in an analogous fashion can be used for signalling purposes. Setting: 1. The enabling of the negative sequence protection, the intended connection of a blockage sig-

nal, the enabling of the required stages and - for the first stage - the selection of the time de-pendence and setting of the pickup values, resetting ratios and timer modules can be effected under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Nega-tive Sequence I“.

2. If required, the required optocoupler input must be configured for the blockage signals under “Setting Set / Setting / Inputs / Protection Modules / Negative Sequence I“.

3. The outputs to relays must be selected under “Setting Set / Setting / Relays / Protection Modules / Negative Sequence I“, those to LEDs under “Setting Set / Setting / LED / Protec-tion Modules / Negative Sequence I“.

4. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Negative Sequence I“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.10 Inrush restraint (harmonic restraint) When transformers operating at no load are switched on, inrush current peaks occur according to the rush effect (magnetizing current). The currents may reach peak values up to 8·In and occur only at the connected winding end of the transformer. Similar phenomena can also be observed when transformers are connected in parallel, however, with a considerable time delay after paral-lel connection.

Important: The inrush restraint can be used for the (emergency overcurrent time protection). The dis-tance starts are not affected.

If the ratio of first harmonic to the fundamental component exceeds the adjustable pickup value “6801 I2f/I1f> (IL)“ in a phase whose r.m.s value has exceeded the pickup threshold IL> of the overcurrent time protection, the current starts enabled for inrush restraint(“6831 In-rushrest. IL>“, “6832 Inrushrest. IL>>“, “6833 Inrushrest. IL>>>“, “6834 In-rushrest. IL>>>>“) of the appropriate phase are blocked. The current stages of the switch-on protection (SOTF) are not affected by the closing lock-out on principle. As standard, crossblocking (intertripping the other started phases) has been set “6830 In-rushrest. IL“: “Crossblock“. Exceeding the I2f/I1f ratio in one of the started phases is suffi-cient to block the starting and the tripping, independently of the harmonic content of the other phases. Cross-blocking can be limited in time using the timer “6814 top Crossblock“.

If crossblocking is not used (“singleblock“), the harmonics of all started phase currents must exceed the setting“6801 I2f/I1f> (IL)“ to result in blocking of the enabled phase current starts IL> to IL>>>>.

The earth current IE is not analysed for its harmonic contents being exceeded. Instead, for each IE stage, a separate selection can be made (“6835 Inrushrest. IE>“, “6836 Inrushrest. IE>>“, “6837 Inrushrest. IE>>>“, “6838 Inrushrest. IE>>>>“), as to whether exceed-ing the “6801 I2f/I1f> (IL)“ value in the phase current is to result in blockage or not. While the lowest IE starting threshold to be biased (=initiation of harmonic weighting), no phase current start is required to exist in order to perform weighting of the harmonic content. The only condition is that the current in the phase to be evaluated exceeds 0.2⋅In. If the setting “Cross-block“ has been selected, exceeding the harmonic ratio in a phase current of >0.2⋅In is suffi-cient; in case of “Singleblock“ all phase currents >0.2⋅In must have exceeded the harmonic ratio to enable blockage of the enabled IE starts.

In analogy to the description of the influencing of the IE start by the inrush restraint, the start of the negative sequence current stages can also be influenced by setting “6840 Inrushstab. Ineg>“ or “6841 Inrushstab. Ineg>>“ accordingly; i.e. in this case, the phase currents of phases >0.2⋅In are weighted for their harmonic content and - taking cross- or singleblock selec-tion into account - blockage of the negative sequence current start is generated. An important setting is the maximum value for the phase current “6808 Inrushrest. up to IL“ up to which the 2nd harmonic is weighted. This is important to prevent blockage of tripping in case of a higher 2nd harmonic content due to transformer saturation. If this maximum value is exceeded in a phase, the inrush restraint is finished. To this effect, the maximum value would have to be selected as low as possible in order not to prevent the locking out of short-circuits. Contrary to current starts, the r.m.s value including its aperiodic component is used for monitor-ing the maximum value. Thus, the currents displaced by aperiodic components (possibly up to almost the double value) are integrated in the check for the maximum value. This permits a more realistic mapping of the transformers’ real behaviour.

Functions


6871 Inrushrest. L1

6872 Inrushrest. L2

6873 Inrushrest. L3

≥1

&

≥1

&

&

D... 6

6800 Inrush Restraint

6899 Blockage IR &

6898 Blockage Inrushrest.

H

H

6890 Inrushrest.FctOn

6899 Blockage IR

& enabled

6870 Inrushrest. gen.

6801 I2f/I1f> (IL)

iL1

iL2

iL3

IL2 IL3

ILmax < 6808

Inrushstab up to IL

IL1

≥1

≥1

6814 tw &

&

&

&

&

&

&

&

&

IL1 > 1101 IL>Definitite Time IL1

IL1 > 1102 IL>Inverse Time

IL1 > 1201 IL>>

IL1 > 1301 IL>>>

IL1 > 1401 IL>>>>

IL2 > 1101 IL>Definitie Time

IL2


IL2 > 1201 IL>>

IL2 > 1301 IL>>>

IL2 > 1401 IL>>>>

IL3 > 1101 IL>Definite Time IL3


IL3 > 1201 IL>>

IL3 > 1301 IL>>>

IL3 > 1401 IL>>>>

&

&

&

&

&

&

&

&

&

&

6831 Inrushrest. IL> enabled

&

H

H

6832 Inrushrest. IL>>

H

6833 Inrushrest. IL>>>

H

6834 Inrushrest. IL>>>>

enabled

Blockage IL>

Blockage IL>>

Blockage IL>>>

Blockage IL>>>>

&

&

&

H 6830 Inrushrest. IL

Crossblock

Singleblock L

&

&

&

≥1

&

connected

Fig. 5.10-1 Active principle Inrush restraint for phase current start, overcurrent-time protection

Functions


If the procedure is classified as power system fault (e.g. if no Crossblock has been selected and the harmonic ratio is not satisfied in a started phase), the inrush restraint is deactivated and any inrush restraints, which are already active in individual phases, are reset. The protection module "Inrush restraint“ can be blocked via an input “6899 Blockage Inrush-stab.“ after having entered the intended utilization of the blockage input in “6898 Blockage Inrushrest.“. The started phases which show exceeding of the harmonic content are available via the output commands “6871 Inrushrest. L1“, “6872 Inrushrest. L2“, “6873 Inrushrest. L3“ for further processing or signalling“6870 Inrushrest. gen.“ is available as collective com-mand. Remarks: • The protection function “Inrush restraint“ should only be switched on if it is required. It ex-

tends the command time of the overcurrent time protection by min. 20 ms if the current is in its range of action.

• Contrary to the function Switch-on protection SOTF, the “Inrush restraint“ is also used to detect external inrush procedures of transformers, as the harmonic monitoring is working continuously.

Setting: 1. The enable, the intended connection of a blockage signal, the mode of operation (Crossblock

or Singleblock), the selection of the current starts to be blocked and the setting of the pickup value, the maximum value and the Crossblock time can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Inrush Restraint“.

2. For a blockage, the required optocoupler input must be configured under “Setting Set / Set-ting / Inputs / Protection Modules / Inrush Restraint“.

3. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Inrush Restraint“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Inrush Restraint“.

4. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Inrush Restraint“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.11 Auto-Reclose (AR) The device features an up to 5-shot, 3-pole AR. In addition, a synchrocheck "Synchrocheck AR“ can be used for reclosure (RC) of the distance protection DDEY 6. On principle, assuming system readiness, AR is effected as follows:

• Starting-up the AR when start condition is satisfied, using the non-final TRIP command • Dead times during which the arc can go out, thus eliminating any cause of fault • Validity tests are effected before reclosing is effected. In case of inadmissible RC, termi-

nation of AR and start of its blocking time • Reclosing,

o in case of success, termination of the AR cycle upon expiry of the reclaim time o in case of re-start with the start-up condition satisfied, further dead times and re-

closing up to a maximum admissible number. Subsequently, the reclaim time ex-pires.

• In case of restarting after the last possible reclosing, the AR is inactive, the main func-tions of the distance protection handle the error.

The function AR produces "TRIP not final" commands as long as "CB CLOSE by AR" commands are possible. If AR remains without success after the selected number of AR shots has expired, AR is terminated by the distance protection modules - unaffected by the AR - with the "final" TRIP command.

Prerequisites

Fig. 5.11-1 AR Enable and blockage

The AR can only be set and used if the ready signal coming from the circuit-breaker can be evaluated for an AR. The “432 Signal CB ready “ in the equipment adaptation must be set to “connected“ and be used in the AR as input signal "9963 CB ready". It is also useful to utilize “460 CB closed manually“ to stop AR from occurring while the line is being connected.

Due to the external enable options, there is a specific feature to AR. It can be selected via the function switch “9900 Auto-Reclosing AR“ for “disabled“, “enabled“ or “prepared“. The last-mentioned state enables all AR settings to be viewed in case that it is not enabled = acti-vated = effective at present.

The AR protection module can be switched ON and OFF externally via

9999 AR extern Blockage

H &

9998 Blockage AR

&

9990 AR FctOn

9961 AR ON-Pushbutton

9962 AR OFF-Pushbutton &

&

9999 AR extern Block-age

&

AR enabled

1

1

9900 Auto-Reclosing ARS

R enabled

prepared

disabled

H H L

H L L

&

&

51632 Cmd AR On/Off

H enabled

AR On

AR Off

D... 6

Saving, initializing of setting set

connected

Functions


• the substation control command "AR ON/OFF“, if it has been permitted: “51632 Cmd AR On/Off“ or

• one optocoupler input each “9961 AR ON-Pushbutton“ and “9962 AR OFF-Pushbutton“. At the same time, it must be ensured that an active signal is never applied to both inputs simultaneously.

Note: • Switching on or off operations act like a reparameterization of the protection device (many

settings are added or eliminated) incl. the non-volatile storage of the new state. No protec-tion modules are performed within a period of <200 ms.

• AR switching on or off is effected more quickly via a replacement of the characteristic set per optocoupler or using the AR blockage input, as the state need not be saved in the set-ting set.

The state of the protection module "AR“ is effected via the output command “9990 AR FctOn“, which is active when the AR is enabled. The maximum admissible number of reclosing operations is determined by the setting “9930 Number of AR Shots“.

The AR can be blocked by means of the input signal “9999 AR extern Blockage“ on the op-tocoupler input to be configured. Intended utilization must be communicated in the settings: “9998 Blockage AR“ “connected“. Both the final and non-final TRIP command – “9280 TRIP final“, “9270 TRIP not final“ – must be configured to the trip relay (see also 5.20). For further output commands of the AR for signalling purposes, see Table 21.

AR readiness

Fig. 5.11-2 AR readiness

AR readiness must exist on the first start-up (beginning of cycle). The autoreclosing function will be ready if • the AR is switched ON, • the input signal "9963 CB ready" is present,

9963 CB ready

9915 tb Blocking Time AR

9905 tblockAR CBC CB Close

&

9972 AR not ready

9963 CB ready

9971 AR ready

n > 9930 Number of AR Start

DDx 6AR enabled

AR cycle runs ≥1

461 CB Position On

462 CB Position Off &

≥1

L

H

9949 CB pos for AR ready

consider

do not consider

AR ready

&

Functions


• no “CB closed manually“ started by the signal “9905 tblockAR CBC CB Close“ of the AR is running,

• AR is not blocked (by a running blocking time or an external blocking signal), • no reclaim time is running due to the maximum number of reclosing operations reached, and • if the circuit-breaker is in ON and not in OFF position when the CB position signals (“9949 CB

Pos for AR Ready“) are taken into consideration and enabled.

From there, the effect of timer “9905 tblockAR CBC CB Close“ can be recognized, amongst other things: it serves to prevent an AR on manual reclosing of the outgoing feeder during the runtime. The output command pertaining to this timer “9979 tblockAR CBC runs“ signals ex-piry.

If the conditions are not met, the AR doesn't become effective. A “9280 TRIP final“ (instead of “9270 TRIP not final“ during the AR cycle) is generated in accordance with the settings outside of the protection function "AR“. The readiness of the AR can be signalled via the output commands “9971 AR ready“ and “9972 AR not ready“. In the case of a fault in the voltage path and selected direction or distance-dependent AR start-up, the AR is blocked due to the fact that no direction decision has been made. Note:

The prevention of a CB reclosing, which is in off position, is only then possible if “9949 CB Pos for AR Ready“ “consider“ is chosen and both position indications are connected to the inputs “461 CB Position On“ and “462 CB Position Off“. If only one of the indica-tions is available, the other one must be formed by negation and used.

AR start-up When the selected start-up condition is satisfied, the non-final TRIP command is issued, which is to be followed by an ON command after the dead time, provided that the prerequisites exist. For start-up of an automatic reclosure, the following can be admitted “9948 Distance AR Start“:

a) “if Distance Start“ – detection of a distance start (Z<, U-I start). The effect of this start-up condition can be limited to the first TRIP command with the set-ting under “9944 AR TRIP undelayed“ – “first TRIP only“ instead of “all non-final TRIPS“. If “first TRIP only“ is selected, all starts following the first TRIP are treated as de-scribed in the start condition, subsection c). This means that all the further starts of the AR are effected by the zone timers expired within the operating time “9919 top2 from 2ndDeadTime“ incl. classification to the appropriate distance zone.

b) “Dist.Start+forward“ or “Dist.Start+reverse “ – Distance starts and direction de-cision in according to the selected direction are available. The effect of this start-up condition can also be limited with the setting under “9944 AR TRIP undelayed“ – “first TRIP only“ instead of “all non-final TRIPS“. If “first TRIP only“ is selected, all starts following the first TRIP are treated as de-scribed in the start condition, subsection c). This means that all the further starts of the AR are effected by the zone timers expired within the operating time “9919 top2 from 2ndDeadTime“ incl. classification to the appropriate distance zone.

c) “homog. line Z1x,t1x“ – in addition to start and direction of the distance-dependent position of the fault in the overreach stage Z1x, t1x, i.e. after expiry of the time t1x. The overreach stage is only utilized on the first start. Afterwards, the overreach stage is no longer relevant for start. The second operating time“9919 top2 from 2ndDeadTime“ en-ables the user to select which distance zones authorize reclosing. All zones corresponding to the direction of Z1x,t1x whose timers are within this operating time may result in reclos-ing (mostly Z1,t1 and possibly Z2,t2). If this distance-related setting has been selected, Z1x will reasonably get impedance values

Functions


which realize overreaching over 100% line length (ZLine): Z1x=1.15⋅ZLine. For the second and the subsequent TRIPs, no overreaching is effected, as not Z1x but Z1 become effective as impedance zone. Thus, e.g., Z1 is set to Z1=0.85⋅ZLine. In Fig. 5.11-4 shows the successful operation of twice an AR. The position of the fault is once within zone Z1 (green, dark graph) and the other time in the range from Z1 to Z1x (yel-low, bright graph). Important:

When signal comparison is enabled, stage Z1x,t1x always remains active. Signal compari-son prevents non-selective overreach. This limits the AR range to the section to be pro-tected.

d) “inhomog. section 1“, “inhomog. section 2“ – – measured impedance must be in the overreach stage Z1x, t1x and in the overhead line section of an inhomogeneous line, consisting of cable and overhead line section (for further details, see sect. 5.11.1).

Important: • For an AR utilizing the overreach stage Z1x,t1x the timers t1 (“5111 t1 Time Zone Z1“) and

t1x (“5211 t1x Time Zone Z1x“) must be coordinated: If t1 ≥ t1x,AR will be started in case of a homogeneous line also by a fault involving Z< Z1 (preferred variant). If t1 < t1x is set, however, classification in Z1 results in a final TRIP without reclosing. Any further protection module generating the TRIP command before expiry of t1x prevents the AR start.

• If “5230 Signal Z1x,t1x“ is entered as “connected“ in the distance zone and if it is ac-tivated during a running AR cycle, it does not affect operation of the AR. In case a corre-sponding power system fault exists, a signal“5260 Z1x,t1x“ received prior to the AR cycle results in a final TRIP in Z1x, t1x without start of the AR.

Moreover, the AR can also be started by the following starts - to be enabled individually - of other protection modules, which is important for AR in case of emergency OTP:

e) Line starts of the overcurrent time protection “(Emerg.)OTP“ (“9931 IL> AR Start“, “9932 IL>> AR Start“ “9933 IL>>> AR Start“ “9934 IL>>>> AR Start“)

f) Earth current starts of the overcurrent time protection (“9935 IE> AR Start“, “9936 IE>> AR Start“ “9937 IE>>> AR Start“ “9938 IE>>>> AR Start“)

g) Negative sequence current stages (“9940 Ineg> AR Start“, “9941 Ineg>> AR Start“)

h) a detected earth fault, if a TRIP command is admissible to this effect (“9942 Earthfault AR Start“)

For these starts of other protection modules, two different start conditions of the AR can be selected:

1. “Pickup(+Direction)“ → TRIP commands of the first TRIP are effected without delay (exception: delayed by tUNE> in case of earth fault detection), in case of directed stages following detection of the direction set in the started stage. All the following non-final TRIP commands are handled in accordance with the setting “9944 AR TRIP undelayed“ – “first TRIP only“ or “all non-final TRIPS“. If “first TRIP only“ is selected, all the starts following the 1st TRIP will not result in AR starting until after the delayed TRIP command by the stage in being started (in analogy to the starting condition mentioned below under item 2.).

2. “Pickup+TRIP “ → TRIP commands are always delayed and possibly directed by the appropriate stage concerned. Thus, reclosing is graded in time.

Independently of internal starts of the protection device, a start

Functions


i) is possible by an external input signal “9960 AR External Start“. To this effect, the start must have been enabled by “9943 External AR Start“. → Special case: Reclosing is effected only once. The TRIP command (“9270 TRIP not final“) is undelayed, independent of start and di-rection, it is only executed if the AR is "ready". Reclosing is also only effected after valid-ity has been established. The TRIP command is used to start the reclaim time. The signal is not effective while AR is running, i.e. while the AR cycle is running.

! Important:

In case of an external AR start (and for the AR test), the duration of the TRIP command is determined by the set minimum operating time of the TRIP relay. It must be selected very carefully so that the relay is not overloaded once the tripping circuit opens (see also 5.20). In the disturbance record, without the delay, due to the minimum operating time, the general TRIP is only represented "active" for 1 ms.

Dead times and tests The type of the first pause is adjustable (“9945 First Dead Time(tD)“): • Short dead time, dead time for rapid reclose (tDshort - short-time interruption) • long dead time (tDlong - delayed reclose). All the following dead times are long dead times (tDlong).

Fig. 5.11-3 Tests before reclosing after the short dead time (delayed reclose analogously)

Prior to a reclose, existence of the input signal"9963 CB ready" (“9946 CB ready at tDshort“, “9947 CB ready at tDlong“) can be tested on request in addition to the inte-grated validity tests

• no general start, • no TRIP command, • no blockage, • no running AR blocking time and • in case of enabled CB position test “9949 CB Pos for AR ready“ both position indica-

tions “Off” and not “On” have to exist. If the test result is negative, reclosing is omitted, RE is terminated and the blocking time is acti-vated.

A circuit breaker failure (CBF protection enabled) leads to a blocking of reclosing and ends the AR Cycle by a furthermore existing TRIP command and the started AR blocking time.

9963 CB ready

Gen TRIP

GS

&

9980 Close by AR 9915 tb Blocking Time AR

AR enabled

&

D...6

462 CB Position Off

461 CB Position On & 9949 CB pos for AR ready

consider

H 9946 CB ready at tDshort

necessary

CB Close

Functions


Z1x,t1x

Operative times AR

9270 TRIP not final

9912 Dead time d 9911 Dead time r

Zx,tx

9980 CLOSE by AR

Reclaimtime AR

9970AR-Cycle

9971AR ready

Z2,t2

Homogenous line Z1x,t1x, successful AR at second time

Start

9919 top2

9280 TRIP final

9963CB ready

Z1,t1

9916 tr

top: error in overreaching area (>Z1) down: error in Z1

t2

t1x

9917 tcl

9912 Dead time d

t1x

t1 t1

9914 top1

9917 tcl

9916 tr

9916 tr

9917 tcl

each zone, if time pass within operative time top2

Fig. 5.11-4 Examples for a successful AR procedure

The characteristic of the input signal “9963 CB ready“ from the circuit-breaker shown in Fig. 5.11-4 is shown here only to demonstrate its effect on the AR ready signal. In most other cases, a different signal characteristic will occur in reality. Explanation of important settings

Operating time “9914 top1Time1st DeadTime“ “9919 top2 from 2ndDeadTime“: Within the AR operating time, the starting and the TRIP command must be omitted after a TRIP command. Otherwise, the AR is blocked. The operation time is started by the start of the stages permitted for AR starting. It must be longer than the total time consisting of command time (incl. zone timer up to which RC is to be admitted), circuit-breaker time (including arc quenching) and the release time of the general start.

Dead times “9911 Dead Time rapid Recl“ “9912 Dead Time delayed R.“: The dead time is started with detection of start reset after TRIP. The de-energized dead time, properly speaking, depends on the remote station - in extreme cases, the opposite side does not start before this side has been switched off. This fact must be taken into consideration when selecting the dead time. For short-time interruption, a de-energized pause of 0.3...0.5 s is normally required for de-ionization.

Duration of CB CLOSE command by AR “9917 tcl Duration CBCLOSE“: This setting value is provided to adjust the CLOSE command duration by the protector in ac-cordance with specific circuit breaker conditions. When a general start is detected, the CLOSE command is cancelled immediately. The preset minimum operating time for the selected ON relay acts in parallel. Realization might also be effected over this time, however, with the drawback that the minimum operat-ing time is not cancelled by a start.

Functions


Important: The duration of the CLOSE command must be selected very carefully, so as to prevent the relay from being overloading on opening the CLOSE circuit.

Blocking time after Manual Close “9905 tblockAR CBC CB Close“ Start of this timer module is communicated via the CB manual CLOSE signal either on the binary input “460 CB closed manually“ or internally by the substation control system (“51638 CB Close from SCADA“). An AR is blocked during its operation time.

Reclaim time “9916 tr Reclaim Time AR“: The reclaim time is starts with the end of the dead time, when the “9980 CLOSE by AR“ command is given. At the same time, the counter of allowed number of reclosings still al-lowed is decremented by 1. When the counter is greater than 0, the reclaim time may be cancelled by a TRIP command. In this case, the next reclosing attempt is started within the AR cycle. At counter reading 0 the reclaim time runs till its end independently of a TRIP command, thus terminating the AR cycle. During the running reclaim time, no new AR cycle can be started. This is to provide the cir-cuit-breaker with the required "regeneration time" and prevent unfavourable effects on the power system.

Blocking time of AR “9915 tb Blocking Time AR“: If a blocking time is running, AR is prevented. The blocking time is started if - after a non-final TRIP command, the start is not reset within the operating time or a starting comes within the dead time, - the test of reclosure permission produces a negative result, - any other protection module generates a TRIP, - the TRIP command is issued by the input signal "9960 AR External Start", - an internal circuit breaker failure is detected.

Manual closing of the line On closing (which can be recognized by the active close signal edge “460 CB closed manu-ally“) following a short-circuit, the AR is not to operate on closing. Thus, it is blocked for the duration of expiry of the timer module “9905 tblockAR CBC CB Close“ (the output command pertaining to this timer “9979 tblockAR CBC runs“ signals expiry). As basic condition for this task, the setting which has been selected on delivery “430 Sig. CB Manual Close“ “available“ in “Equipment Adaptation / CB Adaptation“ must be unchanged. The physical CB Manual CLOSE signal can be communicated in two ways:

• CB CLOSE signal communicated internally by the substation control part (“51638 CB Close from SCADA“) Note:

This signal can only be activated by the CB with the smallest node number (e.g. Q0 01.-01) in the control system setting.

Or / and • input signal “460 CB closed manually“.

In case of direct connection to the CLOSE coil of the switch, the input signal“460 CB closed manually“ can also signal closing operations that are not routed via the control module of the DDx 6. An active input “460 CB closed manually“ during an AR cycle is not weighted as Manual Close signal. AR and teleprotection system The AR is capable of cooperating with the protection module ”Teleprotection“. This serves to enhance selectivity and, if possible, reduction of the trip times. The cooperation AR / signal com-parison means that the non-final TRIP commands generated by AR are tripped using signal com-parison. Only if the AR starting condition “homog. line Z1x,t1x“ is used, cooperation can be realized. This also concerns cases in which change-over to this starting condition is effected after the first

Functions


TRIP command (utilization of the starting condition “if Distance Start“ or “Dist.Start+forward“ and “9944 AR TRIP undelayed“ set to “first TRIP only“).

There is additionally the special case of the switched-off distance protection whereas the direc-tion is used in the current starts, together with the starting condition “Pickup+TRIP“ in which signal comparison can be used. Here, there are also cases in which the change-over to this start-ing condition is effected after the first TRIP command (“Pickup(+Direction)“ and “9944 AR TRIP undelayed“ set to “first TRIP only“).

Final TRIP is of course subject to the treatment by the enabled teleprotection. Important:

− For the AR, the input signal “9963 CB ready“ and the output relays (command outputs) for the “9280 TRIP final“, “9270 TRIP not final“ and “9980 CLOSE by AR“ are man-datorily required.

− The input signal “460 CB closed manually“ or its transmission from the control section of the DDx 6 “51638 CB Close from SCADA“ is an important signal to prevent AR during closing.

− Unwanted switchings on and thus dangerous conditions can be avoided by use of the posi-tion indications of the circuit breaker at the inputs “461 CB Position On“ and “462 CB Position Off“.

− The operating and reclaim times must always be set longer than the set maximum DDx 6 tripping time relevant for AR.

− If AR and the signal comparison method (except "blocking overreach protection") are en-abled, identical start and transmit conditions must be set for both protective functions.

− When starting-up the AR with an external signal, the minimum operating time selected for the duration of the TRIP command is decisive for the "survival" of the command relay.

Setting: 1. The intended connection of the signals CB ready “432 Signal CB ready“ and, unless al-

ready covered under the close protection, of the “430 Sig. CB Manual Close“ must be notified in the menu “Setting Set / Setting / Setting Values / Equipment Adaptation / CB Ad-aptation“ of the command relay.

2. Enabling or the preparation of the AR, the envisaged connection of a blockage signal, the use of CB position indicators, enabling the starting authorizations and the appropriate start-ing condition, assignment of the non-final TRIP regarding non-delayed tripping, the type of the 1st dead time and setting of the timer modules can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Auto-Reclose (AR)“.

3. The command "AR On/Off“ for the substation control system is enabled in the menu “Set-ting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“.

4. If “CB closed manually“ is received from the substation control, its utilization must be con-firmed under “Setting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“ “51638 CB Close from SCADA“ by “yes“. If the “460 CB closed manually“ signal reaches the device via an optocoupler and the CB position indications will be used, the re-quired optocoupler inputs must be assigned under “Setting Set / Setting / Inputs / Equipment Adaptation / CB Adaptation“.

5. For “9963 CB ready“, the connections of the AR close or trip buttons and - in case of an intended external AR start or blockage - the optocoupler input in question must be config-ured under “Setting Set / Setting / Inputs / Protection Modules / Auto-Reclose (AR)“.

6. For the outputs to relays, the required minimum operating times must be selected under “Setting Set / Setting / Setting Values / General / Relays“.

7. The outputs to relays are configured under “Setting Set / Setting / Relays / Protection Mod-ules / Auto-Reclose (AR)“.

8. The outputs to LED are to be selected under “Setting Set / Setting / LED / Protection Mod-ules / Auto-Reclose (AR)“.

Functions


9. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Auto-Reclose (AR)“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

5.11.1 AR on inhomogeneous line An inhomogeneous line consists of a cable section and an overhead line section. Besides usual AR on a homogeneous line, the distance protection features AR for the overhead line section of an inhomogeneous line. Cable runs should not be provided with AR. Selective AR in the event of a fault in the overhead line section is possible if the overhead line section is precisely defined by: • the section in which the AR is to be effected “9948 Distance AR Start“ “inhomog.

section 1“ or “inhomog. section 2“, • reactance of the first section (X1x⋅f) with the division factor f “9918 Section Factor

f*X1xs“ (<1) of the line and • the total reactance of both sections (“5201 X1xs*In/A Reactance“). Fault location is effected by measurement of the impedance. If the fault is in the cable section, no AR will take place, but the section will be switched off only. If located in the overhead line section, this section will be subjected to AR. For this case of application, the measurement in forward direction (Z1x) is assumed. Fig. 5.11-5 shows the settings of protectors A and B for AR on an inhomogeneous line. In this example, the overhead line is the 2nd section of protector A and the 1st of protector B.

Fig. 5.11-5 AR on inhomogeneous line

General remarks: • AR in the 1st section (1st section is the overhead line):

The "TRIP not final" is requested if X < X1x⋅f and Z < Z1x are valid. If only Z < Z1x applies, a final TRIP is effected within the time t1x. For the final TRIP following an unsuccessful AR cycle Z < Z1 within t1 applies. Z1x is to be set preferably - as Z1 - to underreach (e.g. Z1x=Z1=0.85⋅Z1st+2nd section).

• AR in the 2nd section (2nd section is the overhead line): The first "TRIP not final" is requested X > X1x⋅f and Z < Z1x are valid. If only X < X1x⋅f ap-plies, a final TRIP is effected within the time t1x. For other non-final TRIPs and the final TRIP following an unsuccessful AR cycle Z < Z1 within t1 applies. Z1x is to be set preferably to overreach and Z1 to underreach (e.g. Z1x=1.15⋅Z1st+2nd section and Z1=0.85⋅Z1st+2nd section).

A B

(Z1)A (Z1x)A

(Z1)B (Z1x)B

(Z2)A

(Z2)B

Cable Overhead line

(f⋅X1x)A

(f⋅X1x)B

(t1x ≤ t1)A

(t1x ≤ t1)B

(t2)A

(t2)B

After first Recl.Lockout or final TRIP after unsuccessful AR

Functions


jX

R

forward

X

RLL

Z1x

RLE

f⋅X

Fig. 5.11-6 AR on inhomogeneous line - section factor f

When the “9918 Section Factor f*X1xs“ is set, it must be taken into consideration that it mostly refers to an overreaching or even underreaching impedance zone Z1x, e.g. X1x=1.15⋅XLine. On the other hand, the section factor f for 100% of the line length is known, e.g. 0.5. The “9918 Section Factor f*X1xs“ to be set is inversely proportional and amounts to 0.5/1.15=0.43. General:

offf %100= 5-29: Section Factor f

with: f “9918 Section Factor f*X1xs“ fo overreach/underreach factor referred to 100% length of line XLtg f100% section factor for 100% length of line The combination of AR on inhomogeneous line with a signal comparison procedure is admissible and makes sense. Thus, all TRIP commands for 100% line length are realized by overreaching the stage Z1x in case a positive signal comparison result has been realized within the time t1x. If an AR takes place in the first section, Z1x is used as overreach stage for the entire line length in this case (setting e.g. Z1x=1.15⋅Z1st+2nd section and Z1=0.85⋅Z1st+2nd section). Setting: in addition to the settings of the previous section: 1. The enable of the distance zones Z1,t1; Z1x,t1x (with their secondary reactance X1x) and the

other impedance zone settings can be found in the menu ”Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Distance Module“.

2. Selection of the line section where AR is to be effected and setting of the section factor f (referred to X1x) are made under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Auto-Reclose (AR)“.

5.11.2 Signalling the circuit-breaker tripping Transfer of a "Breaker tripped" signal generated by a fleeting contact of the circuit breaker during breaker tripping can be suppressed by the protector during an AR cycle. To this effect, the NC contact of a relay configured with the output command “9973 AR In-truptTrip.Sig“ (interruption of trip signal) must be looped in the signalling circuit. Access to this output command requires that the use of “433 CB Tripped Signal“ has been communi-cated in the setting menu of “Equipment Adaptation“ under “CB Adaptation“. During output of the TRIP command, the NC contact is open, so that the circuit-breaker tripping signal is not passed through. Contact opening is initiated by the TRIP command of the protection device and ends with the reset of the TRIP command. Any required extensions of the break time can be realized via the minimum operating time of the cut-off relay used. There is a signalling problem if a non-final TRIP command has not been signalled as required, but it turns out subsequently that the intended reclosing cannot be effected. In this case, a non-final

Functions


TRIP command which has been realized is "converted" subsequently into a final TRIP, which should also be signalled externally. This may be due to:

• external blockage during the dead time • WE inadmissible, as CB not ready.

To this effect, the breaker trip signal is simulated. The output command “9974 CBTRIPSignal later“ generates a very short fleeting pulse which can be used upon extension to signal subse-quently breaker tripping. The make contact of the relay to which this command is assigned can, for example, be connected to a contact output of the break relay for interruption of the breaker tripped signal. To determine the duration of the fleeting pulse of the relay to which the output command “9974 CBTRIPSignal later“ is assigned, its minimum operating time “322xx Oper. Time ...“ must be used. Setting: 1. The fact that the breaker trip signal interruption option is used must be communicated in the

menu “Setting Set / Setting / Setting Values / Equipment Adaptation / CB Adaptation“ by choosing “connected“.

2. The relay pertaining to the interruption and the relay for the subsequent breaker trip signal must be selected subsequently under “Setting Set / Setting / Relays / Protection Modules / Auto-Reclose (AR)“.

3. The mandatory selection of the fleeting contact time for the subsequent breaker trip signal must be effected via the operating time under “Setting Set / Setting / Setting Values / Gen-eral / Relays“ for the relay used. Any required breaker trip interruption can be extended in the same way.

Functions


5.12 Teleprotection method (TP) Through the application of a signal transfer between protection devices, it is possible to switch off faults in the entire area of the protected section with the shortest possible time. Seven basic teleprotection versions may be selected: • Reverse interlock, also in terms of H2 logic • Two-wire connection to remote station (signal comparison method) • Unidirectional operation • Permissive overreach protection (POP - signal comparison method) • Blocking overreach protection (BOP - signal comparison method) • Permissive underreach protection (PUP - signal comparison method) in two ways:

- PUP together with a correct direction at the other end - accelerated underreach protection (AUP). Receipt of signal at the other end starts measur-

ing by overreach zone Z1x,t1x. Additionally, • intertripping for weak fields at no existing general start may be used for the signal comparison methods. The required method is selected via the setting “19030 Mode Teleprotection“. Special case: All direction decisions (and thus distance protection) are switched OFF. In case of the switched-off direction decisions, the teleprotection mode cannot be selected any longer. If teleprotection is enabled, the function “Reverse interlock“ will be effective (see 5.12.2.1). To start the function, it is enough if a start arrives through IL or IE. The “Unidirectional operation“, “Permissive overreach protection“ “Blocking overreach protec-tion“ and “Permissive underreach protection” are provided for use with teleprotection facilities. The methods “Reverse interlock“ and “Two-wire connection“ use wire connections. The various teleprotection methods are explained in more detail in specific sections.

• The starting conditions required for teleprotection, i.e. • start (IL> and upon enabling IE or earth fault), • direction decision or • measured impedance

are provided by the modules • distance protection (5.5), • (emergency) overcurrent time protection (5.6), • earth short-circuit direction (5.4.3), • TRIP at earth fault with (5.7)

o exceeding the set power (no direction) or o earth fault direction in the isolated system

These protection modules are relevant for teleprotection. The cooperation with AR is stipulated as follows:

• In the case of the final TRIP command by the AR, teleprotection is effective. • In case of selection in the AR of “9944 AR TRIP undelayed“ “first TRIP only“, all

delayed TRIP are affected. • This also applies to all TRIP commands when the AR start-up condition "Pickup+TRIP“ is

selected. • All the non-delayed, non-final TRIPs in case of the start-up condition

“Pickup(+Direction)“ remain unaffected. In a nutshell: all the delayed OFF commands can be coupled with signal comparison.

The "teleprotection" module can be switched on and off, like any other module, additionally via • the substation control command "TP On/Off“, if it has been permitted in the substation

control group: “51633 Cmd TP On/Off“. • one optocoupler input each “19063 TP ON-Pushbutton“ and “19064 TP OFF-

Pushbutton“. At the same time, it must be ensured that an active signal is never applied to both inputs simultaneously.

Functions


Hint: • Switching on or off operations act like a reparameterization of the protection device (many

settings are added or eliminated) incl. the non-volatile storage of the new state. No protec-tion modules are performed within a period of <200 ms.

• TP switching on or off is effected more quickly via a replacement of the characteristic set per optocoupler or using the TP blockage input, as the state need not be saved in the setting set.

Due to the external enable options, there is a specific feature to the protection module "telepro-tection system". It can be "disabled“, "enabled“ and additionally "prepared“. The last-mentioned state enables processing and viewing all settings in case that it is not enabled = acti-vated = effective at present. The output command “19090 Teleprot. FctOn“ is available for the feedback of the enabled state.

The selected teleprotection method may be blocked by means of a binary input. To this effect, the input signal "19099 Blockage TP" must be used after its intended use has been communi-cated via "19098 Blockage TP" “connected“. A fault signal arriving from the teleprotection facility must be connected to the input “19065 TP Connect.disturbed“ for blocking the signal comparison function.

Fig. 5.12-1 Teleprotection – CLOSE / TRIP / Blockage / Generation of the signal "TP ready“

Setting: 1. Enabling or preparation of TP, the intended connection of a blockage signal, approval of the

intended earth short-circuit direction as start condition, selection of the teleprotection mode, selection of the transmit and receive conditions, enabling the intertripping without an existing start function and setting the operating and TRIP delay times can be realized under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Teleprotection“.

2. The command “51633 Cmd TP On/Off“ for the substation control system is enabled in the menu “Setting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“.

3. Connections of the TP Close or Trip button (“19063 TP ON-Pushbutton“, “19064 TP OFF-Pushbutton”), the important teleprotection inputs “19060 TP Signal Input“, “19062 H2:Subst.BlockSignal“, “19065 TP Connect.disturbed“ and any blockage

19099 Blockage TP

H &

19098 Blockage TP

&

19090 Teleprot. FctOn

19063 TP ON-Pushbutton

19064 TP OFF-Pushbutton &

&

19099 Blockage TP

&

TP ready

1

1

&

&

51633 Cmd TP On/Off

H enabled

TP On

TP Off

D... 6

Saving, initializing of setting set

19000 Teleprotection

enabled

prepared

disabled

H H L

H L L

S

R

connected

19065 TP Connect.desturbed

19073 TP Connect.desturbed

Functions


input required“19099 Blockage TP“ must be configured under “Setting Set / Setting / In-puts / Protection Modules / Teleprotection“. Here, any required negation of the physical input signals can be entered.

4. Thus, any required extension of the release time of the receive signal “19060 TP Signal Input“ can be realized via the physical binary input to which it is assigned under „Setting Set / Setting / Setting Values / General / Optocoupler“.

5. The important output commands to relays “19071 TP Send Signal“, “19073 TP Connect.disturbed“ and other required signals must be assigned to the relays under “Setting Set / Setting / Relays / Protection Modules / Teleprotection“. Here, the output commands used can also be negated.

6. Any extension required of the minimum operating time of the transmit relay, assigned with the output command “19071 TP Send Signal“, is possible under “Setting Set / Setting / Setting Values / General / Relays“.

7. Outputs to LED are to be selected under “Setting Set / Setting / LED / Protection Modules / Teleprotection“.

8. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Teleprotection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.12.1 Two-wire connection (three-wire connection) This function is preferably used in meshed networks featuring small distances between stations. In case of fault in the protected line section between two protectors, the function "Two-wire connection" allows for a rapid OFF on both sides. Connection

Transmit relay

Protection A

L+ L-

Input

Transmit relay

Protection B

Input

K1 K2

L+ L- Fig. 5.12-2 Two-wire connection via relays for standard inputs

Transmit relay

Protection A L+ L-

Input

Transmitrelay

Protection B

Input

R

Fig. 5.12-3 Two-wire connection, parallel circuit for low loop voltages

Transmit relay

Protection A L+ L-

Input

Transmitrelay

Protection B

Input

Fig. 5.12-4 Three-wire connection

In this context, the protection relay of one line is connected to the remote station relay through a signal loop supplied from the battery voltage of one station. Due to the non-linear inputs being used as standard in the DDx 6, realization of the signal connection in accordance with Fig. 5.12-4 or Fig. 5.12-2 is used. In the case of minor loop voltages up to max 60 V DC, the solu-tion shown in Fig. 5.12-3 can be used. It has the advantage, versus Fig. 5.12-4, of saving one phase.

Functions


The circuit in acc. with Fig. 5.12-2 requires on each side of the protection relay a reliable trip re-lay which acts as quickly as possible (e.g. RH32 of EAW Relaistechnik GmbH), which is series-connected with the contacts of the protection relay. The relay contacts apply supply voltage to the binary input if current is flowing through the coils. In case of short-circuit between the two relays, the relay of the supply side gets up to twice the voltage. If necessary, a suitable PTC re-sistor might switch off the loop current of double the intensity.

The circuit in acc. with Fig. 5.12-3 only requires an external resistor R which can be dimensioned as follows in accordance with the loop voltage range Umin and Umax used:

max

minmax 2 I

UUR BE

⋅−

= , R

UP ²maxmin =

UDI is the required change-over voltage of the optocoupler input which depends on the equipment variant. Imax is the maximum current flowing into the input – for universal-voltage inputs 0.04A (see 3.3). To ensure a long service life of the resistor, it should be overdimensioned regarding power. Short-circuit of the current loop between the two relays has not a destructive effect.

The last circuit variant is shown in Fig. 5.12-4 In the three-wire connection, high reliability is en-sured as no external components are used; it can be applied to all loop voltages corresponding to the inputs. A short-circuit of the wire connection between the relays has a destructive effect; the d.c. supply must be fused. Important:

In the case of wire connections between stations, the high adjacent current intensities may result in inducted voltages (e.g. in case of an earth short-circuit fault). These must not reach the test voltage of the device inputs and outputs. Thus, the length of the connection is lim-ited.

Method of operation: For each protection device, an internal transmit relay (NO contact for series-connection in acc. with Fig. 5.12-2 and, in case of a three-wire connection, Fig. 5.12-4, NC contact for parallel connection in acc. with Fig. 5.12-3), configured with “19071 TP Send Signal“ and the opto-coupler input “19060 TP Signal Input“, are required. The signal loop between the two protection relays is normally closed when the protection relays are "ready" (closed-current loop principle). The NO contacts in Fig. 5.12-2 and Fig. 5.12-4 are closed, the NC contacts in Fig. 5.12-3 are open. The inputs receive a signal. Any interruption of the loop current exceeding 15 s is indicated as fault to the teleprotection.

In case of starting through • Z<, (U-) I or IL> (emergency) OTP/IDMT) starting or • if “19035 Start TP with EF/IE“ is enabled: additionally also in case of IE> (emer-

gency) OTP/IDMT) starts (except IEint) or in case of earth fault, if “7030 TRIP at Earthfault“ has been enabled,

the transmit relay interrupts the signal for the inputs, while the operating time “19014 topTP Operating Time“, abbreviated topTP, is started. The signal for the inputs is reenabled through the transmit relay, a) if the preset transmit condition (“19032 Transmiss. Condition“) occurs while a start is

present, this may be • the position of the fault within the distance stage “Z < Z1x,t1x“, after expiry of the

time “5211 t1x Time Zone Z1x“ or • - undelayed - the required direction, or

b) if starting is reset.

Functions


Fig. 5.12-5 Active principle two-wire connection

To distinguish between the two causes of the signal reoccurring at the inputs, the operating time topTP is used. It should be set such that a) is within the time and b) outside, due to the grading time. The re-occurred signal at the inputs within topTP during continued starting will cause the TRIP command to occur. In other words: The supply of the binary inputs - interrupted on starting - is re-established when the direction decisions or the distance decision Z<Z1x,t1x (after t1x) are made within the operating time, and a TRIP command is issued immediately afterwards by each protection device to the appropriate circuit-breaker. The faulty line section is thus separated rapidly and selectively from the grid bypassing the grading times. In case of any other fault within the system, the signal loop remains interrupted during the oper-ating time by some contact or other, as in this case the enable conditions (starting and Z<Z1x,t1x or direction decision in the selected direction) are not available. In such case, the circuit-breakers are tripped after the specified grading times. If the start is reset before the transmit condition occurs, no TRIP command is generated even if the signal loop is not interrupted.

forward

19071 TP send signal

1 &

&

19035 Start with EF/IE

≥119032 Transmiss. Condition

EF forward

ESC forward

ESC reverse

EF reverse

≥1

SC forward

≥1

≥1

Z < Z1x, t1x

reverse

SC reverse

IL-Start

Earthfault+TRIP

IE-Start

≥1≥1

(U-)I-Start

Z<-Start

19073 TP connect.disturbed&

19011 tTRIP

GenTRIP H

&

enabled

19034 Intertrippg no Start

19060 TP signal input

&

19072 TP signal received

19060 TP signal input

1

19014 topTP

&

DDx 6

D R

D R

H & t = 15 s & &

TP ready

Functions


To enhance safety, a TRIP delay time has been integrated. Thus, for example, a fault which has been tripped very quickly in the adjacent section (within the topTP), which also generated starts in both protection devices, must not cause tripping due to the loop being closed due to start reset. This is effected by an adjustable "TRIP delay" timer module. If a TRIP command is to be issued due to closing of the loop while a start is still present within topTP, a check is made after expiry of the TRIP delay as to whether the conditions for the TRIP command are still fulfilled (exception: topTP is no longer checked). If this is true, TRIP is requested, This is also helpful in case of parallel lines with double-sided supply if the fault is not switched off simultaneously on both sides of the parallel line. Here, the change of direction may briefly result in faulty signals, which can be sup-pressed via the TRIP delay. When "Intertripping at no start” is also set (refer to 5.12.6), the TRIP command may be issued even if no starting is present but the duration of loop interruption is shorter than topTP. Important:

In case of "intertripping at no start ", any short-time opening of the signal loop results in a TRIP command. While the loop is started up, intertripping is to be blocked in order to prevent TRIP by switching operations.

Remarks:

− The operating time topTP must be set at least long enough to ensure that the slowest protec-tor has a chance of determining its set transmit condition, To this effect, the zone timer t1x “5211 t1x Time Zone Z1x“ be set to a value of 0 or at least < topTP if the transmit condi-tion “Z < Z1x,t1x“ is used. The time “5111 t1 Time Zone Z1“ of a distance stage Z1,t1 operating in parallel muss must be set to ≥, in order still to be able to generate the transmit signal for the remote station.

− If the transmit condition “Z < Z1x,t1x“ is used, it should operate in directional mode. − The output command “19073 TP Connect.disturbed“ should be used as alarm of the

two-wire connection. If only one side signals a disturbance in the connection, this may be due to a short-circuit in the connecting cable.

− Normally, the forward direction is to be chosen as transmit condition. − The determined earth fault direction or - in the earthed system - the earth short-circuit fault

direction - can be used as transmit condition after appropriate enable of “19035 Start TP with EF/IE“ in addition to the short-circuit direction. The use of the earth fault direction requires that the “7030 TRIP at Earthfault“ is enabled additionally, otherwise, the earth fault direction detection is not authorized to perform starting.

− If AR and signal comparison are enabled, identical start and transmit conditions need to be set for both protection modules.

− Starting of the intermittent earth short-circuit fault condition does not start the two-wire connection.

Functions


5.12.2 Reverse interlock function and H2 logic

5.12.2.1 Reverse interlocking This teleprotection function is used most frequently in the busbar area. Distance protection is ahead of the busbar. In the outgoing feeders, additional protection devices are located which are connected to it via the signal input “19060 TP Signal Input“ (Fig. 5.12-6). The signal input is activated by a feeder protection if it detects the fault in its section to be protected. Mostly, the starting signal is sufficient to this effect. The objective is that in the case of a fault on an outgoing feeder, the distance protector ahead of the busbar should trip within a longer grading time than the outgoing feeder protector, but in case of fault in the busbar it should trip within a shortest possible time. This principle also enables utilization in one vector with a short distance from the station. The blockage can be communicated to the protector mounted upstream. Connection:

L- L+

feeder2

feeder3

Outgoing feeder1

Starting relays (in the feeders)

1

2

3

a)

DDx 6 Input: “19060 TP: Signal Input“

L+

feeder2

feeder3

Outgoing feeder1

DDx 6 Input: “19060 TP: Signal Input“ negated

Starting relays(in the feeders)

1

2

3

L- R

b)

L+

feeder 2

feeder 3

Outgoing feeder1

Starting relays(in the feeders)

1

2

3

L-

c)

DDx 6 Input: “19060 TP: Signal Input“ negated

Fig. 5.12-6 Connection principles ”reverse interlock”

The advantage of the closed current loop variants b) and c) shown in Fig. 5.12-6 is that they provide for continuous monitoring of the wire loop. The effect of the signal input “19060 TP Signal Input“ must be negated here, i.e. the active signal is interruption of the current flow. In the case of lower supply voltages, variant b) can be used. To determine the resistance for the standard conditions of DDx 6, the following shall apply:

max

minmax I

UUR BE−= ,

RUP ²max

min =

UDI is the required change-over voltage of the optocoupler input which depends on the equipment variant. Imax is the maximum current flowing into the input – for universal-voltage inputs 0.04A (see 3.3). The resistors in the supply lines and the resistor R which is being used must not ex-ceed the maximum value Rmax.

Variant c) requires NC contacts or NO contacts activated in closed-current loop mode for the starting signal. Activation of the NO contacts can be realized in case of devices of the D...6 se-ries by negation of the activating output command. Both variants are compared in the following Table. Problem Break (NC) contact Activated make (NO) contact Failure of an outgoing feeder device

Interlock operates correctly, except of this outgoing feeder. In case of fault on this outgoing feeder or additional instan-taneous tripping

Loop has permanently active signal; causes deactivation and reverse interlock, and the signal "TP connection disturbed"

Functions


Method of operation:

Fig. 5.12-7 Active principle “reverse interlock”

Normally, no active input signal is present at the input “19060 TP Signal Input“. After rec-ognition of the selected condition (“19031 Start topTP if“), the distance protection starts the operating time topTP (“19014 topTP Operating Time“). Conditions that can be set for the start of topTP are: • upon availability of the direction decision during general start as setting which is preferable in

most cases - forward or - reverse.

• or coming of a distance start ((U-)I start or Z<) or a phase current start IL if the (emergency) overcurrent time protection.

Additionally, the operating time can be started by single-pole earth faults after enabling “19035 Start TP with EF/IE“ i.e. depending on the method of neutral connection

• earth fault or additionally correct earth fault direction in non-earthed systems, or • starting of IE only or additionally correct earth fault direction within the earthed system.

To this effect, the earth fault or earth fault direction detection in non-earthed systems must have been enabled by the “7030 TRIP at Earthfault“ (in the protection module "Earth fault de-tection“), i.e. be capable of authorizing general starts. When the action time has expired, a final TRIP command is issued provided that no signal from an outgoing line feeder protector has arrived (i.e., the latter has not detected starting or forward direction). On the other hand, if a signal arrives during the operating time, it will be assumed that the faulty outgoing feeder switches off within a shorter time. In this case, the function "Reverse interlock-ing" of the distance protection would activate TRIP with expiry of the appropriate grading time if the start remains present.

19014 topTP

GenTRIP

19060 TP Signal Input &

&&

IL-start

Earthflt+TRIP

IE-start

≥1 ≥1

19035 StartTP with EF/IE

SC forward

EF forward

ESC forward

≥1 ≥1

SC reverse

EF reverse

ESC reverse

≥1 ≥1

19031 Start topTP if Start Z, IL, (EF/IE)

forward

reverse

t = 15 s 19073 TP Connect. disturbed

19072 TP Signal received

19060 TP Signal Input

&

(U-)I-start

Z<-start

TP ready

DDx 6

&

Functions


If the start signal is present at the “19060 TP Signal Input“ for more than 15 s, this is sig-nalled by the output command “19073 TP Connect.disturbed“. The rapid tripping with Z1, t1 can operate in parallel to the reverse interlock, which does not in-clude normally the range between Z1 and 100% (the overreach zone Z1x, t1x is not activated). Reverse interlocking secures rapid tripping on faults within the entire 100% range. If Z1 cannot be set safely within the 100% range due to an insufficient impedance (line imped-ance too low), the time(“5111 t1 Time Zone Z1“) can be used for backup grading. Important: • The "Reverse interlock" function may only be implemented in the DDx 6 within the busbar

area. • The setting “19031 Start topTP if“ to “Start Z, IL,(EF/IE)“ should only be se-

lected if no starts can be created which are not located in the busbar direction. Otherwise, in case of faults, tripping after the operating time in the busbar direction need not be ex-pected.

• The duration of the operating time topTP must be set sufficiently long so that the slowest pro-tector will be capable of detecting its starting condition.

• The zone time stages as of Z2,t2 have to be set longer than the time stages of the starts of the protectors in the outgoing feeders (backup protection).

• In the case of wire connections between stations, the high adjacent current intensities may result in inducted voltages (e.g. in case of an earth short-circuit fault). These must not reach the test voltage of the device inputs and outputs. Thus, the length of the connection is lim-ited.

Remarks: • Starting of the intermittent earth short-circuit fault condition does not start the reverse inter-

locking. • In the case of a fault in the voltage path, direction determination is blocked. Thus, a start

condition of the reverse interlock based on it cannot be satisfied.

Functions


5.12.2.2 H2 - Logic In the case of a fault in the voltage path, direction determination is blocked. Thus, a start condi-tion of the reverse interlock based on it cannot be satisfied“19030 Mode Teleprotection“ with “Rev.interl. / H2 logic“. This protection module requires normally two teleprotection inputs which must be configured as "negating" for the recommended closed current loop: 1. “19060 TP Signal Input“. It is connected to the protector of the opposite station. 2. “19062 H2:Subst.BlockSignal“. It is connected to the input of the station blockage bus

of its own station.

The directed protection devices, signal relay outputs with one contact each for 1. the forward direction “1971 Short Circ.forward“ and, if the TRIP command of the earth

short-circuit direction protection or the earth fault direction protection is enabled (makes only sense in isolated-neutral systems), also “2971 Earth-SC forward“ or “7071 EarthFlt. forw.“ and

2. the reverse direction “1972 Short Circ.reverse“ and, if the TRIP command of the earth short-circuit direction protection or the earth fault direction protection is enabled (isolated-neutral systems), also “2972 Earth-SC reverse“ or “7072 EarthFlt. rev.“ (isolated-neutral systems)

are required as undelayed signals. 3. with logic "OR“ gate, the output commands “51280 Malfunction“ and “18280 U Path

disturbed“ must be routed to the relay to which the forward direction has been assigned under 1. Thus, a blocking signal on the station bus is created in case of a device disturbance or a fault in the voltage path.

4. with logic "OR“ gate, the output commands “51280 Malfunction“ and “18280 U Path disturbed“ must be routed to the relay to which the reverse direction has been assigned under 2. Thus, a blocking signal on the station bus is created in case of a device disturbance or a fault in the voltage path.

5. In addition, the output commands “18280 U Path disturbed“, “19073 TP Con-nect.disturbed“ and “19074 StationBus disturb.“ should be retransmitted as mes-sages to the substation control.

As setting value, the instantaneous zone “19014 topTP Operating Time“ must be specified which becomes effective as trip time if there is no blocking signal. Important:

The distance protection stages with forward or reverse direction (or those of the "IL> (Emerg.)OTP“ in case of switched-off distance stage) and - if used - those of the zero power or earth fault direction decision are used for backup grading.

5.12.2.2.1 Method of action of the H2 logic The fundamental method of operation is based on the output of blocking signals to all relays which are not placed at the fault location. The relays which do not receive a blocking signal from other protection equipment switch off in the basic time ("19014 topTP Operating Time"). The grading times of the directed overcurrent time protectors graded within the ring act in terms of redundancy as backup protection times.

In Fig. 5.12-8 a system section is displayed with the stations A, B, C and D. Station B is shown in more detail with several outgoing feeders. As protection relay, directed overcurrent time pro-tection is used for the circuit-breakers 1...6 (distance or overcurrent time protection) and undi-rected overcurrent time protection of the circuit-breakers 7 and 8. The protection opposite relays 1 - 2 and 3 - 4, as well as 5 - 6 have a connection of their signal relay contact for the detected reverse direction with the input “19060 TP Signal Input“. The station blocking bus receives blocking signals from the signal relay contacts for the forward direction of the overcurrent directional relays and from the starting signal contacts of the OTP (7,

Functions


8) in the outgoing feeders. The signal of the station blocking bus is evaluated on the input “19062 H2:Subst.BlockSignal“ of the directed protection devices.

Fig. 5.12-8 H2 Logic within the system

Fault F1: A fault at F1 is fed by A and D. The relays 1...6 (DDx 6, DSRx 6) start. In the DDx 6, the operat-ing time topTP, which represents the basic time for the H2 logic, is started. Relays 2 and 5 "view" the fault in reverse direction and block relays 1 and 6, which "view" the fault in forward direc-tion, within the basic time. The remaining relays – 3 and 4 - measure the fault in forward direc-tion while they do not receive a blocking signal. Upon expiry of the basic time, they issue the TRIP command. The other relays trip in case the blocking signal is present as backup protection within the preset grading time, unless the start has been reset up to this time. (Moreover, instan-taneous tripping of the relays 2 and 5 via the station blocking bus is effected due to the forward direction of no. 3 and 4, which enhances safety.) Fault F2: In case of a fault F2 in an outgoing feeder which is not capable of providing feedback, the over-current time relay issues, through its signal relay contact "General start", a blocking signal to the station blocking bus. Thus, instantaneous tripping for the short-circuit in the busbar direction has been blocked. As the relays 2, 3 and 5 measuring in the reverse direction block their counter-parts in the same way, relay 8 trips with its preset time (here 0.2 s). In this case, backup protection by the grading times of the relays containing a blocking signal is ensured. (The instantaneous zone of relay 5 is additionally blocked via the station blocking bus, as no. 4 acts in forward direction.) Fault F3: Fault F3 demonstrates the effect of the H2 logic as busbar protection. None of the relays located at the station blocking bus generate a blocking signal, so that relays 2 and 3 are capable of trip-ping in the basic time. As the blocking signal only acts on the basic time, the backup protection of the grading time is also operative here. The separate routing of a station blocking signal for the short-circuit direction and the earth short-circuit direction or earth fault direction in the isolated-neutral system, as is known from old, existing systems, is not required if the DDx 6 (and DSRx 6, DSRZE 2) is used. Output of the di-rection signals of these protection functions can be combined in the output configuration.

I> 0.1 s / 0.8 s

→ ←

I> 0.1 s / 0.2 s

← →

Z1 0.1 s / 0.6 s

→ ←

Z1 0.1 s / 0.4 s

← →

I> 0.1 s / 0.4 s

→ ←

I> 0.1 s / 0.6 s

← →

A B C D1 2 3 4 5 6

I> 0 s / 0.2 s

7 8

Fault F1

Fault F2

Fault F3

Station blocking bus

Z1 / I> 0.1 s / 0.8 s

→ ←

Start in Z1 or I>

Direction outputs

Teleprotection inputs basic time / grading time

I> 0 s / 0.2 s

Protection with direction decision e.g. DDx 6, DSRx 6, DSRZE 2

I> 0 s / 0.2 s

Overcurrent time protection e.g. DSZ 2, DSZ 4, DS 6

Functions


Examples: The output commands “1971 Short Circ.forward“ and “2971 Earth-SC forward“ or “7071 EarthFlt. forw.“ are assigned to the output relay DO2 for the forward direction.

Thus, these protection modules permit tripping in the basic time. If cooperation with other directional relays is necessary which require separate station blocking signals, cooperation can be ensured by the use of a second input of the DDx 6. Example:

The inputs DI1, physically on “Short-circuit forward“, and DI2, physically on “Earth short-circuit forward“ (or “Earth fault forward“), are configured in "OR-gated“ fashion as “19062 H2:Subst.BlockSignal“.

5.12.2.2.2 Wired connection of the H2 logic Important:

• To prevent series-mode interference on the signal lines, twisted cables must be used as a minimum requirement. Additional shielding is useful.

• To secure monitoring for interruption of a signal loop in closed-current loop mode to a large extent, the feeding point of the station bus's supply voltage must be arranged at the last relay contact and - if possible - not directly on the optocoupler input.

Connection between two stations The input “19060 TP Signal Input“ which is connected with the protection of the opposite station, can be connected as shown in Fig. 5.12-9. The advantage of the closed-circuit current variants b), c) and d) is automatic monitoring for wire break. Moreover, "automatic" generation of a blocking signal on interruption or short-circuit is beneficial (in case the flow of current is prevented by the input). The solution d) contains OR-gated output commands which have been configured in negated fashion to the relay. This also provides the required blockage automatically in case of failure of the protection relay, e.g. due to failure of auxiliary voltage. Thus, this variant is the most advantageous. In variants a), c) and d), an overload protection (e.g. fuse) must act in case of short-circuit, with only a short-time risk of short-circuit existing in a). As of a duration of the blocking signal of 15 s, the output command “19073 TP Con-nect.disturbed“ is generated in DDx 6 and can be configured to a signalling relay or an LED, and thus signalled. A corresponding entry is made in the event memory. To determine the maximum resistance R in variant b) for the standard binary inputs of the DDx 6, the following shall apply:

max

minmax I

UUR BE−= ,

RUP ²max

min =

UDI is the required change-over voltage of the optocoupler input which depends on the equipment variant. Imax is the maximum current flowing into the input – for universal-voltage inputs 0.04A (see 3.3). The resistors in the supply lines and the resistor R which is being used must not ex-ceed the maximum value Rmax. As the dissipation power of the resistor is relatively high in case of the closed-loop current principle, this variant for the standard inputs of the DDx 6 is only suited for low loop voltages (up to 60V).

Functions


L-

L+

Input: “Teleprotection“

negated

L+


Output: “Reverse direction“

OR „U path disturbed“

OR „Malfunction“

DDx 6, Station A DDx 6, Station B

L- Variant a)

Variant b)

R







L+ L- Variant d)


negated Output: “Reverse direction“ negated

OR „U path disturbed“ negated

OR „Malfunction“ negated

L+ L- Variant c)


negated

Fig. 5.12-9 Principle of connection between two stations

Connection in a station - station blocking bus The binary input “19062 H2:Subst.BlockSignal“ is required for evaluation of the events on the station blocking bus. Fig. 5.12-10 shows the possible interfacing modes.

Due to its power requirements, the circuit in acc. with Fig. 5.12-10 variant a) is only suited for low supply voltages. It requires one external resistor R which can be dimensioned according to the loop voltage range used, i.e. Umin and Umax, as follows:

Ω=08.0min

maxUR ,

RUP ²max

min =

To ensure a long service life of the resistor, it should be overdimensioned regarding power. The variant b) requires the use of NC contacts in the relays to be series-connected, which are connected to the station bus. Variant c) shows that NC contacts can be replaced by NO contacts by the use of negated output commands. Thus, the required automatic blocking of the station blocking bus is available in the case of failure of the auxiliary voltage of a protection device.

Functions


L+

DDx 6 Protection relay 2

Direction protection

StationBus

Protection relay 7

DT Start

Protection relay 8

DT Start L-



Output: „ forward direction“



Optocoupler input: “H2:Subst.BlockSignal“

negated


negated

L+



StationBus

Protection relay 7

DT Start

Protection relay 8 DT Start

L-


Direction protection Optocoupler input:

“H2:Subst.BlockSignal“ negated


negated

Variant a)

Variant b)

Output: „forward direction“









L+



StationBus

Protection relay 7 DT Start negated

Protection relay 8 DT Start

L-


Direction protection Optocoupler input:

“H2:Subst.BlockSignal“ negated


negated

Variant c)

Output: „forward direction“ negated



Output: „forward direction“ negated



Fig. 5.12-10 Connection variants to the station blocking bus in case of DDx 6 as directional relay

Functions


The protection relay is numbered in analogy to Fig. 5.12-8, Station B. In closed-current loop mode (as shown, auxiliary voltage available), voltage is applied to the optocoupler inputs of the station blocking bus. The latter enables instantaneous tripping with the basic time.

If a protection device short-circuits the station blocking bus to 0 V in variant a) by its signalling contact, or if a contact in variant b) or c) opens, the blocking signal is weighted. In this case, the instantaneous zone is blocked.

In case of interruption of the signal line due to a fault, the inputs do not recognize any voltage. This results in the issue of a blocking signal for the timer “topTP” (basic time) to the DDx 6. This is also required in case of short-circuit of the signal line, with a current limit or fuse having to react in variants b) and c). As of a duration of the blocking signal of 15 s, the output command “19074 StationBus disturb.“ is generated in DDx 6 and can be configured to a signalling re-lay or an LED, and thus signalled. A corresponding entry is made in the event memory.

Functions


5.12.3 Unidirectional operation The unidirectional mode operates only in one direction. Thus, the protector may act either as a transmitter or as a receiver only. In the transmitting protector, this method cannot provide for protective signal comparison. The receiving protection can use the advantages of signal compari-son. For protective teleprotection, unidirectional operation is conditional upon a transmission facility of a binary signal, which is self-monitoring. The setting whether the protector is to operate as receiver or transmit relay is made under “19030 Mode Teleprotection“.

5.12.3.1 Unidirectional operation - transmitter No signal comparison is made in case of the protection set to "Transmitter". It does not require a signal output.

Fig. 5.12-11 Active principle "transmitter“ in unidirectional mode

As basic requirement for the sending of a signal, the general start of the protector must be avail-able. Moreover, after “19035 Start TP with EF/IE“ has been enabled - also by single-pole earth faults, depending on the method of neutral connection,

• earth fault with earth fault direction decision in non-earthed systems or • earth short-circuit fault direction in earthed systems,

the basic condition can be satisfied. The earth fault direction decision in non-earthed systems must have been enabled additionally by the “7030 TRIP at Earthfault“ (in the protection module "Earth fault detection“), i.e. be capable of authorizing general starts.

The protection relay closes the contact of its transmit relay if the adjustable “19032 Trans-miss. Condition“ is satisfied additionally: • “Z < Z1x,t1x“ – in case of classification of the measured impedance in the overreach

stage Z1x,t1x, i.e. after classification in the overreaching zone Z1x and expiry of the timer t1x, • “forward“, “reverse “ – "non-delayed" with the selected direction being available. The direction is provided by the short-circuit direction decision or, in case “19035 Start TP with EF/IE“ is enabled, additionally to the earth short-circuit direction or earth fault direction decision.

The internal TRIP is effected - as in case without teleprotection - independently of the selected transmit condition with Z1,t1 (or the other grading stages), but not with the overreach stage Z1x,t1x. Non-selective tripping must be prevented by the usual setting of the Z1 stage to "under-reach".

19071 TP Send Signal

GenTRIP

Z < Z1, t1 Z < Z2, t2 Z < Z3, t3 Z < Z4, t4

t5 t6 DDx 6

19035 Start TP with EF/IE

≥119032 Transmiss. Condition

EF forward

ESC forward

ESC reverse

EF reverse

≥1

SC forward

≥1

≥1

Z < Z1x, t1x

forward

reverse

Gen.Start (Z, I) SC reverse

&

TP ready

Functions


Important • If the “19035 Start TP with EF/IE“ is enabled, the transmit condition “Z<Z1x, t1x“

does not make sense, as these modules only provide the direction. In this case, a direction must be selected as transmit condition.

• The setting of the timer module “5211 t1x Time Zone Z1x“ can be selected for 0, but it must always be ≤ “5111 t1 Time Zone Z1“ in order to permit issuing of the transmit signal before TRIP. The transmit signal can additionally be set to a minimum duration by means of the minimum operating time of the transmit relay.

• The distance zone Z1x,t1x must be set to the direction which measures in the direction of the receiver.

• If the distance zone is blocked, the transmit condition “Z < Z1x,t1x“ cannot be used. • During transmit, a NO contact is required for the transmit relay “19071 TP Send Sig-

nal“. In the case of a fault in the voltage path, impedance and direction determination are blocked. Thus, the transmit condition based on it cannot be satisfied.

5.12.3.2 Unidirectional operation - receiver The protection set to "Receiver" can perform a signal comparison to limit the fault to the 100% protected line. It requires the signal output. As long as no active signal is on the input, failure of the signal connection is not serious.

Fig. 5.12-12 Active principle "receiver“ in unidirectional mode In the protection relay set as a receiver, the signal received from the remote station causes the TRIP command to be requested if the general start is present and the set receive condition “19033 Reception Condition“ is satisfied. Selection is possible between the following re-ceive conditions • “Z < Z1x,t1x“ – classification of the measured impedance in the overreach stage Z1x,t1x, i.e.

the time t1x has expired, • “forward“ – direction forward or • “reverse“ – reverse direction.

GenTRIP &

H &

≥1&

&

enabled


Gen.Start (Z, I)

≥1


&

19060 TP Signal Input 19011 tTRIP


19033 Reception Condition


TP ready

EF forward

ESC forward

DDx 6

ESC reverse

EF reverse

≥1

SC forward

SC reverse

≥1

≥1

Z < Z1x, t1x

forward

reverse

Functions


Moreover, after “19035 Start TP with EF/IE“ has been enabled, the direction can also be provided by single-pole earth faults, and consequently, depending on the method of neutral con-nection


the starting/tripping condition for the signal comparison can be complied with. The earth fault di-rection decision in non-earthed systems must have received additionally the “7030 TRIP at Earthfault“ (in the protection module "Earth fault detection“), i.e. be capable of authorizing general starts. Independently of the TRIP due to signal comparison, TRIP is also generated by the other acti-vated grading stages of the distance protection (Z1,t1; Z2,t2; ... t6).

To enhance safety, a TRIP delay time has been integrated. Runtime effects are prevented by means of the "minimum duration" for the presence of the trip conditions. To this effect, the ad-justable “19011 tTRIP Delay TP“ timer is used. If on expiry of the timer, the TRIP conditions are still present, the TRIP command will be requested. This is e.g. helpful in case of parallel lines with double-sided supply if the fault is not switched off simultaneously on both sides of the par-allel line. Here, the change of direction may briefly result in faulty signals, which can be sup-pressed via the TRIP delay. In case the "receiver" is used in weak infeeds, if the protection relay is set to "Intertripping at no Start" (see 5.12.6), the TRIP command may be issued even if no starting is present, but the transmit signal from the remote station arrives at the receive side. Due to receiver mode, no re-ceipt acknowledgement (echo) is sent. Remarks:

if impedance has been selected as receive condition, the following applies: • The timer“5211 t1x Time Zone Z1x“ determines, together with the receipt of the re-

ceive signal, the trip time of the teleprotection. It can be selected to 0. • The zone Z1x must be selected with overreach to be able to cover 100% of the line safely.

The setting is non-critical due to the signal comparison. • If the distance stage working in parallel Z1, t1 cannot be set safely within the 100% range

due to an insufficiently low impedance, its time t1 (“5111 t1 Time Zone Z1“) must be used for backup grading or this stage must be blocked during signal comparison.

• A fault signal coming from the teleprotection device should be used as signal “19099 Blockage TP“ to block the signal comparison function if an active signal can be applied to the TP signal input in case of fault.

Important:

• If the “19035 Start TP with EF/IE“ is enabled, the receive condition “Z < Z1x,t1x“ does not make sense, as these modules only provide the direction. In this case, a direction must be selected as receive condition.

• If the distance zone is blocked, the receive condition “Z < Z1x,t1x“ cannot be used. • The input “19060 TP Signal Input“ is required for the receiver.

Functions


5.12.4 Permissive overreach protection (POP, POTT) For teleprotection, the "permissive overreach protection" presupposes a transmission device for the binary signals of the two relays which monitors itself. The relative insensitivity to distur-bances of the transmission circuit is an advantage of the permissive overreach protection. A protection signal comparison is made at both adjacent stations. This permits a high selectivity to be achieved even if the fault is located within the overreach zone (Z1 < Z < Z1x). This is made possible by the enable signal from the remote station protector. An extremely rapid selective switching off of a short-circuit supplied on both sides can be realized already by means of the fault direction decision.

Fig. 5.12-13 Active principle permissive overreach protection (POP) A basic condition for the sending of a signal to the remote station and the evaluation of a signal received is the availability of the general start of the protection. Moreover, after “19035 Start TP with EF/IE“ has been enabled - also by single-pole earth faults, depending on the method of neutral connection


the basic condition can be satisfied. The earth fault direction decision in non-earthed systems must have been enabled additionally by the “7030 TRIP at Earthfault“ (in the protection module "Earth fault detection“), i.e. be capable of authorizing general starts. Each of the two protection relays on the section to be protected actuates a transmit relay, if the adjustable “19032 Transmiss. Condition“ is additionally present: • “Z < Z1x,t1x“ – in case of classification of the measured impedance in the overreach

stage Z1x,t1x, i.e. after classification in the overreaching zone Z1x and expiry of the timer t1x,

& ≥1

&

&


19011 tTRIPGenTRIP

&

H

&

enabled



&



≥1

&

TP ready

DDx 619035 Start TP with EF/IE

≥1

19032 Transmiss. Condition EF forward

ESC forward

ESC reverse

EF reverse

≥1

SC forward

≥1

≥1

Z < Z1x, t1x

forward

reverse

Gen.Start (Z, I)

SC reverse

Functions


• “forward“ or • “reverse“ – "non-delayed" with the selected direction being available.

The direction is provided by the short-circuit direction decision or, in case “19035 Start TP with EF/IE“ enabled, in addition to the earth short-circuit direction or earth fault direction deci-sion. The signal received from the remote station causes the TRIP command to be requested if the general start is present and the set receive condition “19033 Reception Condition“ is satis-fied. Selection is also possible between the following receive conditions • “Z < Z1x,t1x“ – classification of the measured impedance in the overreach stage Z1x,t1x, i.e.

the time t1x has expired, • “forward“ – direction forward or • “reverse“ – reverse direction. To enhance safety, a TRIP delay time has been integrated. Runtime effects are prevented by means of the "minimum duration" for the presence of the trip conditions. To this effect, the ad-justable “19011 tTRIP Delay TP“ timer is used. If on expiry of the timer, the TRIP conditions are still present, the TRIP command will be requested. This is e.g. helpful in case of parallel lines with double-sided supply if the fault is not switched off simultaneously on both sides of the par-allel line. Here, the change of direction may briefly result in faulty signals, which can be sup-pressed via the TRIP delay. The relative insensitivity to disturbances of the transmission circuit is an advantage of the per-missive overreach protection. A fault signal coming from the teleprotection device should be used as signal “19099 Blockage TP“, to block the signal comparison function if an active sig-nal can be applied to the TP signal input in case of fault. If in weak infeeds the protection relay is set to "Intertripping at no Start" (see 5.12.6), the TRIP command may be issued even if no starting is present, but the transmit signal from the remote station arrives at the receive side. The protection to be sent in this case contains a response (echo) by means of transmit relay and will switch off immediately afterwards (no waiting for ex-piry of Z2,t2, if the fault is in the overreach area). The minimum duration of the transmit signal must be determined via the minimum operation time of the transmit relay used (Chapter 5.32.5). Remarks: • if impedance has been selected as receive condition, the following applies: o The timer “5211 t1x Time Zone Z1x“ determines, together with the receipt of the re-

ceive signal, the trip time of the teleprotection. It can be selected as 0. o The zone Z1x must be selected with overreach to be able to cover 100% of the line safely.

The setting is non-critical due to the signal comparison. • If the “19035 Start TP with EF/IE“ is enabled, the receive condition “Z<Z1x, t1x“

does not make great sense, as these modules only provide the direction. In this case, a di-rection must be selected as receive condition.

• If AR and signal comparison are enabled, analogue start and transmit conditions should be set for both protection modules (in no case different directions).

• Independently of the TRIP due to signal comparison, TRIP can also be generated by the other activated grading stages of the distance protection (Z1,t1; Z2,t2; ... t6).

• If the distance stage operating in parallel Z1, t1 cannot be adjusted safely due to an insuffi-ciently low impedance, its time t1 (“5111 t1 Time Zone Z1“) must be used for backup grading or this stage must be blocked during signal comparison (e.g. the signal "Signal com-parison disturbed“ might be applied in negated form to the blockage input of the Z1, t1 stage, what activates zone Z1, t1 with the signal comparison disturbed).

Important:

• With the distance stage blocked, “Z<Z1x, t1x“ cannot be used as transmit or receive condition.

Functions


• The setting of the timer module “5211 t1x Time Zone Z1x“ can be selected for 0, but it must always be ≤ “5111 t1 Time Zone Z1“ in order to permit issuing of the trans-mit signal before TRIP. The transmit signal can additionally be set to a minimum duration by means of the minimum operating time of the transmit relay.

• The input “19060 TP Signal Input“ and the transmit relay “19071 TP Send Sig-nal“ (NC contact) are required.

Functions


5.12.5 Blocking overreach protection (BOP) For teleprotection, the "blocking overreach protection" presupposes a transmission device for the binary signals of the two relays which monitors itself. A protection signal comparison is made at both opposite stations. A disable signal will be trans-mitted if the reverse direction is detected, and will disable tripping only for the impedances in the overreach zone (Z1 < Z < Z1x). The procedure has the advantage of selective fast tripping of single-end infeed short-circuits, since no blocking signal can be formed at the other end.

Fig. 5.12-14 Active principle blocking overreach protection (BOP)

Each of the two distance relays on the section to be protected operates a transmit relay to be configured if general starting is present and reverse direction is detected. This blocking signal ef-fects the "blocking overreach protection" in the remote station, i.e. the protection is not affected by the teleprotection function, but is switched off in accordance with the grading time settings of the distance protection. A reverse direction, once detected, becomes effective without any additional delay. In addition to the standard use of the short-circuit direction, the detected reverse direction can also activate the transmit signal upon enabling of “19035 Start TP with EF/IE“ in the case of single-pole earth faults. Depending on the method of neutral connection, the direction results are weighted in case of

• earth fault with earth fault direction decision in non-earthed systems or • earth short-circuit fault direction.

The earth fault direction decision in non-earthed systems must have been enabled additionally by the “7030 TRIP at Earthfault“ (in the protection module "Earth fault detection“), i.e. be ca-pable of authorizing general starts.

19014 topTP

GenTRIP

19060 TP Signal Input &

& SC forward

EF forward

ESC forward

≥1 ≥1



enabled


SC reverse

EF reverse

ESC reverse

≥1 ≥1


&

& Z < Z1x, t1x

&

TP ready

DDx 6

& ≥1

5200 Zone Z1x, t1x en-

abled

IL-Start

Earthfault+TRIP

IE-Start

≥1 ≥1

(U-)I-Start

Z<-Start

&

&

Functions


For tripping, the self-condition (receive condition) “Z < Z1x,t1x“ in forward direction is always used. In the case of a blocked zone Z1x,t1x, the determined forward direction is used as self-condition. The utilization of the overreach zone Z1x,t1x has the advantage over the forward direction that the reach is not extended too far in case of failure of the opposite protector or disturbance of signal comparison. A TRIP command is requested if

• after expiry of the operating time of teleprotection “19014 topTP Operating Time“ • the measured impedance is in the forward-directed overreach zone Z1x and its timer t1x

has expired, • the Z<, (U-) I or IL> starting remains present and, in addition, • no receive signal from the remote station is present.

Thus, the longer of the two timers topTP or t1x determines the trip time. If the transmit signal of the remote station is received previously, the request of a final TRIP is prevented pending complete expiry of the next grading stage or start reset. In case of the receive condition "forward“, Z1x,t1x is not activated. The timer “19014 topTP Operating Time“ must get a value which leaves sufficient time for the remote station to determine and transmit the direction (e.g. >50ms). Especially as regards the use of the earth fault direction, considerably longer times are required in part to complete di-rection determination. To ensure a blocking signal already received ("reverse direction" was present at the remote sta-tion) is not reset more quickly than required, an off delay (approx. 50 ms) of the binary input to which “19060 TP Signal Input“ has been assigned should be set. The cause for the reset of the blocking signal might be the faster elimination of the start in the opposite protector or - in case of parallel lines supplied on both sides - by bilateral, but not simultaneous deactivation of the fault in the parallel line. Here, faulty signals may occur briefly due to a direction change. Remark: • Independently of the TRIP due to signal comparison, TRIP can also be generated by the

other activated grading stages of the distance protection(Z1,t1; Z2,t2; ... t6). • If the distance stage working in parallel Z1, t1 cannot be set safely within the 100% range

due to an insufficiently low impedance, its time t1 (“5111 t1 Time Zone Z1“) must be used for backup grading or this stage must be blocked during signal comparison.

• The use of this signal comparison type in connection with “532 SDLRE Automatic“ is problematic, as interruption of transmitting the reverse direction during the change-over from earth fault to zero power direction is effected until the next direction determination.

Important:

• The distance stage Z1x,t1x must be selected in forward direction “5231 Direction Z1,t1x“.

• The “19014 topTP Operating Time“ must be set to a minimum value, so that the blocking signal from the remote station can be received in time.

• If the distance stage is blocked or if the stage Z1x,t1x is not directed forward, the receive condition “Z < Z1x,t1x“ is not available; forward direction is expected automatically.

• The input “19060 TP Signal Input“ and the transmit relay “19071 TP Send Signal“ are required.

• The physical binary input used for “19060 TP Signal Input“ should be release-delayed. • A fault signal coming from the teleprotection must be used as signal “19099 Blockage

TP“ to block the TP of both protection devices, which prevents tripping by signal compari-son.

• For the case of malfunctions in the protection device, the output commands “51280 Mal-function“ and “18280 U Path disturbed“ must be configured to the “19071 TP

Functions


Send Signal“ (logic "or“) to effect the blocking overreach protection. The NC contact of the relay configured with“51171 Protection ready“ must also be used for the case of total failure of the protection as blocking overreach protection.

5.12.6 Underreach protection – permissive (PUP, PUTT) and acceler-ated (AUP) Both underreach methods presupposes a transmission device for the binary signals of the two re-lays which monitors itself. The relative insensitivity to disturbances of the transmission circuit is an advantage of the underreach protection procedure. In the protection device two underreach methods are realised: 1. Permissive underreach protection – requiring start and correct direction at receivers end, and 2. Accelerated underreach protection – uses Z1x,t1x overreach zone at receivers end (if neces-

sary)

Fig. 5.12-15 Active principle permissive and accelerated underreach protection (PUP, AUP)

Each of the two distance relays on the section to be protected operates a transmit relay to be configured “19071 Send Signal“ if general starting is present and an impedance within zone Z1 is detected. The zone Z1 is not set for overreaching, e.g. its impedance is smaller than 100% of line impedance. After expiry of the accompanying time stage t1 the TRIP command is re-quested. In dependence on the "19033 Reception Condition" a TRIP command is requested too, if • at setting “forward“ (“reverse“) the start and the chosen direction exists – PUP, or

&

&

19071 Send Signal

19011 tTRIP

GenTRIP

&

H

&

enabled



&



≥1

&

TP ready

DDx 619035 Start TP with EF/IE

≥1

transmission condition

EF forward

ESCD forward

ESCD reverse

EF reverse

≥1

SCD forward

≥1

≥1

Z < Z1x, t1x

forward

reverse

Gen.Start (Z, I)

SCD reverse


Z < Z1

Z1, t1 Z2, t2 Z3, t3 Z4, t4

≥1

AUP

PUP

Functions


• at selection “Z<Z1x,t1x“ the measured impedance is within zone Z1x,t1x – AUP. To enhance safety, a TRIP delay time has been integrated. Runtime effects are prevented by means of the "minimum duration" for the presence of the trip conditions. To this effect, the ad-justable “19011 tTRIP Delay TP“ timer is used. If on expiry of the timer, the TRIP conditions are still present, the TRIP command will be requested. This is e.g. helpful in case of parallel lines with double-sided supply if the fault is not switched off simultaneously on both sides of the par-allel line. Here, the change of direction may briefly result in faulty signals, which can be sup-pressed via the TRIP delay. In case of reception condition “Z<Z1x,t1x“ (AUP mode) the “19011 tTRIP Delay TP“ timer should be set to 0 s since t1x already causes the trip delay. Special cases: • Circuit breaker is switched of:

since the protection does not start or measure reverse direction (in case of a fault between CT and CB) an unwanted restriction of the protected line length to Z1 will happen. For this reason the circuit breakers off position signal (“462 CB Position Off“) should be configured logic OR combined to the transmission signal “19071 Send Signal“. If it comes by wire of another slide-in unit, it has to be connected with this sending contact as a parallel wiring. This causes a permanent transmitted signal as long as the circuit breaker is in off position. The opposite side switches off every fault in shortest possible time with that.

• Use at a week infeed: A start on this side is not safeguarded at every fault. With the help of "19034 Inter-trippg no Start" enabled the protection can trip at missing start with signal reception. When the protection is started, the PUP or AUP function is not influenced by intertripping. This function is also known as “intertripping underreach protection“ – IUP.

• Signal transmission equipment is disturbed: A disturbed signal transmission equipment is not a problem for underreach protection meth-ods. Missing received signals cause only the work of the protection in grading time like without signal transmission. A disturbance signal generated by the transmission equipment can be connected to the input “19065 TP Connect.desturbed“. This causes the blockade of the signal comparison, the drive of output command “19073 TP Connect.desturbed“ as well as an event and the compatible report to IEC 60850-5-103.

Note: • A measured impedance in zone Z1 is the fixed transmission condition. Therefore the distance

zone needs to be enabled and parameterised. This stage has to be measured directional. • The reception condition “Z<Z1x, t1x“ is not very reasonable if “19035 Start TP with

EF/IE“ is enabled, because only the direction of these earth-fault functions is delivered. In this case a direction should be chosen as the reception condition.

• If AR and signal comparison are enabled, analogues starting resp. transmission conditions should be set for the two protection modules (in no case unequal directions).

• Independent of the TRIP by the signal comparison the TRIP may as well be generated by the other active grading stages of the distance protection (Z1,t1; Z2,t2; ... t6).

Important: • The input “19060 TP Signal Input“ and the sending relay “19071 TP Send Signal“

(make contact) are necessary. • The underreach protection can not be meaningfully applied, if the distance stage Z1, t1 can

not be definitely set into the 100% zone because of a too small line impedance. • The sending relay, assigned to the transmission signal “19071 TP Send Signal“, can be

parameterised with a minimum operating time (chapter 5.32.5). The signal can then be of-fered long enough to an opposite side that is switching off slower.

Functions


• If the transmission signal of a faster tripping sender can not be extended, the used physical binary input for “19060 TP Signal Input“ needs to be off delayed (reset time). This en-sures the upkeep of the reception condition at a fast switching off of the opposite side. If in this process short-period, false reception signals should be removed, an on delay (pickup time 12..15 ms) might be useful.

5.12.7 Intertripping at no start for weak infeeds Protection relays in weak infeed schemes do not always guarantee starting of the appropriate protector in case of a fault. In this case, to ensure that not only the started protector but also the non-started will trip, the "19034 Intertrippg no Start" (stands for intertripping at no started protection) function may be selected for the protector on the weak infeed. However, this will only be practical for the teleprotection methods "Two-wire comparison", "Unidirectional op-eration" (receiver side), "POP mode" and "PUP mode". Mode of operation: In case of a fault on the protected line section where only the protector on the strong infeed A is started while the protector on the weak infeed B is not started, only protector A will transmit a signal if its transmit condition is fulfilled. Protector B receives the signal and requests the TRIP command immediately. In turn, protector A requests the TRIP command independently of protec-tor B if the necessary conditions are fulfilled, e.g. forward direction. When both protectors have been started, the procedure will no longer be influenced by this function. The intertripping effect can be recognized in the action patterns of the appropriate teleprotection procedures. Important:

• Application of this function presupposes a reliable, undisturbed wire-connection or trans-mission circuit. Otherwise, an unintentional send signal, e.g. open and reclosing of the loop, leads to tripping!

• Intertripping may only be chosen in the protection device of the weak infeed side. • During protection checks, take a possible intertripping of the other side into account!

Functions


5.13 Voltage-Time Protection Overvoltages and undervoltages are dangerous for the operating equipment. Thus, the isolation can be subjected to inadmissible load in case of overvoltage or undervoltage - especially in case of machines. The overvoltage protection is to protect objects subject to protection against ex-cessively high voltages and to disconnect them from the system if necessary. The undervoltage protection may also be used for load shedding.

Two overvoltage and two undervoltage stages are intended to monitor the voltage system. Moreover, the exceeding of the displacement voltage is monitored on two stages.

For evaluation, r.m.s. values are used whose aperiodic component has been removed.

Connection to the voltage transformer is effected via the three phase-to-earth voltages. This makes sense in view of the overall device function, as the earth fault and earth short-circuit di-rection decisions require this connection method.

The voltage stages can be configured individually as signal or tripping stage. Setting: 1. The voltage transformer data must be set under “Setting Set / Setting / Setting Values /

Equipment Adaptation / Transf. Adaptation“. 2. Enabling the voltage starts, the intended connection of a blockage signal, the selection

whether phase-to-phase or phase-to-earth voltages are to be weighted, the enabling of a TRIP command (in case of undervoltage also the supplementary condition for TRIP) and the setting of the pickup values, resetting ratios and timers can be performed under “Setting Set / Set-ting / Setting Values / Protection Modules / Character. setx / Voltage Protection“.

3. In case of utilization of the CB TRIP position signal in the undervoltage protection, the OFF position signal must be routed under “Setting Set / Setting / Inputs / Equipment Adaptation / CB Adaptation“.

4. For a blockage, the optocoupler input required in each case must be configured under “Set-ting Set / Setting / Inputs / Protection Modules / Voltage Protection“.

5. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Voltage Protection“, those to relays under “Setting Set / Setting / Relays / Protection Mod-ules / Voltage Protection“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Voltage Protection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.13.1 Overvoltage protection U>, U>>

Fig. 5.13-1 Active principle U>

After enabling “14100 U> Stage“ or “14200 U>> Stage“ the overvoltage protection monitors the voltages for exceeding the setting “14101 U>” or “14201 U>>”. separately for each phase. On expiry of the appropriate timer “14111 tU> Time” or “14211 tU>> Time” either a TRIP command (and disturbance record) can be generated or only a signal be issued, depending on the selected setting “14130 TRIP at tU>” or “14230 TRIP at tU>>”. For overvoltage protection, a selection can be made between the monitoring of the line-to-line voltage calculated from the three phase-to-earth voltages and monitoring of the phase-to-earth voltage. To this effect, the settings “14131 U> Mode” and “14231 U>> Mode” are used. The resetting ratio “14104 Reset Ratio U>”, “14204 Reset Ratio U>>” can be adapted in accordance with the requirements. The pickup value U> must be entered as a secondary value. In case of monitoring of the phase-to-earth voltages, the value of Un divided by √3 is considered as nominal voltage (setting in transformer adaptation “334 Un VT sec.”). This has the advantage that detection of the devia-tion from the setpoint 1 of the secondary operating measurands is facilitated. To identify this, the “unit“ of Un was adapted for the case of LE voltage monitoring to Un/√3.

Example: In case of setting for monitoring the LE voltages and Un=100V, pickup is effected with a set-ting of 1.2 (Un,LE:/1.73) at a secondary voltage of 69.28V (1.2*100V/1.732). The same set-ting in case of monitoring of the LL voltages results in pickup at 120V.

The settings can be calculated from the primary voltage Up to be measured, the voltage trans-former data "primary rated voltage" Upn and the "secondary rated voltage" Usn (voltage trans-former ratio).

pn

snp U

UUU ⋅>= 5-30: Voltage settings

ULL

14171 U1E> Start

14172 U2E> Start

14173 U3E> Start

D... 6

14100 U> Stage

14199 Blockage U>

connected

& 14198 Blockage U>

H

H

14190 U> FctOn

14199 Blockage U>

& enabled

14174 U12> Start

14111 tU>

&

H

14130 TRIP at tU>

enabled

≥1

UL23 UL31

UL12

uL2E uL3E

ULL

r.m.s

uL1E

14131 U> Mode

Phase-to-Phase (LL)

Phase-to Earth (LE)

14101

U>

14104 Reset Ratio U>

&

&

&

&

&

14175 U23> Start

14176 U31> Start

14180 tU> expired

& GenTRIP ULE

r.m.s. UL2E UL3E

UL1E

Functions


In case of a voltage path error, the overvoltage monitoring is switched off at the latest after ex-piry of the timer “18211 tU Time Malf. U Path“. For further details on monitoring of the voltage path, see measurand check in section 5.29.1.

Each overvoltage stage can be blocked individually once the intended port “14198 Blockage U>“, “14298 Blockage U>>“ has been announced. To this effect, the appropriate input signal “14199 Blockage U>“, “14299 Blockage U>>“ must be used for the blockage. Identically named output commands are available to signal the blockage.

5.13.2 Undervoltage protection U<, U<< After enabling “15100 U< Stage“ or “15200 U<< Stage“, the undervoltage protection moni-tors the voltages for undercutting the setting “15101 U<” or “15201 U<<” separately for each phase. On expiry of the appropriate timer “15111 tU< Time” or “15211 tU<< Time”, either a TRIP command (and disturbance record) can be generated or only a signal be issued, depending on the selected setting “15130 TRIP at tU<” or “15230 TRIP at tU<<”. The resetting ratio for adjustment of the hysteresis is specified with “15104 Reset Ratio U<“ and “15204 Reset Ratio U<<“. For undervoltage protection, a selection can also be made between the monitoring of the phase-to-phase voltage calculated from the three phase-to-earth voltages and monitoring of the phase-to-earth voltage. To this effect, the settings “15131 U< Mode” and “15231 U<< Mode” are used. Normally, the phase-to-phase voltages should be monitored for undervoltage, as they are affected only minimally in case of earth fault Regarding the settings U<, U<<, the specifications made in the above section regarding the overvoltage pickup values apply. For the undervoltage protection, there is a particular feature to be considered: Each switching-off of the monitored voltage, e.g. by tripping of a protector, results automatically in an undervoltage start or in continuation of the undervoltage start and might thus cause a permanently present TRIP command. To prevent this, the setting “15133 U< Stage“ or “15233 U<< Stage“ can be set to “blocked if IL<Imin“ or “blocked if CB Open“. “blocked if IL<Imin“ means that the TRIP command is reset once three-phase I <Imin (setting “18108 Imin=Line dead“) has been detected. If the criterion is not sufficient, the position signal connected at the input “462 CB Position Off“ can be weighted. In such cases, another possibility is the utilization of the blockage signals for the undervoltage protection. Each stage can be blocked individually. In case of a voltage path fault, the undervoltage monitoring is switched off. As the time between the beginning of the voltage path fault and signalling thereof to the protection module may es-sentially depend on the timer “18211 tU Time Malf. U Path“, this must be taken into con-sideration on setting the trip time of the undervoltage start. For further details on monitoring of the voltage path, see measurand check in section 5.29.1.

Each undervoltage stage can be blocked individually once the intended port “15198 Blockage U<“, “15298 Blockage U<<“ has been announced. To this effect, the appropriate input signal “15199 Blockage U<“, “15299 Blockage U<<“ must be used for the blockage. Identically named output commands are available to signal the blockage.

Functions


5.13.3 Displacement voltage protection UNE>, UNE>> (U4>, U4>>) Especially in systems with low-resistance neutral earthing, starting problems may occur in the case of long lines and high-resistant faults. In this case, the current may not be a sufficient crite-rion for selection of the earth short-circuit fault. Detection should be possible via the displace-ment voltage UNE. Another example for application is the protection of neutral earthing transformers against over-load due to the excessively long presence of displacement voltage.

Fig. 5.13-2 Active principle Displacement voltage protection

Monitoring of the displacement voltage UNE for exceeding the adjustable limit “14301 UNE>” or “14401 UNE>>” is effected in case of voltage transformers by comparison of the value calcu-lated from the 3-phase-to-earth voltages to the pick-up value concerned.

If a synchronizing function is not required, the fourth voltage transformer existing in the DDEY design may be used for

• measurement of the displacement voltage or • measurement of any AC voltage

To this effect, “Residual Voltage UNE“ must be set in the “Equipment Adaptation/Transf. Adaptation“ under “336 Usage VT4“. Now, the selection “14335 Value for UNE>“ or “ 14435 Value for UNE>>“ between standard setting “calculated“ and “measured“ can be made in the voltage protection. The latter selection makes sense if any AC voltage is to be monitored at the transformer U4 for exceeding the settings UNE> or UNE>>. In this case, the settings must be set to “calcu-lated“ in all the other protection modules which require actually the UNE:

• Measurand check (UNE monitoring) • Earth fault detection and • Direction decision (earth short-circuit fault direction).

The voltage r.m.s value is used for this function. The result is issued with a delay via the appropriate timers “14311 tUNE> Time” or “14411 tUNE>> Time”. The resetting ratio is specified with “14304 Reset Ratio UNE>“ and “14404 Reset Ratio UNE>>“. If a TRIP command is required upon expiry of the timer, it must be enabled via the setting “14330 TRIP at tUNE>” or “14430 TRIP at tUNE>>”. Thus, the appropriate stage is author-ized to perform general starts, the TRIP command is realized with the final TRIP. In case of a sig-nal, only the appropriate command is set. The following output commands are available for mes-sages:

14370 UNE> Start

D... 6

14300 UNE> Stage

14399 Blockage UNE> &

14398 Blockage UNE>

H

H

14390 UNE> FctOn

14399 Blockage UNE>

& enabled

14311 tUNE>

H

14330 TRIP at tUNE>

enabled

14301 UNE>

14304 Reset Ratio UNE>

&

uL1 uL2 uL3 UNE

(∑/√3)

UNE

14335 UNE calculated measured (only DDEY6) GenTRIP

connected

uNE

14380 tUNE> expired

Functions


• if the limit UNE>/UNE>>, i.e. “14370 UNE> Start“/“14470 UNE>> Start“ has been signalled "exceeded without delay", and

• “14380 tUNE> expired“/“14480 tUNE>> expired“.

Each stage can be blocked individually once the intended port “14398 Blockage UNE>“, “14498 Blockage UNE>>“ has been announced. To this effect, the appropriate input signal “14399 Blockage UNE>“, “14499 Blockage UNE>>“ must be used for the blockage. Identi-cally named output commands are available to signal the blockage.

Important: • As an unbalanced failure of the voltage path (voltage transformer, connections to the latter)

generates a UNE>(>) start, the detection of the fault in the voltage path should have priority over this stage (utilization of input for fuse voltage transformer, shorter time “18211 tU Time Malf. U Path“)

• The pick-up value “18301 UNE>Check“ of the measurand check should be set to a value exceeding the UNE> of the displacement voltage time protection.

• In the distance protection, there are several UNE> starting modules used in various fashions, and the appropriate signals (UNE>Check, UNE>EFC, UNE>EF, UNEmin ESCD). The UNE stages pertaining to the "voltage protection" group do not have any other identification than “UNE>“ or “UNE>>“.

Functions


5.14 Frequency protection The frequency protection is to protect the object subject to protection against inadmissibly fre-quencies and to disconnect it from the system as required.

Four stages are provided to monitor frequency. These can be selected freely as over- or under-frequency stages. If the selected pickup frequency is lower than the system frequency, the stage operates as underfrequency protection, otherwise as overfrequency protection.

Fig. 5.14-1 Active principle Frequency protection – one stage shown

The frequency protection is blocked in the condition as delivered. It must be enabled in each case via the function switch “16100 f1>< Start“, “16200 f2>< ..“, “16300 f3>< ..“ or “16400 f4>< ..“.

It permits determination for each stage whether it is to generate a TRIP command upon expiry of the timer “16130 TRIP at tf1><”,“16230 TRIP at tf2><”,“16330 TRIP at tf3><”, “16430 TRIP at tf4><”. If a TRIP command has been admitted, each frequency start effects a general start and thus the recording of disturbances. The individual stages and consequently all the appropriate pickup values (“16101 f1><”,“16201 f2><”,“16301 f3><”,“16401 f4><”) and timers (“16111 tf1>< Time”,“16211 tf2>< Time”,“16311 tf3>< Time”,“16411 tf4>< Time”) are not available before enabling of the stages. The frequency determination is based on the voltage which is determined from the difference of two line-to-line voltages (uL12-uL23). The frequency monitoring is set if a minimum rating of the ULL voltages is no longer reached “16008 ULLmin for fx><”. As soon as the frequency of the measuring variable leaves the measuring range (see 3.8.1) in upward or downward direction, the last decision is recorded. If necessary, each stage of the frequency protection can be blocked individually. To this effect, the intended blockage to be used must be enabled “16198 Blockage f1><”,“16298 Blockage f2><”“16398 Blockage f3><”“16498 Blockage f4><”. Then, the appropriate binary inputs can be configured. Setting: 1. The enabling of the frequency starts, the intended connection of a blockage signal, the ena-

bling of a TRIP command and the setting of the min. voltage for frequency determination, setting of the pickup values and timer modules can be effected under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Frequency Protect.“.

2. For a blockage, the optocoupler input required in each case must be configured under “Set-ting Set / Setting / Inputs / Protection Modules / Frequency Protect.“.

16170 f1>< Start

D... 6

16100 f1>< Start

16199 Blockage f1>< &

16198 Blockage f1><

H

H

16190 f1>< FctOn

16199 Blockage f1><

& enabled

16111 tf1><

H

16130 TRIP at tf1><

enabled

&

16101 f1><

16180 tf1>< expired

&uL1 uL2 uL3

u12-u23

UL12 UL23 UL31 min (ULL)

16008 ULLmin for fx><

GenTRIP

connected

Functions


3. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Frequency Protect.“, those to relays under “Setting Set / Setting / Relays / Protection Mod-ules / Frequency Protect.“.

4. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Frequency Protect.“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.15 Power protection The power protection of the three-phase active and reactive power is to protect objects against inadmissibly high power flows or returns and to disconnect them, if necessary, from the power system. The reactive power monitoring can also be used to switch reactive power compensation devices on and off. Even if the power direction is not taken into consideration, the monitoring for exceeding the ac-tive power can be used, e.g. for motor protection. The advantage of power monitoring in com-parison to current monitoring only is in the fact that the current voltage is taken into considera-tion.

Fig. 5.15-1 Active principle Power protection

Two P> and two Q> stages are envisaged for monitoring. One function switch per stage (“17131 P> Direction“, “17231 P>> ..“, “17331 Q> ..“, “17431 Q>> ..“) determines their direction: selection between forward, reverse or non-directional. Forward means one positive sign each for active or reactive power.

Fig. 5.15-2 Definition of the power directions

Q> reverse

Q

P

P> forward P> reverse

Q

P

Q> forward

capacitive

inductive

D... 6

17170 P> Start

P> Start

17130 TRIP at tP> enabled

P>

17101 P> 17104 Reset Ratio P>

&

uL1 uL2 uL3

17131 P> Direction

forward reverse non-directional

iL1 iL2 iL3

17180 tP expired

& GS

&

H

Error U path

17100 P> Stage

17199 Blockage P> &

17198 Blockage P>

H

H

17190 P> FctOn

17199 Blockage P>

& enabled

D... 6

GenTRIP

connected

17110 tO

17112 tR

17111 tP

Functions


The settings of the powers (“17101 P>“, “17201 P>>“, “17301 Q>“, “17401 Q>>“) are re-ferred to the nominal apparent power Sn of the system, i.e. Sn is measured in case of Un and In (Sn =√3⋅Un⋅In). The resetting ratio of the power starts can be selected (“17104 Reset Ratio P>“, “17204 .. P>>“, “17304 .. Q>“, “17404 .. Q>>“). Short-time power peaks can be masked by pick-up delay (“17110 tO P>> Operate Delay“, “17210 tO P>> ..“, “17310 tO Q> ..“, “17410 tO Q>> ..“). If the pickup delay has ex-pired for the stage, a release delay (“17112 tR P> Release Delay“, “17212 tR P>> ..“, “17312 tR Q> ..“, “17412 tR Q>> ..“) can be provided downstream to prevent short-time power undercutting from deactivating the start. If a TRIP command with expiry of the timer tO is enabled in addition to a signal (“17130 TRIP at tP>“, “17230 TRIP at tP>>“, “17330 TRIP at tQ>“, “17430 TRIP at tQ>>“), the stage in question is authorized to perform general starts, i.e. a disturbance record is initiated. In case of a signal, only the appropriate command is set. In case of the enabled TRIP command, the trip delay “17111 tP> TRIP Delay“ (“17211 tP>> ..“, “17311 tQ> ..“, “17411 tQ>> ..“) is started upon beginning of the start, after expiry whereof the TRIP is issued while the overshoot still exists. A fault in the voltage path results in blockage of the P/Q stages. Any existing starts are logged off. The individual power protection stages can be blocked as required via external signals. To this ef-fect, this intention must be notified with the setting “17198 Blockage P>“ (or “17298 Block-age P>>“, “17398 Blockage Q>“, “17498 Blockage Q>>“). Subsequently, the corresponding inputs “17199 Blockage P>“ (or “17299 Blockage P>>“, “17399 Blockage Q>“, “17499 Blockage Q>>“) can be configured. The blockage can be signalled externally via the output command of the same name. The input of the power values in the setting menu of the DDx 6 is effected as secondary three-phase current power referred to √3∙Un∙In = Sn. Thus, these can be determined from the primary three-phase power Pprim (Isn and Ipn are the sec-ondary and primary transformer rated currents and Usn and Upn the secondary and primary trans-former nominal voltage, rI and rU the transformer ratios) as follows):

3111

311

⋅⋅

⋅⋅

⋅=⋅⋅

⋅⋅⋅>=nnIU

primnnpn

sn

pn

snprim IUrr

PIUI

IUUPP

Provided that Isn=In (connection to correct terminal) and Usn=Un (setting of transformer adapta-tion “334 Un VT sec.“ must correspond to the secondary value of the voltage transformer), the following results:

3⋅⋅>=

pnpn

prim

IUP

P 5-31: Power setting

Thus, provided nominal voltage and nominal current are present, the value 1 is reached for the setting "secondary" in analogy of the measurand display. Remark: • An inversion of the power sign which might have been effected for the operating meas-

urands (incl. substation control signals) “339 P,Q Display“ remains without effect on the power protection.

• The release delay tR is to be set shorter than the TRIP command delay. The power protection also can be configured to report an underrun of a set power value (P<, Q<) over a little detour by means of the output commands “17170 P> Start“ (or “17270 P>> Start“, “17370 Q> Start“, “17470 Q>> Start“) for relays. The use of the negated form of the output command is important, i.e. the output relay shall be active at a power below the op-erate value.

Functions


At this use of the power protection the operate value P< is the setting value P> or Q > multi-plied by the resetting value RV>: P< = P> ⋅ RV>. For the resetting values for P< and P> is valid: RV> = 1/RV<. From this we can determine the setting value P> from P< and RV<: P>= P< ⋅ RV< (With P> and RV>: setting values of power protection, for example “17101 P>” and “17104 Reset Ratio P>”) The general TRIP command is not possible in the case of the P<, i.e. the accompanying TRIP command after expiry of the time stage “17130 TRIP at tP>”, “17230 TRIP at tP>>”, “17330 TRIP at tQ>“ or “17430 TRIP at tQ>>“ must not be enabled. If the power underrun (P<) shall nevertheless lead to an undelayed TRIP command, the output command for example “17170 P> Start“ must be configured on the TRIP relay negated. For a required time delay the off delays are usable “17112 tR P> Release Delay“, “17212 tR P>>...“, “17312 tR Q>...“, “17412 tR Q>>...“. The TRIP command is not registered as such but announced only as a reset of the P> power starting in the event memory. Hint:

To prevent a P< start in case of a switched off (dead) line it is recommended to block this power stage using for instance the output command “18163 3phase I < Imin“.

Setting example for a P< annunciation:

An annunciation shall occur at an underrun of the active power P< =0.8⋅Sn. The resetting value shall be 1.1, e.g. at a measured power >0.88⋅Sn this annunciation must disappear. The setting value P> is than P>=P< ⋅ RV<=0.8⋅Sn ⋅ 1.1=0.88⋅Sn. The setting value for the reset ratio is calculated with RV>=1/RV<=1/1.1=0.91

Setting: 1. The current and voltage transformer data must be set under “Setting Set / Setting / Setting

Values / Equipment Adaptation / Transf. Adaptation“. 2. The enabling of the required active and reactive power stages, the intended connection of a

blockage signal, the selection of the required power direction, the enabling of a TRIP com-mand and the setting of the pickup values and timer modules can be effected under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Power Protection“.

3. For a blockage, the optocoupler input required in each case must be configured under “Set-ting Set / Setting / Inputs / Protection Modules / Power Protection“.

4. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Mod-ules / Power Protection“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Power Protection“.

5. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Power Protection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.16 Overload Protection (thermal replica) The overload protection operates using a thermal replica with "memory", i.e. taking the preload into account in accordance with IEC 60255-8 or EN 60255-8. The r.m.s values of the highest phase current are used. The thermal replica operates with a clock frequency of 100 ms, thus the time resolution (time error) is fixed to these steps (±100 ms). The dynamic behaviour for tripping results from the following equations:

⎥⎥⎥⎥

⎦

⎤

⎢⎢⎢⎢

⎣

⎡

−⎟⎠⎞

⎜⎝⎛

⋅

⎟⎠⎞

⎜⎝⎛

⋅−⎟

⎠⎞

⎜⎝⎛

⋅⋅=

⎥⎥⎥⎥

⎦

⎤

⎢⎢⎢⎢

⎣

⎡

−⎟⎠⎞

⎜⎝⎛

⎟⎠⎞

⎜⎝⎛−⎟

⎠⎞

⎜⎝⎛

⋅=

1lnln 2

22

22

22

InkI

InkI

InkI

kInI

InI

InI

t

PP

a ττ valid for:

kInI

> und kInIp <

5-32: Trip delay thermal replica

with: ta Trip time after commencement of overload τ Warm-up time constant of the resource “4102 tau therm.Timeconst.“ I Current flowing at present In Rated current of line transformer IP Preload current k Factor by which the nominal current is multiplied in order to reach the pickup

limit “4101 k Pickup Factor“

InIk max= with Imax as maximal admissible continuous current

k is determined from the primary variables as follows:

primaryrtransforme

equipmentprotected

IpnI

k_

_max= 5-33: Pickup factor, thermal replica

Example: the maximum admissible primary continuous current of the object to be protected be 1.3⋅In, the nominal current of the object to be protected 500 A and the current transformer used has 600/5. Thus, k is calculated as follows

083.1600

5003.1=

⋅=

AAk

As short-circuit currents are switched off very quickly by means of the short-circuit protection, it makes sense not to continue to fill the thermal replica during a short-circuit, which might result in a thermal reclosing lockout. The setting “4111 OLoadProt. up to ILmax“ permits limita-tion up to which current the replica is to be filled. Tripping can be effected at the 100% level of the temperature memory, which corresponds to reaching the operating temperature of the resource concerned. This level is reached by definition if a current of l=k⋅In is flowing for an unlimited time at an ambient temperature to be fixed. When the thermal replica is enabled, the current level appears on the display with the other oper-ating measurands. Normally, the upper ambient temperature limit is the reference temperature for the setting of the tripping limit k⋅In. The following mathematical connection exists between the actually possible pick-up factor knew and the real ambient temperature Tamb at a specified limit temperature Tl and the value kold set for the reference temperature Treference:

referencel

ambloldnew TT

TTkk−

−⋅= 5-34: Effect of temperature on pickup factor

Functions


Fig. 5.16-1 Active principle Overload protection

Example: The setting is kold=1.1 at a reference temperature of 40 °C, the limit temperature be 140 °C. At actual ambient temperatures of 20 °C 0 °C -20 °C knew could be set to 1.2 1.3 1.39

This shows that the resource in question cannot be operated up to its real limits at low ambient temperatures without the ambient temperature being integrated in the calculation.

Remark: The DDx 6 has four changeable characteristic sets. This can be used to change the values for k, e.g. depending on the ambient temperature or operation in summer / winter.

The protection module "thermal replica" has, if enabled accordingly (“4131 Therm. Warn.Level 1“, “4132 Therm. Warn.Level 2“), two adjustable warning levels with the set-tings “4108 Therm. Warn.Level 1“ and “4109 Therm. Warn.Level 2“. These warning levels are required to issue the warning via output relays or LEDs. In case of levels of ≥ 100%, another output command “4180 Therm.Level >=100%“ for signalling purposes is activated.

Apart from the warning levels, TRIP commands can also be issued via the overload protection “4130 Gen.TRIP at >=100%“. Moreover, this setting allows to select whether in case of the

4175 IL > ILmax therm.

4171 Therm. Level 1

DDx 6

4100 Overload Protection

4197 Block.therm. TRIP

disabled

not if Dist/I start

even if Dist/I start &

4196 Block.therm.TRIP

H 4190 O.load Prot FctOn

4197 Block.therm. TRIP

enabled

4172 Therm. Level 2

4133 ReclLockout Overload

enabled

F ≥ 100%

ReclLockout Overload

ReclLockout ready

4130 Gen.TRIP at >=100%

H

IL1 IL2 IL3 max (IL)

&

4111 OLoadProt. up to ILmax

H

4131 Therm. Warn.Level 1

enabled disabled

&

4108 Therm.

Warn.Level 2

&

4103 ReclLockout Ovload from

H

4132 Therm. Warn.Level 2

enabled

&

4109 Therm.

Warn.Level 1

44180 Th L l> 100%

4178 Recl.Lock Overload

connected

&

4104 Reset

ReclLock Ovload

S R

&

& 4101

k Pickup- Factor

F /%

4102 tau therm. Timeconst.

GenTRIP

Functions


simultaneous appearing of a distance protection function and the TRIP by the thermal replica the grading of the distance protection is to be given priority or not. By selecting “not if Dist/I start“, the thermal TRIP command is suppressed during a distance or current start.

Important: The TRIP command through the thermal replica is not reset until the level of 98% has been undercut. Only now is switching on possible again.

If necessary, the TRIP command of the overload protection can be blocked. To this effect, the in-tended connection of the blockage signal must be enabled under “4196 Blockage therm. TRIP“. Subsequently, the input “4197 Block.therm. TRIP“ must be configured. As a protection against inadmissible reclosing after tripping, a reclosing lockout can be activated. For further details, refer to section Fehler! Verweisquelle konnte nicht gefunden werden.. The development of the thermal fill level FI can be recorded in the event memory. If the function switch “4135 Record Therm.Level“ has been enabled, the thermal level is recorded for 5⋅τ, if an active edge is detected on the input assigned “4161 Record Therm.Level“. The time inter-vals of the event entries are 0.25⋅τ. Below, please find a few useful formulas. The mathematical connection between the level FI of the thermal replica in percent and the current required to reach precisely this value is:

2

2

100

kInI

FI

⎟⎠⎞

⎜⎝⎛⋅

= 5-35: Level, thermal replica

Example: A current of 1.055⋅In at k=1.1 results in a level of 92%. For I=1⋅In the result is 82,6%. By means of this equation (inserted in equation 5-32), the remaining time to tripping can be es-timated for an instantaneous level F if the current remains constant:

⎥⎥⎥⎥⎥

⎦

⎤

⎢⎢⎢⎢⎢

⎣

⎡

−⎟⎠⎞

⎜⎝⎛

⋅−⎟⎠⎞

⎜⎝⎛

⋅=2

2

22

%100ln

kInI

FkInI

t theorya τ 5-36: Trip time for level F

The result of this evaluation can be visualized in the operating measurand menu.

If no value is known for the thermal time constant τ, a value can be determined approximately from the data regarding the thermal short-circuit rating of the resource concerned. In many cases, not only the max. admissible continuous current Imax but also the current I1s admissible for 1s is known.

( )2

max

21

)(60 II s

⋅≈τ 5-37: Time constant thermal replica

Remark:

If the overload protection or an Inverse Time stage (IDMT) does not issue a TRIP command, other measures must be taken to ensure that the current transformers’ load capability (section 3.3) is not exceeded in case of overload.

The thermal replica is blocked in the state of delivery of the protection device, and must be en-abled when utilization via “4100 Overload Protection“ is intended. The trip times of various settings of τ can be inferred from the following characteristic represen-tations. They also illustrate the influence of the preload current Ip and of the factor k.

Functions


Setting: 1. The phase current transformer data must be entered in the menu ”Setting Set / Setting /

Setting Values / Equipment Adaptation / Transf. Adaptation“. 2. If the reclosing lockout is to be used, it must be enabled under “Setting Set / Setting / Set-

ting Values / Protection Modules / Character. setx / Reclose Lockout“. 3. The enabling of the overload protection and its warning stages, the intended connection of a

blockage signal for thermal TRIP, the enabling of a TRIP command with supplementary con-dition, if possible the enabling of the reclosing lockout and an intended recording of the level as well as the setting of the pickup factor k, the thermal time constants, the warning levels and the pickup and reset value of the reclosing lockout can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Overload Protection“.

4. For a thermal TRIP blockage and recording of the thermal level, the required optocoupler in-put must be configured under “Setting Set / Setting / Inputs / Protection Modules / Overload Protection“.

5. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Mod-ules / Overload Protection“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Overload Protection“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Overload Protection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

5.16.1 Level after supply interruption or operation In designing the DDx 6, great value was attached to a continuation of the thermal replica with maximum safety. The level is logged as long as the processor is supplied. The following special cases may occur and have the effect shown below:

1. Switching off / on the thermal replica (Setting: “4100 Overload Protection“) Once the overload protection is enabled, the level commences at 0% This is a method – e.g. for testing – to achieve a level of 0% by manipulation.

2. Restart of the device (e.g. connecting the supply voltage) In case of a restart, the level is set to a value which corresponds to the currently flowing current. If the current exceeds the nominal current of the object to be protected in this process 0.91⋅k⋅In, it is set to the value corresponding to 0.91⋅k⋅In (equation 5-35). Safety is our first concern.

3. Protection Restart (in “Protection – Main Menu“) see 2. Restart of the device.

4. Reparameterization In case of changed settings (without reclosing of the overload protection), the level re-mains unchanged.

5. Reset therm. Level (in “Test menu”) In this subitem of the menu “Test“, the level of the thermal replica can be reset to 0%.

6. Software-Reset (in “Test menu”) see 2. Restart of the device.

Functions


In=IB; k = 1.1; Ip = 0 Parameter: τ /min

0.1

1

10

102

103

104

105

106

1 10

I / In

ta /s

1

2

4 6 8

10

20

40

120

5 3 4 2 6 7 8 9

240

480

960

Fig. 5.16-2 Trip characteristics for k=1.1 and without preload (Ip=0)

Functions


In=IB; k = 1.1; Ip =0.9⋅In Parameter: τ /min

0.1

1

10

102

103

104

105

106

1 10

I / In

ta /s

5 3 4 2 6 7 8 9

1

2

4 6 8

10

20

40

120

240

480

960

Fig. 5.16-3 Trip characteristics for k=1.1 and Ip=0.9⋅In

Functions


In=IB; k = 1.1; Ip = 1⋅In Parameter: τ /min

0.1

1

10

102

103

104

105

106

1 10 I / In

ta /s

1

2

4

6 8

10

20

40

120

5 3 4 2 6 7 8 9

240

480

960

Fig. 5.16-4 Trip characteristics for k=1,1 and Ip = 1⋅In

Functions


Fig. 5.16-5 Trip characteristics for different preloads Ip

0.1

1

10

102

103

104

105

1 10I / In

ta /s

1

1

4

20

1

4

4

20

20

k = 1.1Parameter: Ip; τ /min

120

120

120

τ

Ip = 0 Ip = 1 Ip = 0.92 3 4 5 6 7 8 9

Functions


Cooling Parameter : τ /min

1

10

102

103

104

105

0 10 20 30 40 50 60 70 80 90 100 Level /%

t /s

1

4

2

6

10

20

40

120

240

480 960

Fig. 5.16-6 Characteristics for cooling at I = 0, switching-off at 100%

Functions


5.17 Monitoring of temperature limits (option) The following temperature monitoring functions are only possible in case of protection relay models with temperature capturing board PT100 and connected temperature sensors Pt 100. The board PT100 enables connection of up to eight temperature inputs Pt 100. The measurands of the connected sensors are provided to the protection module "Temperature protection" in digi-tized form, if • the “631 Temperature Sensors“ are enabled (“connected“) in "Equipment Adaptation/

Device Adaptation“ and • if the temperature measured in each case was entered as “connected“ (“632 Temperature

1“, “633 Temperature 2“, “634 Temperature 3“, “635 Temperature 4“, “636 Tem-perature 5“).

• if “4400 Temp. Monitoring“ was enabled in the "protection module/temperature protec-tion“.

Fig. 5.17-1 Active principle of the temperature protection based on temperature 1

The digitized temperature values (5.31.6) which have been pre-processed in accordance with the settings in the ”Temp.Sensor TI“ configuration permit a straightforward comparison with a tem-perature limit to be specified (“44xx Limit Temp.x“). Once the limits have been exceeded, a TRIP command can be issued, if the latter has been enabled (“44xx TRIP Temperature x“). Additionally adjustable warning levels can be enabled via “44xx Warn.Level Temp.x“ (setting “44xx Warn.Level Temp.x“), and permit a timely information to the operating company as re-gards the state of the object to be protected. The “software” temperature 2 has a second warn-ing level.

4471 Warning Temp. 1

DDx 6

4400 Temp.Monitoring

4499 Block. Temp.Monit. &

4498 Block. Temp.Monit.

H

H

4490 Temp.Monit. FctOn

4499 Block. Temp.Monit.

& enabled

H

4431 TRIP Temperature 1

enabled

4473 Temperature 1 >

&

&H

631 Temperature Sensors enabled

H

632 Temperature 1

enabled

Temperature Sensor TI1








&

Configuration ma-trix

665 Temperature 1

Maximum Minimum Average

PT100

&

4402 Limit

Temp.1

&

4401 Warning Temp.1

H

4430 Warn.Level Temp.1

enabled

&

H

4432 If TRIP by Temp.1

set reclose lockout

& Reclose Lockout Temperature

ReclLockout ready

GenTRIP

connected

Functions


The warning levels and the temperature limit overshoots can be configured by means of appro-priate output commands to relays, vDIs and LEDs to be signalled externally (“44xx Warn.Level Temp.x“, limit temperature overshot: “44xx Temperature x >“).

If necessary, this temperature protection module can be blocked upon enabling of the blockage signal “4498 Blockage Temp.Monit.“ via the input “4499 Block. Temp.Monit.“. The cycle duration for new temperature measurands is approx. 0.57 s. The temperature limit monitoring can set a reclosing lockout if required (44xx If TRIP by Temp.x), which can only be eliminated via external reset. This requires enabling of the protection module “4500 Reclose Lockout“. This reclosing lockout makes sense at the temperature measurement connectors where defects must be anticipated or which require manual action. Thus, e.g., if the specified temperature of a bearing is exceeded, this may destroy the bearing or require at least elimination of the cause of overheating. The set reclosing lockout must be eliminated via the input signal “4561 Reset Recl.Lockout“ or via an operation on the protective device in the protective device main menu (regarding the reclosing lockout, see also chapter Fehler! Verweisquelle konnte nicht gefunden werden.). In the operating measurands, the configured and mathematically pre-processed temperature measuring connectors are displayed, i.e. the above-mentioned temperature measurement connec-tors 1 to 5. In contrast, the non-processed temperature of each connected physical Pt 100 sen-sor in the test menu can be checked. Remark:

Implausible temperatures are not weighted. Instead, the output command “51273 Warning Pt100 TI“ is activated; an entry in the event memory and a report appear.

Setting: 1. The temperature recording and the individual sensors are enabled in the menu “Setting Set /

Setting / Setting Values / Equipment Adaptation / Device Adaptation“. 2. If the supplementary feature Reclosing lockout is to be used, it must be enabled under “Set-

ting Set / Setting / Setting Values / Protection Modules / Character. setx / Reclose Lockout“. 3. The enabling of the protection module "Temperature Protection“, its warning levels and

those of a TRIP command, the enabling of the reclosing lockout, of the intended connection of a temperature monitoring blockage signal and the setting of the warning levels and tem-

Enables Settings Output Commands 632 Temperature 1 4402 Limit Temp.1 4473 Temperature 1 > 4430 Warn.Level Temp.1 4401 Warning Temp.1 4471 Warning Temp.1 4431 TRIP Temperature 1 4432 If TRIP by Temp.1 (set reclose lockout) 633 Temperature 2 4405 Limit Temp.2 4476 Temperature 2 > 4433 Warn.Level1 Temp.2 4403 Warn.Level1 Temp.2 4474 Warn.Level1 Temp.2 4434 Warn.Level2 Temp.2 4404 Warn.Level2 Temp.2 4475 Warn.Level2 Temp.2 4435 TRIP Temperature 2 4436 If TRIP by Temp.2 (set reclose lockout) 634 Temperature 3 4407 Limit Temp.3 4478 Temperature 3 > 4437 Warn.Level Temp.3 4406 Warn.Level Temp.3 4477 Warn.Level Temp.3 4438 TRIP Temperature 3 4439 If TRIP by Temp.3 (set reclose lockout) 635 Temperature 4 4409 Limit Temp.4 4480 Temperature 4 > 4440 Warn.Level Temp.4 4408 Warn.Level Temp.4 4479 Warn.Level Temp.4 4441 TRIP Temperature 4 4442 If TRIP by Temp.4 (set reclose lockout) 636 Temperature 5 4411 Limit Temp.5 4482 Temperature 5 > 4443 Warn.Level Temp.5 4410 Warn.Level Temp.5 4481 Warn.Level Temp.5 4444 TRIP Temperature 5 4445 If TRIP by Temp.5 (set reclose lockout)

Functions


perature limits is effected under „Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Temperature Protection“.

4. Configuration of the temperature inputs “665 Temperature 1“, “666 .. 2“, “667 .. 3“, “668 .. 4“, “669 .. 5“ including the mathematical preprocessing is performed via “Set-ting Set / Setting / Temp.Sensor TI / Equipment Adaptation / Device Adaptation“.

5. For the required blockage of the temperature protection, the optocoupler input must be con-figured under “Setting Set / Setting / Inputs / Protection Modules / Temperature Protection“.

6. The manual reset required for utilization of the RC lockout via the input signal “4561 Reset Recl.Lockout“ can be configured in the menu “Setting Set / Setting / Inputs / Protection Modules / Reclose Lockout“.

7. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Mod-ules / Temperature Protection“, those to relays under “Setting Set / Setting / Relays / Pro-tection Modules / Temperature Protection“.

8. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Temperature Protection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.18 Reclosing lockout If the NC contact of an appropriately configured relay is switched in the ON circuit of the re-source concerned, the central reclosing lockout prevents reclosing of the object to protect after tripping by:

• the Overload Protection (thermal replica) – when the selectable level is exceeded “4103 ReclLock Ovload from“ (set to 100% as standard, i.e. normally upon tripping)

• the temperature monitoring –

following a TRIP command by a temperature limit overshoot Moreover, the reclosing lockout can be set via the input signal

• “4560 Set RecloseLockout“ by other functions, e.g. by the vDI (virtual binary inputs, see 5.31.2 and 5.32.6) from the nega-tive sequence current stage. The individual tripping elements of the Reclosing lockout which are to be effective must be en-abled individually. For this function, the "overload protection" has been preselected for this func-tion in the factory.

Fig. 5.18-1 Active principle of the central reclosing lockout

F /%

t

I

Reclosing Lockout

100% 4103 ReclLock Ovload from 4104 Rese-tReclLock Ovload

1

0

DDx 6

4500 Reclose Lockout

4599 Block.ReclLockout &

4598 Blockage ReclLockout

H

H

4590 Recl.Lockout FctOn

4599 Block.ReclLockout

& enabled

≥1

4560 Set RecloseLockout

4561 Reset Recl.Lockout

4560 Set RecloseLockout&

& 4561 Reset Recl.Lockout

ReclLockout ready

Recl.-lockout temperature 4570 Reclose Lockout

S R ≥1

thermal level < 4104 ResetReclLock Ovload &

Recl.-lockout overload

connected

&

51639 Cmd Reset Recl.Lockout

H enabled

Reset Recl.Lockout

Functions


If the reclosing lockout (RC) is required, it must be enabled under “4500 Reclose Lockout“ to get access to the other settings in the above-mentioned protection modules. The RC lockout is cancelled as follows

• In case of overload protection: automatically, if the thermal level falls below an adjustable reset value “4104 ResetReclLock Ovload“ of the reclosing lockout.

o Special case: The resetting of the RC lockout via the input signal “4561 Reset Recl.Lockout“ does not result in resetting the RC lockout status at the overload stage or in lowering the thermal level. Reclosing is possible once (emergency re-closing).

• only via the input signal “4561 Reset Recl.Lockout“, by means of the substation con-trol command if “51639 Cmd Reset Recl.Lockout“ has been enabled, or password-protected operation in the Protection system main menu for

o the temperature monitoring o the RC lockout initiated via the input signal.

As the first cause of a reclosing lockout is "coming", the lockout is set and reset as the last cause is "going". Coming and going of the blocking effect is recorded in the event memory. Once a reclosing lockout has been set, the period of time until reclosing is possible can be taken from the operating measurand display (5.32.1). Via the optocoupler input "4599 Block. ReclLockout" the Reclosing lockout can be blocked so that a reclosing lockout cannot occur during the input signal and any existing one is invali-dated. The behaviour is largely identical with that of the input “4561 Reset Recl.Lockout“ and switching the RC lockout function off and back on by appropriate setting. The signal designated in an analogous fashion can be used for signalling purposes. Important:

• The following actions resetting the RC lockout require precise knowledge as to whether reclosing of the resource can be permitted (e.g.: cause of fault eliminated)! Otherwise, there is a risk of overload, destruction or major damage!

o resetting the RC lockout via the input signal “4561 Reset Recl.Lockout“ or the operation in the main menu,

o resetting the RC lockout via the enabled substation control command, o blockage of the RC lockout via the input "4599 Block. ReclLockout" or o blocking and reenabling of the reclosing lockout function

• If the reclose blockage is used, a relay with NC contact must be configured to ensure correct functioning of the blockage. This contact must be looped in the CLOSE circuit of the resource.

Setting:

1. If any reclosing lockout is to be enabled and a blockage signal to be connected, this must be done under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Reclose Lockout“.

2. Subsequently, the RC lockout can be used depending on the stage in the protection func-tions "Overload Protection“ and "Temperature Protection“.

3. The - possibly important - signal “4561 Reset Recl.Lockout“, the signal “4560 Set RecloseLockout“ and - if used - the blockage signal must be configured to the required optocoupler input under “Setting Set / Setting / Inputs / Protection Modules / Reclose Lockout“.

4. The outputs to relays, especially the command “4570 Reclose Lockout“, must be se-lected under “Setting Set / Setting / Relays / Protection Modules / Reclose Lockout“, those to LEDs under “Setting Set / Setting / LED / Protection Modules / Reclose Lock-out“.

Functions


5. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / Reclose Lockout“. , setting of their fur-ther utilization is effected under „Setting Set / Setting / Inputs /..“

5.19 Group "General start" in the protection modules To accelerate the finding process, this group within the settings of the protection device includes the group output commands for

• “9170 General Start“ – contains all starts which may result in a trip command (TRIP is enabled). These are all distance protection starts, current and voltage starts incl. the switch-on protection starts (I>SOTF), power start, earth fault start and frequency start. There are no starts for temperature monitoring and overload protection; thus, these are not included.

• The phase-selective starts “9171 Start L1“, “9172 Start L2“, “9173 Start L3“, “9174 Start E“. These output commands are based on the compatible range of IEC 60870-5-103. They contain the phase-selective distance (Z<, U-I) and other current starts (OTP/IDMT, ISOTF). Thus, a phase subject to an earth fault or concerned by a voltage start (U>, U<) is not signalled.

• Current starting in general “9176 DT/IDMT Start“ contains the IL> and IE> (emer-gency) OTP/IDMT starts (incl. IE>int), the switch-on protection starts and the negative sequence current starts. The (U)I starts of the distance protection are not included.

Setting: The outputs to relays must be selected under “Setting Set / Setting / Relays / Protection Modules / General Start“, those to LED under “Setting Set / Setting / LED / Protection Modules / General Start“ and those to the virtual inputs vDI under ”Setting Set / Setting / Cmd.->Inputs (vDI) / Pro-tection Modules / General Start“.

Functions


5.20 TRIP command (CB TRIP)

Fig. 5.20-1 Active principle of the TRIP command stage

The various protection functions existing in the protection equipment can order the issuing of a TRIP command from a central "TRIP command stage". Only this function group can then issue the “9280 TRIP final“ or “9270 TRIP not final“ depending on the presence of a block-age. The “9270 TRIP not final“ originates only in context with the function "AR" (section Fehler! Verweisquelle konnte nicht gefunden werden.) and means that in contrast to the "TRIP final", re-closing is intended and that some tasks in the protection device change, for example: the inter-ruption of the circuit breakers "off" signal is activated. Due to their great importance, both TRIP commands have been pre-configured in the factory to the command output relay PS-CO1 to activate the circuit-breaker tripping circuit.

! Important:

• As often high voltages are applied to high-power inductances (tripping coil) via the contacts of the TRIP command relay, it is essential that the limited tripping capacity is taken into ac-count. Normally, a circuit-breaker auxiliary contact opens this current circuit if it has gone into TRIP position. The TRIP command relay of the DDx6 should not be released before the de-energized state is reached. Otherwise, there is a risk of contact welding or even complete destruction of the relay.

• This is why minimum operating times have been preset by the factory “32201 Oper. Time PS-CO1“ (and “32202 .. PS-CO2“, “32203 .. PS-CO3“, “32204 .. PS-CO4“) for all CO output relays of 200 ms, i.e. an output command to the relays PS-CO1 ... PS-CO4 is issued with the minimum duration of 200 ms.

In the list of configurable output commands, output commands of the type "tx expired" are to be found, which often signal the TRIP request of the appropriate protection module group to the

≥1

9280 TRIP final

9270 TRIP not final

DD... 6

9230 Extern. TRIP Commands

9299 Blockage sign. TRIP

connected

& 9298 Blockage TRIP

H

9260 External TRIP 1

9299 Blockage sign. TRIP

H disabled 1 external TRIP

2 external TRIPS


9261 External TRIP 2 &

≥1

&


&

&

9278 Blockage TRIP

GenTRIP

&

51631 Cmd Blockage TRIP

H enabled

Blockage TRIP arrives

Blockage TRIP goes &

S R

≥1

saving of set-ting set

AR: non-final TRIP

Functions


TRIP command stage. A possibly existing blockage does not affect these output commands. They normally are only used for signalling purposes. The signal “9299 Blockage sign. TRIP“ can be used to block a TRIP command. Intended utilization must be communicated in the settings: “9298 Blockage TRIP“ “connected“. More-over, the possibility of "TRIP blockage” can also be selected for the substation control via a command. This may be helpful in special cases, e.g. for cases of change-over when the circuit-breaker must not be switched off in intermediate switching states. To accept the blockage com-mand from the substation control, that command must be enabled: “51631 Cmd Blockage TRIP“. This setting is found under “Com.+SubstCtrl./ Substation Control“. An additional function can generate a "group TRIP command" which is recorded and processed for substation control. If additional equipment is provided to switch off the circuit breaker beside the DDx 6, for example an external measuring or monitoring relay, this can be effected via the optocoupler inputs. The number of the required TRIP inputs can be determined via the set-ting“9230 Extern. TRIP Commands. Subsequently, the function “9260 External TRIP 1“ or “9261 External TRIP 2“ must be assigned to the required optocoupler input. The receipt of such input signal resulting in the output of the “9280 TRIP final“ is recorded in the event memory and signalled to the substation control equipment. The input configured with “9360 Signal CBF extern.“ also results in “9280 TRIP final“, if “9332 TRIP at CBF external“ has been enabled. However, the event records are adapted to the function. For further details, see 5.21.

Remark: In case of the DDx 6, a TRIP command of at least the duration of the minimum operating time of the output relay is issued. The maximum duration corresponds to the input signal time. Please make sure that the minimum operating time is assigned a value in which the circuit-breaker auxiliary contact is capable of opening the tripping circuit.

Setting: 1. The settings are limited to the intended connection of a blockage signal or an external TRIP

command under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / CB TRIP“.

2. The TRIP blockage command for the substation control system is enabled in the menu “Set-ting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“.

3. For external TRIP or blockage, the required optocoupler input must be configured under “Set-ting Set / Setting / Inputs / Protection Modules / CB TRIP“.

4. The important outputs to relays which have been preconfigured by the manufacturer can be found under “Setting Set / Setting / Relays / Protection Modules / CB TRIP“, those to LEDs under “Setting Set / Setting / LED / Protection Modules / CB TRIP“.

5. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / CB TRIP“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.21 Circuit-breaker failure protection (CBF) The circuit-breaker failure protection is used to check correct execution of the TRIP command by the circuit-breaker. It monitors a TRIP command issued

• by the DDx 6 and/or • by another device placed at the same switch.

Moreover, a TRIP signal (coming from lower-ranking outgoing feeders, due to the CB failure), can be executed.

It has two function parts: • Protection module on output side

The function of the circuit breaker is monitored following a TRIP command by observation of the current in the protected line section. By means of a TRIP command to the circuit-breaker, the timer for the internal failure protection “9311 tCBF intern“ is started; within this timer's runtime, the currents in all phases must be below the minimum current limit “9308 IminCBF “ If this does not occur, the output command “9371 Internal CBFailure“ is is-sued upon expiry of the timer and the output relay to which it is assigned in the configuration is actuated. This output relay should preferably activate a contactor whose contact is capable of interrupt-ing the often high-intensity, inductive TRIP coil circuit of the circuit-breaker assigned to it. The other contacts of the contactor are required for the output of the switch-off request to the protection relays in the incoming feeder circuits. If the circuit-breaker position signal is also to be used as criterion for circuit-breaker failure, this must be enabled under “9330 CB Check Pos Open“. In this case, the CB position is weighted additionally (TRIP must occur within tCBF internal, the intermediate, fault or ON position must not exist). This means that on expiry of the timer, I < IminCBF as well as the final trip po-sition of the circuit-breaker must be available.

Remarks: • Integration of the position signal may result in unwanted operation, e.g. due to contact

or voltage problems. This criterion should only be used if the current measurement is not sufficient.

• On the other hand, the position signal enables checking for effective switching off in case of switch-off by protection functions which do not require enhanced current (e.g. voltage protection).

• Protection module on input end The input signal “9360 Signal CBF extern.“ starts the timer “9312 tCBF external“ af-ter expiry thereof and with the supplementary condition satisfied that at least one current is higher than IminCBF (i.e. circuit-breaker has not tripped), the output command “9372 tCBF extern. expired“ is activated. If the “9330 CB Check Pos Open“ is enabled, the CB position is weighted additionally to the IminCBF criterion. Thus, two different functions can be realized: o If the execution of the TRIP of a device located on the same circuit-breaker is to be moni-

tored, the output command “9372 tCBF extern. expired“ must be configured jointly with the output command “9371 Internal CBFailure“ to an output relay in order to reach the same effects as an internal TRIP command monitored by the protector. The ad-ditional output of the TRIP command by the external signal is not required in this context (setting “9332 TRIP at CBF external“ to “disabled“). If the CB position is also monitored, I < IminCBF as well as the defined TRIP position of the circuit-breaker must be present on expiry of the timer tCBF external.

o If a TRIP command is to be issued by the input “9360 Signal CBF extern.“, “9332 TRIP at CBF external“ must have been enabled. This makes sense, e.g. in case the circuit-breaker failure signal of a lower-ranking outgoing feeder is received. In this case, the timer “9312 tCBF external“ can be set to 0 or to a smaller value to interrupt inter-ference pulses. The TRIP command is only issued by the DDx 6 if the current flowing at present exceeds IminCBF or if the circuit-breaker is switched ON when the CB position moni-

Functions


toring is enabled. This TRIP command is performed by the above-mentioned function on the output end.

Fig. 5.21-1 Active principle Circuit-breaker failure protection

Remarks: • As long as the state "internal circuit-breaker failure" is present, the TRIP command re-

mains active. An AR will be blocked and their blocking time is started if the AR is enabled. • The reset of the external CBF signal defines the duration of the output signal “9372 tCBF

extern. expired“.

Using an optocoupler input, circuit-breaker failure protection may be blocked. To this effect, upon enable (“9398 Blockage CBF“), the input signal “9399 Blockage CBF“ must be used. The signal designated in an analogous fashion can be used for signalling purposes.

! Important:

− The setting “9308 IminCBF“ must be selected so that this current is undercut with cer-tainty if the line is switched off.

− To ensure the protective function of circuit-breaker failure protection for the assigned circuit breaker, it is mandatory to configure an output relay with the output command “9371 In-ternal CBFailure“ and to wire it in the system accordingly.

− To prevent - in case of CB failure - the potential danger of destruction of the switching relay, programmed with the “9280 TRIP final“ and “9270 TRIP not final“-command, by switching OFF high inductive currents, a contactor or a "victim relay" can be used to open the trip circuit. The contactor is controlled by the relay configured via the output command o “9371 Internal CBFailure“.

GenTRIP &

9311 TCBF intern

3polig I < 9308 IminCBF

& 9360 Signal CBF extern.

9312 tCBF external

9371 Internal CBFailure

9372 tCBF extern. expired

GenTRIP 9332 TRIP at CBF external enabled

IL1 IL2 IL3 ≥1

461 CB Position On

462 CB Position Off

&

≥1

H

9330 CB Check Pos Open

enabled

D R

H

& 9360 Signal CBF extern.

9300 CB Fail.Protect. CBF 9390 CBF FctOn

9399 Blockage CBF &

9398 Blockage CBF

H

enabled H

9399 Blockage CBF

&

D... 6

H

9331 External CB Failure

enabled

&

connected

Functions


Setting:

1. The enabling of the circuit-breaker failure protection, the intended connection of a block-age signal, the enabling of the integration of the CB position signal in the evaluation, the enabling of the use of an input to monitor an external TRIP and the enabling of a TRIP re-quest in case of external failure as well as the setting of the current threshold IminCBF and the times tCBF intern, tCBF external can be performed under “Setting Set / Setting / Setting Val-ues / Protection Modules / Character. setx / CBFailure Protection“.

2. If the position of the circuit-breaker must be evaluated, its inputs must be assigned in the menu “Setting Set / Setting / Inputs / Equipment Adaptation / CBFailure Protection“.

3. For the input signal “Ext. Signal CBF“ and - if required - for the blocking signal, the required optocoupler input can be configured under “Setting Set / Setting / Inputs / Pro-tection Modules / CBFailure Protection“.

4. The important outputs “Internal CBFailure“, “tCBF ext. expired“ to relays must be selected under ”Setting Set / Setting / Relays / Protection Modules / CBFailure Protec-tion“, those to LEDs under “Setting Set / Setting / LED / Protection Modules / CBFailure Protection“.

5. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Protection Modules / CBFailure Protection“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.22 Fault location (FL) In case of a grid fault, the "Fault location" function detects, after the TRIP command, the most probable location of the fault by comparing the measured reactance with the reactance set for this section of the line. The measured reactance values used to generate the mean-value for fault location are time val-ues around the issued TRIP command so as to evaluate the steady state, if possible. The complex earth factor is included when calculating phase-to-earth faults. In addition to locating the fault after a TRIP command, the function also attempts to locate a fault after a start which has not resulted in tripping. The limits of this fault location depend on the measuring range of the protector. The fault location appears in the report and is entered in the event memory. In addition to specifying the measured fault loop, the reactance of faults with a positive deter-mined reactance is represented as primary reactance in Ohm, in km and in percent of the line length. Example: Fault location X1E: 0.53Ω 6.2km 172.6% In the case of faults with measured negative reactance, only the primary reactance can be issued in Ohm: Fault location X1E: -1.33Ω In order to specify the fault location, the input of the secondary reactance of 100% line length is required “9401 XLs*In/A React.100%“. The latter can be determined easily via the following formula from the primary reactance for this line length:

pn

snpnLp

pn

snn

sn

pnLp

n

U

ILpLs U

UIX

UU

AI

II

XAI

rrXX

⋅⋅=⋅⋅⋅=⋅⋅= 5-38: Fault location: Setting X

with In=Isn and: XLs Sought secondary reactance for setting on the protection device (100% line

length) XLp Primary reactance of the line for 100% length Upn Primary rated voltage of the voltage transformer Usn Secondary rated voltage of the voltage transformer Ipn Primary transformer rated current, phase current transformer In Nominal current of protection device selected via terminal arrangement A Unit of measurement Ampere, used to make In dimensionless rI rU Transformer ratio, switchgear current and switchgear voltage transformer For the fault location in kilometres, the actual length in km must be assigned to “9402 100% - Line Length“ via input. Now the protector determines the distance from these values:

%100sXXs

Ls

seF ⋅= 5-39: Fault location: Distance

with: sF Distance of fault location from installation location Xse Secondary reactance measured by the protection XLs Set secondary reactance (100% length) s100% Setting for 100% line length

Functions


Fig. 5.22-1 Inputs and outputs of the fault location

The output command “9470 Fault Loc. < 100%“ can be used to signal a fault location within any impedance (setting for the 100%). Remarks: • The fault location determination can only provide correct values in the case of a homogene-

ous line • For phase-to-earth faults, as for the distance stage, correct setting of the earth factor under

"System Adaptation" is a prerequisite for reasonable results. • The maximum primary reactance which can be represented is 999 Ω. If it is exceeded, no in-

formation is given on % of the line length or km. If the ranges of the values for the indications “...% Line length“ or “...km“ are exceeded, ”999.9“ is issued.

The fault location can be blocked via the input signal “9499 Blockage FL“. Intended utilization must be communicated in the settings: “9498 Blockage FL“ “connected“. Setting: 1. The earth factor should have been set already for the distance protection under “Setting Set /

Setting / System Adaptation / Character. setx / System Adaptation“. 2. The function enable of the fault location, logging-on an intended utilization of the blockage

signal and the settings for 100% length can be made in the menu “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Fault Location“.

3. For the blockage, the required optocoupler input must be configured under “Setting Set / Set-ting / Inputs / Protection Modules / Fault Location“.

4. The signalling of an error location on the line and the blockage signal passed through by the input can be routed to the outputs, if required: “Setting Set / Setting / Relays (or LED or Cmd.->Inputs (vDI)) / Protection Modules / Fault Location“.

DDx 6

9400 Fault Location FL

9499 Blockage FL

connected

& 9498 Blockage FL

H

H

9490 Fault Loc. FctOn

9499 Blockage FL

& enabled 9401

XLs *In/AReact.

100%

9402 100% Line

Length

9470 Fault Loc. < 100% iL1 iL2 iL3

uL1 uL2 uL3 loop

selec-tion

& X ↓

storage

∅

Fault Location

ukl-umn;

ikl-imn

Functions


5.23 Current Annunciation I>an As tells the name of this supplementary function, these current monitoring stages are used for signalling purposes only. On exceeding the limit, no start, no TRIP command and no disturbance record is generated. If necessary, TRIP can be obtained by the additional configuration of the signal output command to the TRIP relay, however, the latter is not listed as such in the event memory and in the messages to substation control.

Fig. 5.23-1 Active principle Phase current annunciation stages

The phase current is monitored for overshoots and signalled phase-selectively with two stage values “11101 IL>an“, “11201 IL>>an“, the earth current in one stage. After the parameteriz-able delay time “11111 tIL>an Time”, “11211 tIL>>an Time” or “12111 tIE>an Time” the appropriate output command “11180 tIL>an expired”, “11280 tIL>>an expired” or “12180 tIE>an expired” is activated and can be used for signalling.

Remark: If a delayed, phase-specific current overshoot annunciation is to take place via relays, this is possible using the logic AND gate in the output configuration. e.g.: “11171 IL1 > IL> an” UND “11180 tIL>an expired”.

For the earth current determination for signal purposes, the choice is possible between • IE calculated from the phase currents and • IE measured via the installed IN transformer.

The decision is made with the setting “12133 Value for IE>an“ measured or calculated. In case of a device with sensitive earth fault transformer IN, the detection of a very low earth cur-rent is thus possible. The appropriate pickup value is “12105 IE> an sensitive“. If the de-vice has an insensitive earth current transformer or if earth current is calculated, the appropriate pickup value is “12101 IE>an“. If the IN transformer is not required for earth fault detection (earth fault detection is switched OFF), the IN transformer of the device can be used to measure any other current. The only dis-advantage is the possibly incorrect current designation in the events. Each signal stage can be blocked individually once the intended port “11198 Blockage IL>an“,“11298 Blockage IL>>an“, “12198 Blockage IE>an“ has been announced. To this effect, the appropriate input signal “11199 Blockage IL>an“,“11299 Blockage IL>>an“, “12199 Blockage IE>an“ must be used. Identically named output commands are available to signal the blockage. Setting: 1. The enable of the current annunciation, the intended connection of a blockage signal, the

choice whether the measured or the calculated earth current is to be weighted, and the set-ting of the pickup values and timers can be effected under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Current Annunciation“.

11173 IL3 > IL>an

D... 6

11100 Annunciation IL>an

11199 Blockage IL>an &

11198 Blockage IL>an

H

H

11190 IL>an FctOn

11199 Blockage IL>an

& enabled

&

11101 IL>an

11111 tIL>an Time

11171 IL1 > IL>an

11172 IL2 > IL>an

11180 tIL>an expired

≥1

IL1 IL2

IL3

connected

Functions


2. For a blockage, the optocoupler input required in each case must be configured under “Set-ting Set / Setting / Inputs / Protection Modules / Current Annunciation“.

3. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Current Annunciation“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Current Annunciation“.

4. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Current Annunciation“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.24 Synchrocheck and Synchrocheck AR (only DDEY6) The Synchrocheck function enables interconnection of live systems by the following evaluation:

• Frequency synchronism of both systems • Loss of voltage of one or both systems

The Synchrocheck function is capable of cooperating with the integrated substation control sys-tem as well as with the AR protection module. To satisfy the various requirements of both modes, separate Synchrocheck parameters and enable criteria can be set in each case.

The following activation modes are possible: • Connecting command due to a substation control command:

− remote − local − digital input

• Connecting command due to a reclose command from the AR • Measurement request from the substation control

Remark:

The description of the Synchrocheck setting is in this case limited here to the protection part. Configuration from the point of view of substation control has been described in a separate document.

In the case of a connecting command, the voltages of the supply systems are evaluated. In case of synchronism or loss of voltage of one or both systems, a connecting command is issued and subsequently the Synchrocheck function is terminated.

During operation, supply systems must be checked for synchronism frequently, even without connecting command. To this effect, the supply systems can be measured by the substation control via a measurement request, and evaluated. Subsequently, appropriate substation control messages are issued.

In case of a connecting command, the maximum synchronization runtime is started (“9712 tsyncmax time“ or “9812 tsyncmax AR“). Only during this time are the supply systems being evaluated and connected in case of synchronism or loss of voltage. In case of a timeout, an ap-propriate message is issued, in conjunction with an event entry.

The supply systems are subjected to a two-step evaluation according to the following criteria: • Voltage check • Synchronism check

Functions


Fig. 5.24-1 Active principle Synchrocheck

= 1

LL

LB

DL

DB

&

&

&

U S 1

CB Close Request by Control

“check voltage” function

“check synchronism” function

Voltage range

Voltage difference

U S 1

U S 2

U low ULV

U S 2 <UDd

Live voltage

Dead voltage

t3 0

t2 0&

U low U LV

=1

CB Close immediate by Control

“9760 Bypass SyncCheck“

Max . Sync. Time“9712 tsyncmax time“

“9812 tsyncmax AR“

1t1

R

“9799 Blockage SyncCheck“ &

&

Bypass check delay“9713 tdeadlive Bypass“

“9813 tdeadlive Bypass AR“

Synchronous condition

Voltage bypassing

CB CloseBypassing

3

1

1

1

U S 1<U Dd

?f < fdiff

?U < Udiff

LL -live line LB - live bus DL - dead line DB - dead bus

“9730 If Blockage Sync“

Functions


Setting: 1. The transformer data of the outgoing voltage transformer and of the synchronization voltage

transformer are configured under: “Setting Set / Setting / Setting Values / Equipment Adap-tation / Transf. Adaptation“.

2. The general settings of the Synchrocheck, such as enable of the Synchrocheck, intended connection of a blockage/forced tripping signal, intended connection of a bypass signal, se-lection of the synchronizing voltage, circuit-breaker inherent delay, angle adaptation, sig-nal/event processing and thresholds for energized and non-energized are effected under: “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Synchro-check“

3. For a blockage and bypass signal and for an external voltage monitoring relay of the syn-chronizing voltage, the required optocoupler input concerned must be assigned under “Set-ting Set / Setting / Inputs / Protection Modules / Synchrocheck“.

4. The settings of the Synchrocheck for connection by the substation control, bypassing condi-tions and waiting time for bypassing the voltage check, voltage level, voltage, frequency and angle difference, synchronization waiting time and max. synchronization runtime are also effected under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Synchrocheck“

5. The settings of the Synchrocheck for automatic reclosing (AR), enabling the synchrocheck for the AR, bypassing conditions and waiting time for bypassing the voltage check, voltage level, voltage, frequency and angle difference, synchronization waiting time and max. syn-chronization runtime are also effected under “Setting Set / Setting / Setting Values / Protec-tion Modules / Character. setx / Synchrocheck AR“

6. The outputs to LEDs must be selected under “Setting Set / Setting / LED / Protection Mod-ules / Synchrocheck resp. Synchrocheck AR“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Synchrocheck resp. Synchrocheck AR“.

7. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Synchrocheck resp. Synchrocheck AR“. Subse-quently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

5.24.1 Voltage check Evaluation of the supply systems by comparing the r.m.s values of the voltages applied to the settings “9704 Udead Dead Value“ and “9705 Ulive Live Value“ results in one of the fol-lowing options:

• “live“ • “dead“

On the outgoing feeder end, the comparison is made on three phases with all three phase-to-phase voltages (calculated internally). In the case of earthed systems, the three connected phase-to-earth voltages are compared additionally. This synchronizing voltage is designated as “US1“. On the busbar end, the comparison can only be made with the one synchronization voltage US2 connected to transformer U4. To obtain information about all three phases also in this case, ex-ternal overvoltage and undervoltage relays can be connected for the subsequent evaluation of all three phases. To this effect, “9735 US2 3~“ must be selected as “connected“. The inputs “9761 US2 3~ Dead“ und “9762 US2 3~ Live“ enable evaluation:

• Synchronizing voltage "live" - “9762 US2 3~ Live“ is active • Dead - “9761 US2 3~ Dead“ is active • Invalid range - both signals active or inactive

In addition to the comparison of the r.m.s value, there is also a monitoring feature for the fre-quencies of the supply systems as regards compliance with the device's measurement limits. The following system states are determined via the voltage check:

• Outgoing feeder dead / busbar dead dead line / dead bus

Functions


• Outgoing feeder live / busbar dead live line / dead bus

• Outgoing feeder dead / busbar live dead line / live bus

Moreover, the user can select whether in these states connection is to be effected or not: • Connection if outgoing feeder dead and busbar dead

o dead line / dead bus "9732 Bypass US1D/US2D" "9832 Bypass US1D/US2D AR"

• Connection if outgoing feeder live and busbar dead o live line / dead bus

"9733 Bypass US1L/US2D" "9833 Bypass US1L/US2D AR"

• Connection if outgoing feeder dead and busbar live o dead line / live bus

"9734 Bypass US1D/US2L" "9834 Bypass US1D/US2L AR"

As each of these conditions can be selected individually, combinations are also possible. If a system state occurs in which connection is required, a connection command is issued once a monitoring time has elapsed (minimum degree of compliance with the above enable conditions) (“9713 tdeadlive Bypass“ or “9813 tdeadlive Bypass AR“). System states as well as bypass states can be entered in the event memory and signalled to the substation control. Important:

To avoid malfunctions, it is essential that the miniature circuit breaker (fuse of voltage trans-formers) of the outgoing voltage transformers and the synchronization voltage transformers are connected to digital inputs. In case of a fuse failure of the voltage transformer, the volt-age check is blocked automatically and the system states are declared to be invalid.

5.24.2 Synchronism check The synchronism check evaluates the synchronism of systems whose both sides are live accord-ing to the following criteria:

• Voltage level “9706 Usync min limit“ or “9806 Usync AR min“ “9707 Usync max limit“ or “9807 Usync AR max“

• Differential voltage “9701 Udiff max“ or “9801 Udiff AR max“

• Frequency difference “9702 fdiff max“ or “9802 fdiff AR max“

• Phase-angle difference “9703 phidiff max“ or “9803 phidiff AR max“

A single-phase comparison is effected between the synchronization voltage US2 and the corre-sponding outgoing feeder voltage US1. As synchronization voltage, any phase-to-earth or phase-to-phase voltage can be connected by means of the setting parameter "9731 US2 connected as“. As outgoing feeder voltage, the voltage corresponding to the synchronization voltage (UL1E..UL3E measured or UL12..UL31 calculated) is selected automatically. If a transformer is inserted for both voltage transformers, its vector group can be compensated via angle adaptation "9710 phi correction US2“ so that no external adaptation means are required. For the correction angle to be entered, the result of the connection variant a) or b) in Fig. 5.24-2 and the characteristic k of the vector group (common are: 0, 5, 6, 11) of the trans-former

Functions


a) “9710 phi Correction US2“ = + k ⋅ 30° b) “9710 phi Correction US2“ = - k ⋅ 30°

Fig. 5.24-2 Connection versions of the transformer U4 = US2

If all synchronism conditions are satisfied, a connection command is issued upon expiry of a monitoring time during which the synchronism conditions must be satisfied as a minimum(“9711 tsync delay CLOSE“ or “9811 tsync AR“). The status of the synchronism check, as well as synchronism conditions which are satisfied or not, can be entered in the event memory and signalled to the substation control. Each condition which has been satisfied or not can be signalled explicitly to enable the synchronization proce-dure to be analyzed. Remarks:

• The synchronism check is only performed in the case of systems which are live on both sides. The evaluation whether the systems are live or dead is performed via the settings “9704 Udead Dead Value“ and “9705 Ulive Live Value“ (see voltage check).

• The synchronization delay “9711 tsync delay CLOSE“ or “9811 tsync AR“ must be adapted to the frequency and phase-angle difference settings. Otherwise, connection may not be possible especially in case of a large frequency difference and a small admis-sible phase-angle difference.

5.24.3 Adaptation of phase differences US1 - US2 and CB inherent de-lay The synchrocheck function provides for the synchronization of various voltage levels. This is achieved via specific parameters in equipment adaptation for transformer adaptation of the syn-chronization input US2. The primary value “304 Un VT prim. U4“ as well as the secondary value “337 Un VT sec. U4“ of the synchronization input can be set independently of the val-ues of the outgoing voltage transformers. In addition, the vector group of an inserted transformer may be compensated with the angle ad-aptation “9710 phi Correction US2“ in the function group "Synchrocheck“, so that no ex-ternal adaptation means are required. Especially in case of large frequency differences, the inherent mechanical delay of the command circuit (circuit breaker and pickup time of an auxiliary relay which may be mounted upstream) are to be compensated via an integral inherent delay compensation (“9714 tCB Inherent De-lay“). The current system variables are used to pre-calculate the inherent delay, and the connection command is issued accordingly earlier.

5.24.4 Blockage and bypassing the synchronization If necessary, the use of the optocoupler input enables connection to be effected without consid-ering the voltage and synchronism check. To this effect, the appropriate input signal “9799

DD..6 U4

U1..U3

US1

US2

k

US2

US1

k

a) b)

DD..6 U4

U1..U3

Functions


Blockage SyncCheck“ must be used for the blockage. This signal can be applied to the appro-priate optocoupler inputs after activating “9798 Blockage Sync.Check“ “connected“. The function of this signal can be set to “Refuse CLOSE“ or “Enable CLOSE “ with “9730 If Blockage Sync.“ . Moreover, it is possible to effect a general enable by means of the input signal "9760 Bypassg SyncCheck“ without taking the voltage and synchronism conditions into account. Both signals are only evaluated during activation of the synchrocheck function. They only influ-ence the enabling of a connection. The two enable signals “9760 Bypass SyncCheck“ and “9730 If Blockage Sync.“ “Enable CLOSE“ have priority over a possibly present blockage signal and over a malfunction of the Syn-chrocheck function. If one of these two signals is present, a connection request to the synchro-check is sufficient to trigger immediate connection. If a blockage signal is present and if a synchro-check malfunction is present, connection is not interrupted and does not expire until expiry of the max. synchronization runtime. If during this time, a present blockage signal ("9730 If Blockage Sync.“ set to "Refusal CLOSE“) is reset and if the enable conditions are satisfied, connection is effected.

5.24.5 Signals, events and measurands of the synchrocheck The voltage check as well as the synchronism check provide ample status information which can be entered in the event memory and signalled to the substation control. To prevent the event memory and the message transfer modules from being overburdened by the flow of information, conditions can be defined for entry in the event memory and message trans-fer. The selection is based on the setting “9736 Messages/Events“:

• “M. during Synccheck“: During synchronization runtime, status information is sig-nalled to the substation control. No entry is made in the event memory.

• “M/E.during Synccheck“: During synchronization runtime, status information is sig-nalled to the substation control and entered in the event memory.

• “M. after Synccheck“: The current status is only signalled to the substation control in case of connection, abortion or expiry of the synchronization runtime. No entry is made in the event memory.

• “M./E. after Synccheck“: The current status is only signalled to the substation con-trol and entered in the event memory in case of connection, abortion or expiry of the synchronization runtime.

The synchrocheck function's measurands are displayed in a separate operating measurand win-dow. The measurands are only displayed and updated during activation of the synchrocheck function. For a precise analysis of the synchronization procedure, the states of the voltage and synchro-nism check are displayed additionally. Non-satisfied synchronism conditions are characterized by their grey background (negated view). A satisfied condition during a synchronism request ap-pears on bright background. Remark:

Without synchronism request, not all values for the synchronizing operating measurand dis-play are available, e.g. no difference measurands.

5.24.6 Interaction with substation control If synchronous connection due to a substation control command is intended, the setting parame-ter “9700 Synchrocheck“ in the protection module group "Synchrocheck" must be set to “en-abled“. Afterwards, all settings for synchronous connection can be made.

Functions


Remark: At the same time, the switching device type "Synchro-check CB protection“ must be selected in the substation control switching device management. The description of the parameteriza-tion of the substation control part of the combination device is located in the SPRECON-E-Designer manual.

After a CLOSE command has been generated in the substation control, connection of the syn-chrocheck function is requested after this command has been checked for validity. Subsequently, the synchrocheck function is activated and evaluation of the supply systems is started. If all enable conditions are satisfied, connection to the relay to which the output command “9796 Sync: CB CLOSE“ is assigned, is tripped. Independently of that, immediate connection can be initiated by a forced tripping command from the substation control, without taking account of voltage and synchronism conditions. Moreover, an abort command from the substation control can be used to abort the synchroniza-tion procedure.

5.24.7 Interaction with AR If synchronous reclosing at AR is intended, the setting parameter “9800 Synchrocheck AR“ must be set to “enabled“ in addition to the above-mentioned function enable under "Synchro-check“ in the protection module "Synchrocheck AR“. Afterwards, all settings for synchronous reclosing at AR can be made. The following options for synchronous reclosing are available at choice with “9830 Synchrocheck AR”:

• after rapid reclose (RR) • after delayed reclose (DR) • after both interruption modes (RR & DR)

If the enable conditions are satisfied, the AR trips reclosing to the relay "9980 CLOSE by AR“. Otherwise, the AR cycle will be aborted after the max. synchronization runtime. Remark:

For the synchronization requests of the substation control and in the scope of the AR, there are two different output commands for output of the synchronized CLOSE command; these must be routed to the command relay provided for switching on: “9796 Sync: LS-EIN“ and “9980 CLOSE by AR“.

Functions


5.25 Pulse shaper stage The pulse shaper stage serves to pass input signals through to the output, permitting various time-related changes of the signals. In combination with the logic input signal processing and utilization of the feedback feature of outputs to inputs via the virtual binary inputs (see chapter 5.32.6) ), a very variable, parameterizable logic function is available. Fig. 5.25-1 shows the positioning of the pulse shaper stage between inputs and outputs of the protector.

Fig. 5.25-1 Block diagram to position the function group ”pulse shaper stage“

The pulse shaper stage has the two input signals “19161 Signal 1“ and “19261 Signal 2“, to which one or - with logic gating - several physical signals can be assigned in the scope of the input configuration. The physical signals reach the device either via an optocoupler input (binary input) or via a virtual binary input "vDI“, and are thus available in the input configuration. After configuration, i.e. assignment of the physical inputs to the software signals "Signal 1“ and "Signal 2“, the input signals are available to the pulse shaper stage. The output commands (out-put signals) of the pulse shaper stage “19170 Signal 1“,“19180 IO Coupl. signal 1“, “19270 Signal 2“ and “19280 IO Coupl. signal 2“ are generated following the time-related effect. The difference between "Signal x“ and "IO coupl. signal x“ only consists in the blockability of the "IO coupl. signal x“. The time characteristic (effects, see Fig. 5.25-4 to Fig. 5.25-8) can be changed depending on

• the start conditions “19130 Signal1,Start with“ “19230 Signal2,Start with” whether the ON or OFF edge is to represent the beginning of the output signal,

• the selected time settings for the “19111 Signal1 On-Delay“ or “19211 Signal2 On-Delay“ of the beginning of the signal,

• the conditions for the end of the signal “19132 Signal1,ends with“, “19232 Sig-nal2,ends with“ either with the ON or OFF edge of signal 1 or 2 or on receipt of a separate input signal, and

• the selected time setting for the “19112 Signal1 Off-Delay“ or “19212 Signal2 Off-Delay“ .

As mentioned above, the end of signal can be determined by another input of the pulse shaper stage “19162 Reset Signal1“ or “19262 Reset Signal2“. An active signal on this input terminates the appropriate output signal.

The output signals of the pulse shaper stage can be output like any other output command in the scope of the output configuration to relays, LEDs and virtual digital inputs.

19180 IO Coupl. signal 1

19261 Signal 2

19161 Signal 1

19162 Reset Signal1

Opto-coupler

1

Opto-coupler

2

Opto-coupler

...

Input Configuration

of pulse shaper stage inputs

• Negation • AND • OR

Output configuration

of pulse shaper stage signals

to • Relays • LED • vDI

LED 1

LED ...

Relay ...

Relay 1

19262 Reset Signal2

vDI 1

vDI ...

19199 Block. I/O-Coupl.1


Pulse shaper

stage

• Trigger • Reset condit. • On-delay • Off-delay

&

&

NO

T / A

ND

/ O

R

NO

T / A

ND

/ O

R

OR



19170 Signal 1

19270 Signal 2 19280 IO Coupl.

Signal 2

19190 Signal1 Fct On

19290 Signal2 Fct On

D... 6

Functions


Further to the explanations above, an additional feature of signal processing can be set for sig-nals 1 and 2. Regarding the ON or the OFF delay, a selection can be made as to whether a time already started is to be restarted by a newly detected, active level at the input ("restart pos-sible“) or whether it is to expire unaffected of it to its end, permitting a new time sequence af-terwards only (“not to restart“).

Fig. 5.25-2 Retriggerable / non retriggerable (here setting in accordance with Fig. 5.25-6)

If no change to the time sequence of the input signals is required, a setting of 0 s is required for the delay times. By combining logic gates of various binary inputs and utilization of the feedback from the output of the protection relay to the input via virtual inputs (vDI) together with the signals 1 and 2, a wide range of parameterizable influencing options can be created. This includes • logically combined signals, signals directly following in time • on-delayed signals • off-delayed signals • signals having a fixed (adjustable) length • signals with separate reset. This function has a flip-flop effect, i.e. the possibility to latch a

signal up to an external reset. • “Software wiring“ from the output to the input and subsequent reprocessing, i.e. the output

commands can be output either in a negated form or logically combined as IO coupling sig-nals.

The maximum number of logic operations which is possible for the feedback of outputs to inputs is limited, also in view of comprehensibility (see Fig. 5.25-3).

Fig. 5.25-3 Max. possible feedback of output to input with logic operation

Important: • Feedbacks to their origin are inadmissible, e.g. IO coupling of signal 1 to signal 1. • When selecting the times of the pulse shaper stage, the pickup and reset times assigned to

the binary inputs in the input configuration as well as the preset minimum operating times of the relay outputs must be taken into consideration.

• Before utilization of the preset, configured pulse shaper stage, verification of the intended function by testing is strongly recommended.

If necessary, each IO coupling signal can be blocked individually. To this effect, the intended blockage used must be enabled “19198 Blockage I/O coupl.1”,“19298 Blockage I/O Coupl.2”. The binary inputs pertaining to it “19199 Block.I/O-Coupl.1”,“19299 Block.I/O-Coupl.2” can then be configured.

Signal1

retriggering not possible

t t ton ton

retriggering possible

ton ton ton

IO coupling signal1

AND OR

Signal 1 or IO coupling signal 1

Signal 1

Reset Signal 1

Opto-coupler

1

AND OR

vDI 2

Pulse shaper stage

Opto-coupler

x

List of out-put com-mands

Opto-coupler

y

AND OR

vDI 1

Signal 2

Reset Signal 2

Pulse shaper stage

List of out-put com-mands

AND OR

Relays

LED

vDI 3

Signal 2 or IO coupling signal 2

Input configuration

Input configuration

Output configuration Cmd.->Inputs (vDI)

Output configuration Cmd.->Inputs (vDI)

Functions


Remark: The output commands “19170 Signal 1“ and “19270 Signal 2“ cannot be blocked!

Setting: 1. The enabling of signals 1 and 2 of the pulse shaper stage, their start and end conditions, the

intended connection of a blockage signal and the setting of the pickup and off delay can be performed under “Setting Set / Setting / Setting Values / Protection Modules / Character. setx / Pulse Shaping“.

2. The inputs for an external reset of the signals 1 or 2 as well as for a blockage can be config-ured under “Setting Set / Setting / Inputs / Protection Modules / Pulse Shaping“.

3. The outputs to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Pulse Shaping“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Pulse Shaping“.

4. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Pulse Shaping“. Subsequently, setting of their further utilization is effected under ”Setting Set / Setting / Inputs /..“

Functions


On-delay

Input signal

Signal 1 or 2 after processing

t On-delay

Input signal negated

t Off-delay Off-delay

Fig. 5.25-4 Beginning with "On" edge, end with "Off" edge

On -d ela y t

On-delay

t

Inp ut s ignal "Reset" for Signa l 1 or 2 Inpu t sign al "Reset" n egate d

Inpu t s ign al Input signa l n egate d

Signa l 1 or 2 af ter processing

Fig. 5.25-5 Beginning with "On" edge, end with reset signal to separate input

On-delay t On-delay t

Off-delay Off-delay

Signal 1 or 2 after processing

Input signal Input signal negated

Fig. 5.25-6 Beginning and end with "On" edge

On-delay t

On-delay t

Input signal "R eset" for Signal 1 or 2

Signa l 1 or 2 af ter processing

Input signa l Input signal negated

Input signa l "Reset" negated

Fig. 5.25-7 Beginning with "Off" edge, end with reset signal to separate input

On -d elay

Off -d elay

t t Off -dela y

On-delay

S ign al 1 or 2 after p rocessing

Inpu t s ign al Inp ut s ignal negated

Fig. 5.25-8 Beginning and end with "Off" edge

Functions


5.25.1 Example: Using I/O-coupling for AR in case of two circuit breakers

Fig. 5.25-9 Using the AR together with two circuit-breakers

Problem: Only one of the two circuit breakers existing at the busbars has switched on. This is the only one to receive the AR CLOSE command. If its is switched off by an AR, there is no more information as to which switch had been ON before.

Principle of solution: The pulse shaper stage integrated in most devices of the D series enables "memorizing" the CB switched on before for the case of reclosing. The signal of the CB's ON position signal contact is routed to the input configured with the func-tion “19162 Reset Signal1“, in the example DI 1 of the PROT module. From the circuit-breaker b, this signal is routed to the input configured with “19161 Signal1“, in the example DI 2. The output command of the pulse shaper stage “19180 IO Coupl. signal 1“ is configured to a relay with change-over contact, in the example AO 1. The change-over contact provides control as to which of the two circuit-breakers is to be switched ON.

Deactivate the function: Normally CB a is switched on over the NC contact. When the CB b is switched on manually, AO1 is activated until a signal arrives on the input "Reset Signal1“, which is tantamount to switching back to CB a. The timers of the pulse shaper stage can be set to 0 s, as they are not required.

L+ L1b L2b L3b

Σ

L1a L2a L3a

L-

Input:Signal1

Input:Reset Signal1

CO1 Output command: TRIP final / not final

CLOSE for a

L+

L- for CLOSE a,b

CO2 Output command: CB CLOSE by AR

AO1 Output command: IO Coupl. signal1

b

a

CO 1

CO 2

CO 3

CO 4

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

U1

U2

U3

IL1

IL2

IL3

DI 1

DI 2

DI 3

AO 2

Protection relevant connections only

IN

X12-2 X12-1

X12-5 X12-6

X12-3 X12-4

PS

X3-3

X2-2 X2-1

X3-1 X2-3

X3-2

AO 1

DO 2

DO 1X6-3

PROT X6-1 X6-2

X7-1 X7-2

PROT

X11-6X11-5

X11-2X11-1

X11-3X11-4

X21-2X21-1

X21-5X21-6

X21-3X21-4

X12-6X12-5

X12-2X12-1

X12-3X12-4

X12-8X12-7

X2-1 X2-2

X1-1 X1-2

U4

1A

5A

1A

5A

1A

5A

1A

5A

X3-2 X3-1

L+

L-

L+

L-

L-

L-

L+

CLOSE for b

Functions


5.26 Trip circuit supervision The trip circuit supervision is to detect interruptions in the trip circuit and - if possible - failure of the auxiliary voltage. In addition, the coil of the trip relay CO .. is monitored for detection of an interruption by the self-monitoring of the protection device – to this effect, no further measures are required by the user.

Fig. 5.26-1 Active principle Trip circuit supervision

The trip circuit supervision is based on the detection of the current flow through the tripping coil and through one or several binary inputs. Various binary input types can be ordered for the D..6 devices As standard, strongly non-linear optocoupler inputs are used; linear inputs are available on special request. Setting:

1. Enabling of the “434 TripCircuitSupervision“ together with the determination of the number of binary inputs used and any intended connection of a blockage signal, as well as the adjustment of the trip circuit supervision time can be performed under “Set-ting Set / Setting / Setting Values / Equipment Adaptation / CB Adaptation“.

2. The enabled binary inputs “463 TripCircuitSuperv. 1“, possibly “464 TripCir-cuitSuperv. 2“ and - if required - the input for the blocking signal must be configured under “Setting Set / Setting / Inputs / Equipment Adaptation / CB Adaptation“.

3. The output “480 Malfunct TripCircuit“ to relays must be selected under “Setting Set / Setting / Relays / Equipment Adaptation / CB Adaptation“, the output to LED under “Setting Set / Setting / LED / Equipment Adaptation / CB Adaptation“.

4. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Set-ting / Cmd.->Inputs (vDI) / Equipment Adaptation / CB Adaptation“. Subsequently, set-ting of their further utilization is effected under ”Setting Set / Setting / Inputs /..“

5.26.1 Using non-linear binary inputs Fig. 5.26-2 shows the various connection principles. The block diagrams show the circuit-breaker in OFF position.

Variant a) has two binary inputs whereas the other variants use only one input. The safety as-pects regarding faulty tripping are dominating in the illustrated variant a2) versus a1). Failure of the relay contact or of the input (short-circuit) does not activate the trip due to the resistor R. However, the series connection of contacts in the trip circuit of the protector means again that the trip reliability is reduced.

In b), a change-over contact and a NO contact of the auxiliary switch are required; however, the same scope of monitoring as in variant a) is only realized with a binary input. To enhance safety due to faulty tripping with a second trip contact, the arrangement in analogy to a2) can also be used here and is equivalent.

480 MalfunctTripCircuit

D... 6

434 TripCircuitSupervision

499 BlockageTripCircSv &

498 BlockageTripCircSv

H

H

490 TripCircSupv FctOn

499 Blockage TripCircSv

disabled

411 tTripCircuitSuperv. ≥1

connected

with 1DI

with 2DI &

&

463 TripCircuitSuperv. 1


≥1

Functions


Variant c) uses also one input only, but requires the use of an external resistor. The use of the circuit with a second trip contact in analogy to a) is not always possible, due to dimensioning problems. The switched-off circuit-breaker features the series connection of two resistors. R may only be half the value versus the variants a2) or c). In case of failure of the input contact or the upper contact 1, only R/2 limits the current through the tripping coil.

In variant d), the auxiliary contact is not taken into consideration for monitoring. The variant has the lowest scope of monitoring. For the current flow through the binary input, the additionally required resistor R in the variants a2) and c) bridges the second relay contact or the auxiliary contact of the circuit-breaker (if the switch is set to OFF). Together with the trip coil resistor, the resistor R must allow for a short time to flow a higher current Imax in case of the minimum auxiliary voltage Umin which occurs:

SpuleBE R

IUUR −

−=

max

minmax

. UDI is the required change-over voltage of the optocoupler input which

depends on the equipment variant. Imax is the maximum current flowing into the input – for uni-versal-voltage inputs 0.04A (see 3.3). Thus, the max. admissible resistance Rmax can be deter-mined.

L+

L-

Input

TRIP-relay CO..

Protection relay

b)

L+

L-

OFF-relay CO..

Protection relay

R

c)

L+

L-

TRIP-relay CO..

Protection relay

d)

Input Input

L+

L-

Input 1

TRIP-relayCO..

Protection relay

TRIP coil

a1)

Input 2

Auxiliary contact

monitored conductors, contacts and coils

L+

L-

Input 1

TRIP-relay CO.. Contact 1

Protection relay

a2)

Input 2

R

TRIP-relay CO.. Contact 2

Fig. 5.26-2 Block diagrams - Trip circuit supervision

Functions


CB in position

variant a1) Level 1 / 2 / Safety against faulty trip-

ping

Variant a2) Level 1 / 2 /

Safety against faulty tripping

Variant b) Level / Safety

against faulty trip-ping

Variant c) Level / Safety


Variant d) Level / Safety


ON H / L / ↓ H / L / ↑ H / ↓ H / ↓ H / ↓ OFF L / H / ↓ L / H / ↑ H / ↓ H / ↑ H / ↓

In the circuit-breaker's two stable states required, i.e. ON and OFF, at least one input will show current flow = High (H) level. Only during

• the time of closing the OFF relay and the transitions of the auxiliary switch contacts • or on interruption of the supply voltage • or on interruption of the current flow in the trip circuit (terminals, auxiliary contact, coil)

are the inputs unable of detecting current flow (Low (L) level). If the duration of the L level exceeds the time adjustable for the transitions “411 t TripCir-cuitSuperv.“ this implies a fault in the tripping circuit. The latter can be signalled with the out-put command “480 Malfunct TripCircuit“. Remark:

In case of single-pole switching of the tripping coil and specific safety requirements versus faulty tripping by failure of the binary input (short-circuit), a current limiting resistor could be installed in series with the binary input in order to limit the short-circuit of the binary input to min. 40 mA. The special dimensioning instructions in case of variant c) must be taken into consideration R/2).

Important: • Connection to the trip circuit supervision inputs of the protection relay must be effected as

close as possible to the terminals of the TRIP relay in order to get a maximum monitored line length.

• The validity of the trip circuit supervision with the short-time peak currents of the binary in-puts (min. 40 mA) is to be verified. In case of connection of a maximum auxiliary voltage, the trip coil must not react due to the short-time high current of the inputs, and must be de-activated safely at the input's closed-circuit current.

5.26.2 Using linear binary inputs If the device is equipped with linear binary inputs, additional interfacing variants can be used in addition to the block diagrams shown in Fig. 5.26-2.These variants e) to g) shown in Fig. 5.26-3 e) to g) contain series-connected inputs.

L+ (≥48 V)

L-


TRIP relay CO..

Protection relay

TRIP coil


Auxiliary contact

e)

L+ (≥48 V)

L-


TRIP-relay CO.. contact 1

Protection relay

TRIP coil 464 TripCircuitSuperv. 2

f)

TRIP-relayCO.. contact 2

L+ (≥48 V)

L-



Protection relay

TRIP coil 464 TripCircuitSuperv. 2

g)


R

Input DIx

Fig. 5.26-3 Supplementary block diagrams for trip circuit supervision with linear inputs Variant e) is monitored in CB TRIP position by series-connected inputs; in ON position, only the TRIP circuit supervision 1 is active.

Functions


Variant f) is suitable for two-pole activation of the trip coil with a low monitoring current flow. In both states of the circuit-breaker, there is a series connection consisting of two components (in-puts TRIP circuit supervision 1 – TRIP circuit supervision 2 / Resistor R – input TRIP circuit su-pervision 2). This is advantageous for the case of "short-circuit" faults of a component, as it does not result in tripping. However, the series connection of contacts in the trip circuit of the protector means, on the other hand, that the trip reliability is reduced. The resistor R must be dimensioned for a minimum current flow of 3 mA (

SpuleBE RUUR −Ω

−=

003,0min

max)

Variant g) permits, like variant f), the monitoring for two-pole switching, however without the additional external resistor at the same safety level. The resistor R has been replaced by any lin-ear input of the protection device. No software function need to be assigned to this additional input, as only its internal resistance is used.

CB in position

variant e) Level 1 / 2 / Safety

against faulty tripping

Variant f) Level 1 / 2 / Safety

against faulty tripping

Variant g) Level 1 / 2 / Safety

against faulty tripping ON H / L / ↓ H / H / ↑ H / H / ↑ OFF H / H / ↑ L / H / ↑ L / H / ↑

This state - both inputs detect L – may only occur briefly. If the duration of the L level exceeds the time adjustable for the transitions “411 t TripCircuitSuperv.“, this implies a fault in the tripping circuit. The latter can be signalled with the output command“480 Malfunct TripCir-cuit“. Important: • Connection to the trip circuit supervision inputs of the protection relay must be effected as

close as possible to the terminals of the TRIP relay in order to get a maximum monitored line length.

• As inputs are series-connected at least at times, only max. half the auxiliary voltage is ap-plied to an input, i.e. the auxiliary D.C. voltage must at least be 48 V,

• and both inputs must be of the same type.

Functions


5.27 Event logging Events are saved chronologically to analyse the faults. They are displayed in clear text on the de-vice. Events are classified into various groups:

• System (signals from the protection device system) • Signal (from the switchgear, from the object to be protected) • Malfunction (device faults) • Power system fault (fault of the object to be protected • Operation (signals of operations) • Control (events generated by the control system)

This has the advantage that the event memory display is classified more clearly according to one of the groups. Events are classified, on the one hand, in groups, and, on the other hand, in main and sub-events (pertaining to a main event). Events are "time marked". Main events are marked with date and time, sub-events get the time relative to the main event (in ms). For faults, a fault number is logged, incremented by +1 with every new fault or every new dis-turbance data logging. Each general start, each TRIP command without previous general start (e.g. external TRIP) and an externally enforced disturbance record increment the fault number. The fault number “Fltno“ is indicated in the event memory as sub-event entry ”Fault re-cording Start“. Additionally, a grid fault number is stored, which unlike the fault number is not continued to be counted during an AR cycle, but is counted only at the first AR start. This grid fault number “GrdFlt“ is also located in the event memory in subevent ”Fault recording Start“, next to the fault number. The event memory can be displayed on the protective device without using a PC; to this effect, see 9.1. It is a ring-type memory overwriting the oldest events. If necessary, the contents of the protection system main menu "Clear events" can be deleted. The contents of the event memory is copied over to the flash memory in case of failure of the supply voltage, and is thus retained for any length of time. Setting: The event and disturbance data memory can be deleted via the protection system main menu.

5.28 Disturbance Record The disturbance data record is the result of saving the digital instantaneous values produced at intervals of ms of the three phase currents, the measured earth current and of the three phase-to-earth voltages and, in the DDEY 6, also the voltage on the transformer U4 regarding a certain fault. In addition, important tags (status) of the protection device are recorded. This includes the time of starting, the direction decision and the TRIP command. All the saved tags are specified in section 3.12 on page 27.

Continuous logging is effected. The recording process is triggered by: • General start coming, • TRIP command (without previous general start) and at choice • Input signal “51460 Disturb.Data Record“ • by hand in the test menu incrementing the fault number by +1. The recording ends - depending on the cause of tripping - (but always includes the pre-fault time and, if the maximum length is not exceeded or the disturbance record has been restarted, the post-fault time):

• if the general start disappears • on beginning of the TRIP command or in the case of an external TRIP, with the reset of

the input signal, • at the latest after the max. possible length of 5 s.

Functions


The pre-fault time of the disturbance data memory, i.e. the recording duration prior to the trigger-ing event, is adjustable “51411 Pre-Fault Time“. A value can also be chosen for the post-fault time of the disturbance data memory “51412 Post-Fault Time“. Fig. 5.28-1 shows the conditions.

Fig. 5.28-1 Disturbance data record The disturbance data memory is a ring-type memory overwriting the oldest data. Its contents are copied over to the flash memory in case of failure of the supply voltage, and are thus retained for any length of time. The same occurs when clearing the event memory. The characteristics of the measured variables cannot be viewed on the device’s display. The events must be read out together with the fault data via PC and the operating software COMM-3. Subsequently, the output file can be generated in COMM-3 in COMTRADE format. A file available in COMTRADE format can be viewed and evaluated by means of the graphic software SDA 2. From the graphic display, an individual signal can be analyzed. For analogue variables, a Fourier analysis including graphical or tabular display is also available. COMM-3 generates additional analogue variables calculated from the recorded fault data. The use of a calculation algorithm which is largely similar to the protection algorithm secures reliabil-ity of the computed variables for the behaviour of the protection device. The available, addition-ally calculated variables are also specified in section 3.12. Important: • The currents in the graphic software are represented taking account of the setting “Current

transformer earthing“ “line end“ or ”busbar end“ in the equipment adaptation. The protector processes these measured variables in the same way.

• Exception: the voltage U4 = US2 can be phase-rotated at random with the synchrocheck set-ting “9710 phi Correction US2“ via the software. This rotation is not effected in the disturbance data!

• The optocoupler input states are viewed with the physical level "high" when voltage is ap-plied. In this context, software processing of the optocoupler input signal by negation is not taken into consideration.

Setting: 1. The pre-fault and post-fault time can be selected under “Setting Set / Setting / Setting Values

/ General / Disturbance Record“. 2. The input for an external, controlled disturbance record can be configured under “Setting Set

/ Setting / Inputs / General / Disturbance Record“.

tpost-fault trecord

trecord

trecord

5 s

tpost-fault

tpre-fault

tpre-fault

tpre-fault

Functions


5.28.1 Additional causes for starting a record The above-mentioned causes of tripping for a malfunction protocol can be extended by use of the virtual binary inputs (vDI). For further details on the vDI, please refer to sections 5.31.2, 5.32.6, 8.3.3, 8.4. The basic principle is the use of the input signal “51460 Disturb.Data Record“ for the start of logging and configuration of this input with an output command of the device. For the provision of output commands in the input configuration of the function "Distur-bance data record“, the vDIs are used. Thus, each output command (Table 20) can trip a record. In this context, the following reservations must be taken into consideration:

• Recording is effected as long as the signal is active. • The maximum record length is limited to 5 seconds • Output commands which are present for more than this time should be limited by the

pulse shaper stage to max. 5 s, in order not to impede any records to be started by other events.

Fig. 5.28-2 Start of disturbance record by any output commands

5.28.2 Additional binary tags in the record The labels recorded as default can be extended using the virtual digital inputs (vDI). As standard, the first three vDIs are integral parts of the disturbance data. If they are assigned any output command, this output command is included as label in the fault data. The only disadvantage is that it is not the output command that appears as identifier, but the vDI used to this effect. An output command configured for the start of a disturbance record in accordance with the pre-vious section is automatically included at the same time in the disturbance data as tag.

Fig. 5.28-3 Any output commands as tag in disturbance record

AND OR

Output command 1

Output command 3

Output command 2

Configuration commands → input (vDI)

vDI 1...3

AND OR

Output command 1

Output command n

Output command 2

AND OR

Disturbance data re-cording

Input

Input

Configuration commands -> inputs (vDI)

Configuration inputs

vDI x

Functions


5.29 Supervision and test functions

5.29.1 Measurand check (MCHK) The current and voltage measurands coming in through the device transformers are monitored for their plausibility. Regarding the distance protection, especially the voltage path monitoring fulfils an important task, i.e. to avoid unwanted operation of the protection device. When voltage or impedance related starts are used, the failure of voltages results in starting and - due to the im-pedance Z=0 - also in tripping (this is another advantage of current starting only). In the DDx 6, subsequent measurand checks are performed, provided the monitoring in question has been enabled.

In the voltage path (U path): • detection of three-phase voltage failure • voltage unbalance without current unbalance • direction of the rotating voltage field via measurement of the negative sequence • displacement voltage UNE without IE start (earthed system) or earth fault detection (non-

earthed system) • monitoring the input signal of the fuse voltage transformers (safest and most reliable method) Faults in the voltage path tend to result in blockage of all distance stages (t6 does not run ei-ther), of the direction decision, the fault location determination, the voltage stages and in change-over to emergency overcurrent time protection, see section 5.6.1. The functions depend-ing on direction decisions do not operate any longer, too. The following sections explain, amongst other things, whether the change-over to the emergency overcurrent time protection is effected undelayed or delayed via timer “18211 tU Time Malf. U Path“.

In the current path (I path): • detection of current unbalances • IE-Start without UNE> or phase starting • in case of DDE(Y) 6: comparison of measured zero current with calculated sum of the phase

currents In the case of a fault in the current or voltage path, the output commands “51270 Alarm“ are issued as group signal and the cause of alarms (“18180 I Path disturbed“, “18280 U Path disturbed“, “18370 UNE>Check“ and “18281 WarnPhaseSequ. V“) and an LCD report. A detailed entry into the event memory is triggered. The pickup values for current and voltage unbalance and UNE> can be selected, the reset ratio is fixed to 0.95. The measurand check stops operating in most cases once starting has been detected. The meas-urand check should only be switched off if this is indispensable, e.g. in the case of single-phase tests. If necessary, the plausibility checks can be blocked individually via an input as well. To this effect, the intended connection of the blockage signal in question must be enabled under “18198 Blockage Check IPath“, “18298 Blockage Check UPath“, “18398 Blockage Check UNE“. The inputs of the same names must be configured accordingly. A switched-off or blocked voltage path check does not switch off the assessment of the input signal of the fuse voltage transformer. Remarks:

• All measurand check faults are included in the group output command “51270 Alarm“. • The phase sequence of the currents and of the voltages may be correct, but displacement of

both systems towards one another is possible. To check the correct phase relationship, the power indication by the individual phases should optimally be used, which should normally have a positive P and a positive Q (ohmic inductive behaviour).

Functions


• In the distance protection, there are several UNE> starting modules used in various fashions, and the appropriate signals (UNE>EFC, UNE>, UNE>>, UNE>EF, UNEmin ESCD). The UNE of the measurand check has the identifier "UNE>MCHK“.

Setting: 1. For utilization of the input "360 FuseVoltageTransf.“ or “361 Fuse VT U4“, the connec-

tor must first be logged on under “Setting Set / Setting / Setting Values / Equipment Adapta-tion / Transf. Adaptation“.

2. The enables, the intended utilization of blockages and the settings of the "Measurand check“ can be found in the menu “Setting Set / Setting / Setting Values / Protection Modules / Char-acter. setx / Measurand Check“.

3. The input “360 FuseVoltageTransf.“ or “361 Fuse VT U4“ can be configured under “Setting Set / Setting / Inputs / Equipment Adaptation / Transf. Adaptation“.

4. For the blockage, the required optocoupler input must be configured under “Setting Set / Set-ting / Inputs / Protection Modules / Measurand Check“.

5. The outputs of the alarm signals to LED must be selected under “Setting Set / Setting / LED / Protection Modules / Measurand Check“, those to relays under “Setting Set / Setting / Relays / Protection Modules / Measurand Check“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Protection Modules / Measurand Check“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

5.29.1.1 Signal of fuse voltage transformer's miniature circuit-breaker The miniature circuit-breaker frequently used for the protection of voltage transformers are a safe means for the detection of missing voltages. In the case of an active signal of the voltage trans-former's miniature circuit-breaker, the voltage path fault is signalled without delay.

Fig. 5.29-1 Measurand check U: fuse voltage transformer input

Remark:

If “18200 Supervision U-Path“ or “18300 Supervision UNE“ is switched OFF, a con-figured input “360 FuseVoltageTransf.“ and “361 Fuse VT U4“ remains active.

360 FuseVoltageTransf. &

335 Fuse Voltage Trans.f.

H

18280 U Path disturbed

18282 I> Backup Operation

DDx 6

connected

361 Fuse VT U4

& 338 Fuse Voltage Transf. U4

H connected

DDEY 6 ≥1

Emerg. OTP enabled

&

Functions


5.29.1.2 Detection of the three-phase voltage failure

Fig. 5.29-2 Measurand check U: I without three-phase U

A three-phase voltage failure is recorded via two different methods based on the measurands. The first method ( Fig. 5.29-2) deals with a three-phase voltage path failure when switching the line on (also in case of AR). This also enables the user to recognize three-phase voltage failure during operation. A non-delayed signal and the treatment of the fault in the voltage path are effected in case of at least one enabled, voltage-dependent start. If the voltage-dependent distance starts are not used, a recognized current flow in the absence of voltages is not effective until after a minimum time of “18211 tU Time Malf. U Path“. A voltage transformer failure exists if three-phase ULL < “18208 Umin = min. Voltage“ and simultaneously current flow (at least a phase current > “18108 Imin = Line dead“) are de-tected. In order to distinguish the three-pole short-line fault from the voltage path fault, the as-sessment is only effected as long as there are no current starts or the minimum currents of U-I “5801 I>“ or Z< start “5904 IminZ<“ have not been exceeded. It can be recognized that the procedure permits failure detection in the case of voltage trans-formers on the line end, but that no monitoring for three-phase voltage transformer failure is ef-fected already in the current range as of the minimum current of the voltage-dependent starts.

A fault detected in the voltage path and consequently the change-over to the emergency over-current time protection remains present until (not shown in

Fig. 5.29-2) • correct voltage is detected again, or

all ULL < 18208 Umin = min. Voltage

all IL < 18108 Imin = Line dead

I > 5811 I>>

&

≥1

I > 5801 I>

I > 5904 Imin Z<

&

5830 (U-) I-Start Program voltage independent

5900 Z< Impedance Start enabled

≥1

&

Error U Path

≥1

DDx 6



18200 Supervision U Path 18290 Superv.Upath FctOn

18299 Block. Check UPath &

18298 Blockage Check UPath

H

enabled H

18299 Block. Check UPath

& Supervision U path active connected

&≥11136 IL>+ErrorUPath/EOTP

1236 IL>>+ErrorUPath/EOTP

1336 IL>>>+ErrorUPath/EOTP

1436 IL>>>> ErrorUPath/EOTP

2136 IE>+ErrorUPath/EOTP

2236 IE>>+ErrorUPath/EOTP

2336 IE>>>+ErrorUPath/EOTP

2436 IE>>>>+ErrorUPath/EOTP

8136 IL>+ErrorUPath/EOTP

8236 IE>+ErrorUPath/EOTP

Emerg. OTP enabled

I > IL> DT/IDMT

I > IE> DT/IDMT (besides IE>int)

I > Ineg> DT/IDMT

18211 tU

AR cycle runs

Functions


• all I are also lower than “18108 Imin = Line dead“, i.e. the voltage transformer and the line are switched OFF.

The second procedure in accordance with Fig. 5.29-3 is especially suited for use with voltage transformers on the busbar end, but it does not detect faults when connecting the object to be protected in the case of voltage transformers on the line end. It is investigated whether a current change is present simultaneously with the three-pole voltage drop ULL < “18208 Umin = min. Voltage“. If it is not, failure of the voltage transformer is as-sumed.

Fig. 5.29-3 Measurand check U: three-phase U < Umin without current change

5.29.1.3 Voltage unbalance without current unbalance Handles an unbalanced voltage path failure in case the line is switched ON. The unbalanced volt-age failure during operation can also be recognized.

≥1

all ULL < 18208 Umin =min.Voltage

|ΔIL| > 18108 Imin = Line dead

all IL < 18108 Imin = Line dead

&

Error U Path


18274 3phase U<Umin

Supervision U path active

DDx 6


Emerg. OTP enabled

&

|ΔIL| > 10% &

≥1

U-I Start

Z< Start &

current starting (except IE>int)

&

5830 (U-) I-Start Program voltage independent

5900 Z< Impedance Start enabled

& ≥1

≥1

18211 tU

IL > 18109 Imin Unbalance

&

≥1

Error U Path ULmax/ULmin >

18201 ULmax/ULmin Unbal.

ILmax/ILmin > 18101 ILmax/ILmin=Unbalanc

IE > 4901 IE>EFK


≥1

≥1


18282 I> Backup Opera-tion Emerg. OTP

enabled

&

DDx 6

ULL > 18209 Umin Unbalance

U-I Start

Z< Start

Current starting (except IE>int and Igeg)

4911 t1p runs

1115 t1p runs

Functions


Fig. 5.29-4 Measurand check U: U – unbalance without I – unbalance

Detection, signalling and treatment of the fault in the voltage path is effected without delay or, in case voltage-independent starts are used, delayed by the timer “18211 tU Time Malf. U Path“. As long as no starts are present, no voltage unbalance ULmax/ULmin > “18201 UL-max/ULmin Unbal.“ may be present without simultaneous current unbalance ILmax/ILmin > “18101 ILmax/ILmin=Unbalanc“ or earth current IE >“4901 IE>EFC“ (earth fault criterion). Otherwise, the system decides that a voltage path failure exists. This voltage path monitoring is only effected if there is no fault in the current path, and

• at least one phase-to-phase voltage is greater than“18209 Umin Unbalance“ and • at least one current is above the adjustable beginning of the current unbalance monitoring

“18109 Imin Unbalance“ or if the earth fault exceeds the earth fault criterion. A fault detected in the voltage path and consequently the change-over to the emergency over-current time protection remains present until (not shown in Fig. 5.29-4)

• correct voltage is detected again, or • all ULL are lower than “18208 Umin =min. Voltage“ while all I are lower than “18108

Imin = Line dead“, i.e. the voltage transformer and the line are switched OFF. Important:

The balance checks of the measurand check cannot be set in accordance with the aspects of power system management. They have the task to detect the failure of measurands and must be selected accordingly. In the case of voltage unbalance monitoring, the current unbalance detection must be set as sensitive as to ensure that it occurs together with the voltage unbalance in each case of nor-mal operation. Otherwise, there may be an unnecessary change-over to the emergency over-current time protection.

The voltage unbalance must be set for the case of failure of a voltage. Theoretically, the mini-

mum ULL only amounts to ULL/√3, which results in an unbalance of 33=

⋅

LL

LL

UU . Taking the injec-

tion of interferences in the supply line of the failed transformer into account, settings of 1.4...1.5 should be a good compromise. The current unbalance is never to be set to a value higher than the selected voltage unbalance.

5.29.1.4 Detection of UNE without general start or earth fault Deals with an unbalanced voltage path failure. Monitoring is effected during operation, but not in case of current starts.

18211 tU

Error U Path UNE >

18301 UNE>Check

DDx 6

Earthfault

error U Path

≥1 18280 U Path disturbed

18282 I> Backup Operation Emerg. OTP

enabled

&

18300 Supervision UNE 18390 Superv. UNE FctOn

18399 Block.Check UNE &

18398 Blockage Check UNE

H

enabled H

18399 Block.Check UNE

& connected

18370 UNE>Check &

general start

Functions


Fig. 5.29-5 Measurand check U: UNE without IE or earth fault

If the displacement voltage setting of the measurand check “18301 UNE>Check“ is exceeded without starting or earth fault, this indicates a fault in the voltage path. In case of faults, the sig-nal can be delayed by “18211 tU Time Malf. U Path“, as the earth fault detection does not take place before expiry of the time tUNE>. Due to the fourth voltage transformer in the DDEY 6, there is a special feature to the displace-ment voltage monitoring. If “Residual Voltage UNE“ has been selected in the "Equipment ad-aptation/transformer adaptation“ under “336 Usage VT4“, “18335 Value for UNE Check“ can also be set with “measured“. This affects monitoring differently. If "calculated“ is se-lected, a fault is detected in the three phase-to-earth voltages used for summation. If “measured“ is selected, faults can be detected in addition to primary winding failures in sum-ming up the voltages in the voltage transformer's earth fault winding. Remarks:

• The protection function "Earth fault detection" must be switched on in the compen-sated / isolated-neutral system to permit monitoring of the UNE. If the earth fault detection is not used, the monitoring UNE must be switched off. Otherwise, a voltage path fault signal might be issued during the earth fault.

• When the "earth-fault detection" is used, the timer "tU time malf.U path" has to be set to a value longer than its timer "tUNE> time for UNE>" to permit earth fault detection.

5.29.1.5 Monitoring of rotary voltage field Connections in the voltage path are interchanged by determining the negative sequence system which increases to high values in case of non-cyclic interchange.

Fig. 5.29-6 Measurand check U: rotating field

A wrong rotating system in the voltage is signalled delayed by the timer “18211 tU Time Malf. U Path“. Important:

The phase sequence of the currents and of the voltages may be correct, but displacement of both systems towards one another is possible. To check the correct phase relationship, the power indication by the individual phases should optimally be used, which should normally have a positive P and a positive Q (ohmic inductive behaviour) in case of a power flow from the busbar to the line.

18211 tU

Error U Path

DDx 6


18281 WarnPhaseSequ. V


&Emerg. OTP enabled

U2 uL1-2 uL2-3 uL3-1 U2 >

0.8·Un &


GS

Functions


5.29.1.6 Monitoring of current unbalance The unbalanced failure of current transformers and the appropriate connections can be monitored with this function.

Fig. 5.29-7 Measurand check I: Current unbalance

The measured phase currents are monitored for exceeding a max. tolerated unbalance “18101 ILmax/ILmin= Unbalanc“. To avoid pick-up due to unbalances during operation, especially in case of low loads, at least one of the line currents must exceed the setting “18109 Imin Un-balance“.

Moreover, no start (distance or current start) may be present and at least one ULE voltage must have exceeded the value “18208 Umin = min. Voltage“.

The alarm signal in the current path can be delayed by the timer “18111 tI Time Malf. I Path“. A current unbalance results only in signalling the fault in the current path. Protection modules are not blocked.

Remark The time “7014 tUNE>EF Time f. UNE>“ should be set to a shorter value than the delay time for the current path fault “18111 tI Time Malf. I Path“, to permit an earth fault detection to occur before any "current path fault" signal due to the existing current unbal-ance.

5.29.1.7 IE start without UNE> or general starting

Fig. 5.29-8 Measurand check I: IE start without UNE> or general starting

& 18111 tI

Error I Path

Supervision I path active

DDx 6

18180 I Path disturbed

IE > 2101 IE>Definite Time IE > 2102 IE>Inverse Time

IE > 2201 IE>> IE > 2301 IE>>>

IE > 2401 IE>>>>

UNE > 18301 UNE>Check UNE > 2902 UNEmin ESCD

UNE > 4905 UNE>ESC UNE > 7002 UNE>EF UNE > 14301 UNE>

UNE > 14401 UNE>> GS

IL > 18109 Imin Unbalance

& 18111 tI

Error I Path

3 x ULL < 18208 Umin = min. Voltage

ILmax/ILmin > 18101 ILmax/ILmin=Unbalanc

GS


DDx 6


18100 Supervision I Path 18190 Superv.Ipath FctOn

18199 Block. Check IPath &

18198 Blockage Check IPath

H

enabled H

& connected

18199 Block.Check IPath

Functions


This monitoring detects unbalanced failures of line current transformers which are included in current total generation for the earth current. For distance protection devices with separate IE transformer input (except DD 6), an IE> start measured by the earth current can also be checked for plausibility. Thus, a transformer fault of the earth current measured via the Holmgreen circuit can be detected. The alarm signal delayed by the timer “18111 tI Time Malf. I Path“ is generated if an IE> start is present, without the simultaneous presence of a displacement voltage start or - especially important in earthed systems – without the simultaneous distance protection or phase current start (general start GS).

5.29.1.8 Comparison of the current total with the measured IE The most sensitive method, which is also suitable for the total failure of all three line current transformers, is present in the distance protection devices DDE 6 and DDEY 6 with a fourth cur-rent transformer to measure zero current. This requires zero current to be measured via a sepa-rate summation current transformer also on the switchgear end.

Fig. 5.29-9 Measurand check I: Comparison IE calculated with IE measured

The r.m.s value of the phase current total less the measured earth current (amplitude-adapted) should normally have the value 0. If the result exceeds the setting “18102 Isum>“ there is a fault in the current path: (iL1+iL2+iL3 – iEmeasured)r.m.s > Isum> As the calculated earth current features a mapping fault of the phase current transformers in-creasing along with the current intensity, the reference value Isum> is stabilised:

Isum'> = Isum> + fstab ⋅ ILmax 5-40: Biasing of current total check

Isum> setting for pickup Isum’> biased pickup value fstab setting “18107 fstab Isum>“ ILmax Phase current with the highest r.m.s value Monitoring is effected within the linear measuring range of the device current transformers. The alarm signal in the current path can be delayed by the timer “18111 tI Time Malf. I Path“. Protection modules are not blocked.

18111 tI

Error I Path

DDx 6


iE measured

iL1 iL2 iL3 ∑

&

18102 Isum>

18107 fstab Isum>

ΣiL ≠ iEIEmeasured < 2,5 In


18130 Supervision I Sum H enabled

DD 6

IEmeasured < 25 In

IL < 40 In

&

& IE device ct insensitive

≥1

Functions


Fig. 5.29-10 Measurand check I: Biasing the summation current pickup value

Stabilization total current with different fstab

0

5

10

15

20

25

30

35

40

0 5 10 15 20 25 30 35 40

ILmax

Isum'

0.1

0.3

0.5

0.7

0.9

Isum> = 0,2 In

Functions


5.29.1.9 Imin The current designated "Imin“ is the setting “18108 Imin = Line dead“. To execute certain protection functions, the DDx 6 must "know" whether the object to be pro-tected is or was switched off (de-energized). This concerns e.g. the protection modules "Direc-tion decision“, "Voltage protection“, "Overload protection“, "Measurand check“. Imin has always to be set in such a way that

• in case of a dead object to be protected this value will not be exceeded (lowest limit for Imin and mandatory condition) and

• if the object which is switched on allows a higher current to flow (upper limit for Imin) In the measurand display (see section 5.32.1) no current values are displayed for I < Imin, since no precise measurands can be expected.

5.29.1.10 Umin The setting for the minimum voltage “18208 Umin = min. Voltage“ is a minimum line-to-line voltage. If this setting is undercut • in all three phases and, simultaneously, there is a three-phase I < Imin, "switched-off pro-

tected object" is detected, • in all three phases and there is simultaneously I > Imin, a malfunction in the voltage path is

possible (5.29.1.2), • “< Umin“ appears in the operating measurand display. Setting is possible if the use of Umin is known. Umin must represent a switched-off object to be protected.

5.29.2 Self-monitoring and start of protector Comprehensive monitoring routines for the hardware and software guarantee the detection of protector malfunction and their indication. There are cyclic tests and tests during start-up (con-nection of the auxiliary voltage). The green “Ready” LED signals error-free device operation, i.e. the substation control part and the protection part both are in proper working order. Depending on the detected fault state, the protector is either stopped by a malfunction signal, or an alarm is passed. Both states can be announced separately through appropriately assigned out-put elements (signal relay, LED). Simultaneously, event logging is performed. The output command “51171 Protection ready“ has been provided to signal the undisturbed operation of the protector via a contact. It remains also active in case an alarm is present. “51271 No Warning/Malfunc.“ is also a signal well suited for group signals. It is only active if no alarms or malfunctions of the protector are present. Important:

• “51171 Protection ready“ and “51280 Malfunction“ must never be configured jointly to a relay.

• This command is not suitable for signalling the readiness for operation of the complete device (protection and substation control system). If the readiness for operation of the protection and substation control systems is to be signalled, this must be realized in the substation control part.

If the start-up was not successful, the start of the protector is blocked (protector switched OFF), an appropriate fault message is recorded in the event memory and shown on the display.

5.29.2.1 Alarms If an alarm is passed during start-up or during operation, the protector may continue to operate, but possibly in a limited mode. Each alarm may affect the operating mode of one or more protec-tive and supplementary functions and may result in a change-over to another operating mode of the device.

Functions


Switching between the non-alarm state and alarm state is recorded in the event memory as a group signal (coming with the first active alarm, returning with the last active alarm). This group alarm signal is pre-configured as output command “51270 Alarm“ for relays / LED and virtual digital inputs (vDI) by the manufacturer onto the red LED (steady light). Remark:

During an alarm, the device is still operative (LED, signal relay. The text of the alarm may be displayed alternately with another currently present command which requires text output.

The cause for an alarm is issued as text together with “incoming” or “outgoing”: EEPROM alarm An error was detected in only one of the two copies stored in the

EEPROM when the setting set was checked. Corrective action: Check parameterization and save it again, in case of repeated fault:

service is required. I-path disturbed The measurand check detected a fault in the current path. U path disturbed The measurand check detected a fault in the voltage path. TP disturbed The teleprotection line is disturbed Station bus disturbed The station bus for the H2 logic (teleprotection) is disturbed. Warning TI x Temperatures not plausible (with specification of the appropriate input) Corrective action: Eliminate the cause of the fault

5.29.2.2 Malfunctions Various actions are taken, depending on the type of fault determined. If a malfunction occurs while the protector is in operation, it will be switched off automatically. Further operation of the protector is only possible after eliminating the reason for the problem. If a malfunction occurs, the event "malfunction" is recorded as a group signal in the event mem-ory. Additional entries can be provided to explain the causes thereof. As a default, this group signal is configured to the first LED, so that this LED flashes at the onset of a malfunction. Remark:

The protector is no longer operative (green LED, signalling relay. Moreover, the signal “51280 Malfunction“ is available in the output configuration, so that it can be directed to an output relay, if required. This will normally not be required, however, as the signal is issued via “51171 Protection ready“. If a malfunction is detected during protector start-up, the protector will not start. If there is a malfunction with the protector in operation, it will be switched off automatically. The following causes of faults apply to the protector: Text of display Explanation - Malf. Handshake Co-operation of the controllers is disturbed - Malf. ROM Error during EPROM memory check - Malf. EEPROM Error on reading the EEPROM: the setting set has been lost. - Error trip relay Error on checking the coils of the trip relays CO1...CO4 of the

power supply module PS. - Error U-Ref The reference voltage is outside of the admissible tolerance. - UVCC fault The internal supply voltage (5 V or 24 V) is outside of the admis-

sible tolerance. - Meas. not configured Offset adjustment missing - Meas. not calibrated Fault, transformer pcb - Fault, measurand checksum Measurands transferred from the transformer pcb have checksum

error - Error meas. Timeout Time condition for measurands exceeded - Error meas. access Measurands not requested by protection algorithm.

Functions


- StdPara in EEPROM Fault in checking the setting set in the EEPROM: the setting set has been lost. The standard setting set has been written.

- Watchdog reset Error detected by the controller's internal watchdog function. - Malfunction by trap Controller detects an inadmissible command - IO conflict Conflict between the assignment of inputs or outputs between

protection and substation control systems, e.g. by assigning an element twice

- Buffer overflow the number of events exceeds the RAM memory before saving into the non-volatile memory area has been possible.

- Wrong:hardware module a hardware module which is not suitable for the initial hardware equipment has been fitted (does not correspond to firmware adap-tation)

The micro-controller detects such errors that result in non-performance of the actual machine command that had to be executed (trap mechanism). The reason for such errors can be found in the hardware (e.g., memory errors) as well as in the software. In such case, the program imme-diately aborts all protective tasks. If possible, the program runs a special new start-up, enters the error in the event memory and continues its protection task. When the malfunction appears again three times within 30 minutes, the protection device will be switched off in analogy to the hardware malfunction. The output command is signalled with text output, event entry, setting of an output command for “Malfunction“ and resetting of the out-put command “Protection ready“.

5.29.2.3 Measures to be taken in case of "Alarm" and "Malfunction“ With additional data regarding the cause of alarms and faults, the cause for the malfunction in the protection device is usually limited, so that the measures necessary for elimination of the problem can be taken. First of all: • write down the text report on the display and, • if possible, read the event and disturbance data memory by means of the PC, and save it, and • if possible, read the setting set used via the PC and save it. Subsequently, the following might be tried, however with the device under special observation: • If the protection device is off due to the malfunction (corresponding message visible on LCD),

switch it on again in menu “Setting Set / Setting / Setting Values / General / Device On/Off“. • Execution of a "device restart", or - in case results are not legible - of a "software reset" in

the test menu (setting is preserved). • Execution of a "software reset" under the test menu item with the same name. Settings are

preserved, archive data is deleted. In the case of hardware faults, the complicated device design requires, however, special knowl-edge and auxiliary means to eliminate malfunctions in the operational sequence. For all malfunctions of the protector, which cannot be removed by operations performed on the device, it is recommended to inform the manufacturer's service department so that experts can perform a repair. Recorded displays of the event memory content, the setting set and additional information on the operation during which the malfunction occurred might be useful.

5.29.3 Test menu This menu is especially important for start-up, tests and firmware update to a new structure ver-sion. The available functions are described below.

Functions


Test Start Disturbance Record > Loop Measurands Test Earth-Fault InformationBlockg. Reset FltNo. / GrdFlt Reset Statistic Values Inputs Relays Temp.Sensor TI CB Tests Reset Thermal Level Set Thermal Level Test OverLoad +TRIP Test of Telegrams Software Reset Write Defaults

Setting: The test menu is available in the protection system’s main menu as menu item “Test”.

5.29.3.1 Start disturbance record The release of a fixed-length disturbance record does not require a password. The record is started without delay and without further information by selecting the menu entry “Start distur-bance record“ and by subsequent actuation of the <E> or <→> button. The fault and grid fault numbers are incremented in this process.

5.29.3.2 Loop measurands The impedances and angles can be displayed for commissioning. The angle is determined to this effect for the direction decision from an appropriate loop (Table 3). This means that the loop cur-rent and its 90° line-to-line voltage is used for angle determination. Thus, single-phase infeed into UL1E and IL1 cannot result in a plausible angle indication. In case of zero power direction, the powers are specified from the calculated UNE and the calcu-lated IE, and used for angle determination.

Test – Loop Measurands Loop Measurands Primary / secondary values secondary Ohm Degree Phase loop, measured angle Loop 1E: phiRi -- measured resistance R, reactance X R -- X -- Loop 2E: phiRi -- R -- X -- Loop 3E: phiRi -- R -- X -- Loop 12: phiRi -- R -- X -- Loop 23: phiRi -- R -- X -- Loop 31: phiRi -- R -- X -- Zero Power secondary [In,Un] Degree Zero active power, zero active power P0 -- Q0 -- Angle of active and reactive power phiRi -- C → Cancel ←→ Pri/Sec

Changing over between primary and secondary values is possible via the cursor buttons.

Functions


The maximum primary impedance that can be represented amounts to 999 Ω, higher values are specified with this value. The highest secondary impedance amounts 401 Ω.

5.29.3.3 Earth fault test The earth fault test is available to check the correct in-phase connection for the earth fault direc-tion decision in acc. with section 10.3.7.4.1. By means of this test, the criteria normally required for an earth fault ULE≥ 0.6·ULLmax and ULLmin=0.75·Un (see page 89) are invalidated. Upon entry of the password, the criteria are switched off by actuating "set earth fault“ with the <E> button. The test in accordance with 10.3.7.4.1 can now be effected.

Test – Test Earth-Fault Set Earth-Fault EarthFaultMeasurands Weighting factors fp and fu fp -- fu -- secondary [In,Un] Active and reactive power from IEmeas. and UNE P0 -- Q0 -- secondary Un In UNE <Umin IEmeas. <Imin E → Select ←→ Pri/Sec

The earth fault measurands are represented. The earth fault criteria are re-activated on exiting the test menu item or on acknowledging ”Reset earth fault“.

5.29.3.4 Activating and deactivating information blocking A blockage for transfer of signals and measurands for substation control can be activated and deactivated in the test menu item "Information blocking“. This requires the input of a password. In case device tests must be performed, it is useful to prevent the transfer of signals and meas-urands to the substation control. Important:

The information blocking is effective until it is deactivated with this menu item. Remark:

Activation/ deactivation can also be effected via the input “51660 InformationBlockg.“ (5.27). The information blocking is only eliminated if the blockage is inactive both in the test menu and as input.

5.29.3.5 Resetting the fault and grid fault number In the menu item "Reset FltNo. / GrdFlt“, the fault number and the grid fault number are reset upon input of the password and confirmation thereof with <E> (see also section Fehler! Ver-weisquelle konnte nicht gefunden werden.). This may make sense once commissioning tests have been performed.

5.29.3.6 Resetting the statistic values The sums of the deactivated line currents and the counts for activation/deactivation can be set to 0 in this password-protected menu.

Functions


5.29.3.7 Test of inputs The access to the test menu entry “Inputs“ does not require a password. The physical input lev-els which have been detected at present by the protector at the optocoupler inputs are displayed. The status of the virtual inputs vDI is also displayed. The optocoupler levels are represented by “1” for voltage on the optocoupler and “0” for “no voltage at the input”. Thus, a software ”Negation“ which might be configured for the specific optocoupler input is not considered. This display enables a straightforward check versus the anticipated values, e.g. the comparison of the voltage on the terminals with the displayed states.

5.29.3.8 Relay test When the test menu input "Relays" is activated, two options are available:

• Display • Setting.

Access to “ReadOut“ does not require a password. Currently, the activation state of the individ-ual output relays provided by the protection is displayed. According to the displayed state, the actual contact positions can be checked as well. Moreover, it is possible to set the state of the output relays under “Setting“. As this function implies a risk-prone intervention in the method of operation of the overall system, it is protected by password.

! Warning !

When setting the relay state, the switches, devices and the equipment connected to their con-tacts are activated. Before utilization of this test function, all the required measures to avoid dangers (e.g. by switching OFF supply voltages or disconnecting the terminals) must have been made!

! Once the user enters the menu, the protector is deactivated! All relays are switched

off additionally!

Test - Relays First column displays current state of activation PS-CO1 0 1 Second column represents the target state PS-CO2 0 1 PS-CO3 0 PS-CO4 0 PS-AO1 0 PS-AO2 0 PROT-DO1 0 PROT-DO2 0 PROT-DO3 0 PROT-DO4 0 PROT-DO5 0 PROT-DO6 0 PROT-DO7 0 PROT-DO8 0

Select the relay(s) to be activated via the cursor buttons <↑>,<↓>. A first column displays the present activation state of the relays; “0“ means "not activated", “1“ means "activated" (in the example, no relay is activated).

Functions


Subsequently, the target state in the second column can be set via the <→>,<←> buttons. To accept the new state and thus the appropriate relay activation, press the button <E>. The first column indicates the new activation status of the relays. To reset individual relays, follow the same procedure, by entering “0“ for the relay to be acti-vated. If all the activated relays are to be switched off again immediately, the relay menu can be exited via the <C> button. Once the menu has been exited, the original activation state is restored. The protection is ready to operate. After performing the test, this is entered in the event memory.

5.29.3.9 Temperature sensor of board PT100 The temperature sensors (Pt100) connected to the inputs TI1 to TI8 can be checked as regards the current temperature measurand. In contrast to the operating measurand display, each meas-uring location is represented here without processing and in accordance with the terminals X1=TI1/TI11 ...X8=TI8/TI18. Invalid temperatures and non-configured inputs are displayed with “---“.

5.29.3.10 CB test as trial AR and trial TRIP

! Warning !

When performing a trial AR or trial TRIP, the TRIP and CLOSE coil of the circuit-breaker is acti-vated. Before utilization of this test function, all the required measures to avoid dangers (e.g. by switching OFF supply voltages or disconnecting the terminals) must have been made! In this menu, one or two entries are available upon entry of a password

• Trial TRIP • Trial AR (only under certain circumstances)

To check the complete tripping circuit of the circuit-breaker, a trial TRIP can be triggered by means of the button <E> without any further query. In this process, the output relay is acti-vated which is assigned the output command “9280 TRIP final“. The activation period is the minimum operating time set in this output relay. If there is a readiness for AR – this can be recognized by the existence of the menu item "Trial AR“, a trial AR can be performed to check the trip and close circuits of the circuit-breaker. The readiness is subject to the following conditions: • AR is enabled, • No AR blockage is existing and no reclaim time or AR cycle is running. • The circuit breaker must be ready to trip (input signal “CB ready“ is present). • The circuit-breaker must be in ON (and not in OFF position) when the CB position signals are

taken into consideration and enabled. A single TRIP/CLOSE cycle is performed in analogy to an AR start caused by an external signal (see chapter 5.11). The only difference is that tripping is done by use of the device keyboard. Of course, in addition to “9280 TRIP final“, the output commands “9270 TRIP not final“ must be configured to the relay tripping the switch and the “9980 CLOSE by AR“ to another re-lay for the control of the TRIP coil. The TRIP command within the trial AR is effected with the non-final TRIP, as reclosure is intended.

Functions


Fig. 5.29-11 CB tests

After performing the test, this is entered in the event memory and signalled as report.

Important: In case of a trial AR, the duration of the TRIP command or the external AR start is determined by the set minimum operating time of the TRIP relay. It must be selected very carefully so that the relay is not overloaded once the tripping circuit opens (see also 5.20).

5.29.3.11 Resetting the thermal level (overload protection)

! Warning !

Resetting the thermal level may endanger the object to be protected! Resetting may only be per-formed if an object to be protected is present which has been cooled appropriately thermally! In the menu entry "Reset of thermal level“, the level of the thermal replica (overload protection) is set to 0% after entry of the password and confirmation thereof with <E>. This may make sense for test of the overload protection. The level is also reset after exiting the test menu.

5.29.3.12 Setting the overload protection to a thermal level

! Warning !

• The setting to 100% and above results in the immediate tripping of the object to be pro-tected!

• Reducing the thermal level may endanger the object to be protected! This may only be performed if an object to be protected is present which has been cooled appropriately thermally!

In the menu entry "Set thermal level“, the current level of the thermal replica (overload protec-tion) is displayed after entry of the password and confirmation thereof with <E>. Modification for test purposes is possible upon actuation of the <E> button. The preset value is accepted in turn via the <E> button.

9280 TRIP final

CB-Tests

Trial AR 9270 TRIP not final

9980 CLOSE by AR AR cycle runs

AR ready &

Trial TRIP

H

Dx 6

Functions


Test – Set Thermal Level Thermal Level Range of adjustment > 0.0 .. 100.0 % Setting > 9.0 %

The selected level applies also after exiting the test menu. The original level has been overwrit-ten.

5.29.3.13 Overload test with TRIP

! Warning !

Once the level 100% has been reached, tripping is effected immediately! The connection of the TRIP command to the circuit-breaker should be interrupted for this test, except if circuit-breaker actuation has been intended. The overload test permits simplified testing of the thermal replica of the overload protection. Dur-ing this test, all distance and current starts and starting of the power protection are blocked. Thus, overload protection can be tested with higher currents without being prevented by other protection modules. All the relevant measurands appear in the display. Important:

Voltage starts are active during the test, as testing with current is expected.

Test – OverLoad +TRIP primary A I1 <Imin Ineg. <Imin I2 <Imin IEmeas. <Imin I3 <Imin IEcalc <Imin Remain.Time Thermal TRIP min:s -- Thermal Level % 0.0 Safe Reclose min:s -- C → Cancel ←→ Pri/Sec

Functions


5.29.3.14 Telegram test

! Warning !

When signals are sent via the system interface, the substation control equipment will receive the sent information. This might trip switching operations! These in turn may result in death, injuries or material damage! Before using this test function, all the required measures to avoid hazards must have been taken!

For start-up in conjunction with telecontrol and control equipment, the targeted sending of tele-grams generated in the protection device is useful. This is based on the control system telegrams in acc. with IEC 60870-5-103 implemented by the protection firmware, including the private area. After entry into the menu item "telegram test", selection is possible between

• the telegrams "Only Selected" used in accordance with the protection setting, and • all existing "Each Telegram" and • “Each Telegram automatically“.

The required telegram group can be selected in accordance with the device functions by means of the <→> button from the overview appearing under the first two subitems. Within the group, the individual telegram is selected via the <E> button. All the information important for the connected devices (function type, information number, requiring general interrogation) are repre-sented for the selected telegram. The <E> button is used for sending. The arrow buttons can be used for quick change to the next item.

Test – Each Telegram FUN DD6 general INF Software-Restart Interprocess-Interface FUN 1 INF 1 Systeminterface T103 Message Device Internal 2007-Sep-13 17:57:06,924 Software-Restart Transmit? <E>/<C> ↑↓ Select next/prev.

In case of automatic sending, all telegrams are sent successively. To cancel, actuate the <C> button.

5.29.3.15 Software Reset If access to a protection device is not possible or if the protection does not operate correctly and restart of protection (to be effected in the "Protection system main menu") did not prove suc-cessful, a software reset can be tripped. The device's protection part is initialized. While it is pre-sent, the protector for the substation control enters into malfunction state with subsequent re-start. The setting set is preserved and remains active.

Functions


Important: A software reset clears the event memory, the fault data, the fault and grid fault number, the thermal level and the LED with the report.

After the password has been entered, a restart or software reset are performed automatically. This will take approx. 45 seconds. Performing a "Protection restart“ in the protection system main menu involves normally less dis-turbance, compared to a software reset, i.e. without deleting the event memory, the malfunction and grid fault numbers.

5.29.3.16 Write default

! Warning!

Important setting data is overwritten by the manufacturer’s default values!

This menu entry may only be used by the user in special cases. Such cases may be: • loss of password • firmware update to a new structure version • malfunction state due to the previous application of a wrong protection module

In any case, once the menu items are used, the previous settings are lost and replaced by the standard settings defined by the manufacturer. Subsequently, the settings must be replaced by the project-specific settings!

5.29.3.16.1 Password When the password is lost, this menu item enables the user to resort to the password provided by the manufacturer. To reset the password, the manufacturer’s password must be entered (see page 267). Afterwards, the password is reset to this password provided by the manufacturer.

5.29.3.16.2 Identification The identification of the device is set to the standard defined in the software version. Thus, the user texts are deleted.

5.29.3.16.3 Setting set

! Warning!

Before performing this action, it must be ensured that the protector is separated from the switchgear and the protection of the protected object is not assumed by this protector! The setting data is overwritten by the manufacturer’s default values! It is essential to set the protector anew before using it!

5.29.3.16.4 Menu entry "all“

! Warning!

Before performing this action, it must be ensured that the protector is separated from the switchgear and the protection of the protected object is not assumed by this protector! The setting data is overwritten by the manufacturer’s default values! It is essential to set the protector anew before using it! In case of a firmware update to a new structure version 56xx, in most cases supplementary or other settings and events are used in addition to the previous ones. In this case, the old setting

Functions


set is useless in the new structure version. The other components of the protection setting may also be used. By means of this menu entry, the "Default" setting set defined by the manufacturer in the flash ROM is entered. This means:

• The setting set is useless for application in the system!! • The user texts in the identification are deleted. • The password is reset to the password used for delivery. • The user texts in the identification are deleted.

The protector can only be recommissioned (see chapter 5.2) a new correct setting set has been saved by you.

5.29.4 LED test The operativeness of the LEDs of the control panel is established by pressing the <C> button on the control panel for more than 2 s. All LEDs must be lit. At the same time, the displayed status is not reset.

Functions


5.30 Setting set "Setting set" means the entire information necessary to set the intended protective functions of a digital protector subdivided into the following categories

• Firmware (only for manufacturers and service) • Equipment adaptation • System adaptation • Protection modules • General • Communication and Substation Control

These categories are in turn structured in groups to permit quick reference to the required set-tings.

The following settings and configurations must be made: a) Device functions and appropriate settings b) LED c) Relays d) Virtual digital inputs (to be assigned output commands) e) Inputs (digital inputs) f) Temperature sensor, if a corresponding module is existing

The structuring in categories and group can be found under the settings a) ... f).

The setting set can be prepared directly on the protector, or by means of the PC COMM-3 oper-ating software.

On the device, all protective settings are possible which can also be achieved with the operating software. Thus, the setting can also be performed now and - especially in the far future - without PC. Only the assignment of the user text in the device identification is an exception to this. These can only be selected via the operating software as there is no alphanumeric keyboard.

Important: • For setting by PC and COMM-3 via the LAN interface, the “51630 Remote Setting” in

the menu "Setting set / Setting / Setting values / Comm.+SubstCtrl. / Substation Con-trol“ must be enabled at the protection relay first, as this is a safety-related interface.

• When changes are attempted simultaneously, the modification of the setting at the de-vice has priority over the setting via PC.

Functions


5.30.1 Characteristic Sets In DDx 6, up to four characteristic sets can be used for the categories System adaptation and Protection Modules. Thus, the active settings can be changed depending on the state of the pro-tected equipment, without necessarily executing a complete new parameterisation of the protec-tor. Thus, e.g. the distance protection on a coupling might feature the following characteristic sets:

• 1: Operating mode involving two busbars • 2: Short line • 3: Long line • 4: Transformer.

The settings of the other categories, such as equipment adaptation, general, communication and substation control and of the inputs and outputs apply to all characteristic sets. The change-over of the characteristic sets is possible upon determination of the number in "Equipment adaptation" “230 No.of Character.Sets“ as follows:

Category

Group

Function switch of group “Distance Module”

Setting value of group “Distance Module”

Characteristic set 1 Characteristic set 2

Functions


• via Setting on the protection device in the menu “Setting Set / Setting / Setting Values / Equipment Adaptation / Characteristic Set“ – “232 Characteristic Set “, “233 Charac-teristic Set “, “234 Characteristic Set “: 1 (2, 3 or 4) active, or alternately

• via optocoupler input signal “261 Characteristic Set 1“, “262 Characteristic Set 2“, “263 Characteristic Set 3“ or “264 Characteristic Set 4“.

Which of both possibilities is accessible will be decided on enabling or disabling the selection of characteristic sets through optocouplers “231 CharSetSelectByInput“. Additionally, the characteristic sets can be switched through the substation control interface by commands. The values required to this effect must be enabled previously under“51636 Cmd Char. Set Switch“.

Note: • Activation of a characteristic set via substation control is like a re-parameterization of the

protection device (many settings may be included or omitted), incl. the non-volatile saving of the new state. No protection modules are performed within a period of <200 ms.

• The change of characteristic sets via optocouplers is effected more quickly, as the state need not be saved in the setting set.

The determination whether a change-over of the characteristic sets is admissible while a general start is present can be determined in the menu “Setting Set / Setting / Setting Values / Equip-ment Adaptation / Characteristic Set“ with “235 CSSwitch at GenStart“. Remark:

Only one signal may be active for the change-over of the characteristic set via optocoupler in-puts. In all the other cases, the characteristic set valid so far remains active.

Example: On delivery of the device, the characteristic set 1 is active, and upon commissioning, there is no signal on any input or on more than one input: in this case, the characteristic set 1 remains active. There is one output command available for configuration as return signal of the currently active characteristic set: “271 Char. Set 1 act.“, “272 Char. Set 2 act.“, “273 Char. Set 3 act.“ and “274 Char. Set 4 act.“. Setting: 1. The determination of the number of characteristic sets, the path on which change-over is to

take place and whether change-over is admissible during general starting is effected in the menu “Setting Set / Setting / Setting Values / Equipment Adaptation / Characteristic Set“.

2. If the protector is switched over, selection of the required characteristic set is possible in the same menu.

3. For external change-overs, the required optocoupler inputs must be configured under “Setting Set / Setting / Inputs / Equipment Adaptation / Characteristic Set“.

4. The command "change-over of characteristic set" for the substation control system is en-abled in the menu “Setting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“.

5. The output commands to LED must be selected under “Setting Set / Setting / LED / Equip-ment Adaptation / Characteristic Set“, those to relays under “Setting Set / Setting / Relays / Equipment Adaptation / Characteristic Set“.

6. Any required outputs to the virtual inputs vDI can be configured under “Setting Set / Setting / Cmd.->Inputs (vDI) / Equipment Adaptation / Characteristic Set“. Subsequently, setting of their further utilization is effected under “Setting Set / Setting / Inputs /..“

Functions


5.31 Inputs

5.31.1 Use of digital optocoupler inputs (DI) For the following functions, use of binary input signals via DDx 6 optocoupler inputs is required: • Switch-On Protection (5.8) • Distance stage Z1x, t1x, if control via input (5.5.3.2) • AR (5.11) • Teleprotection (5.12) • DD 6: Earth fault direction decision via external relay (5.7.1) • Earth fault direction decision via external relay (5.16) • Setting and resetting the reclosing lockout (Fehler! Verweisquelle konnte nicht gefunden wer-

den.), exception: to reset the RC lockout of the thermal replica • Circuit-breaker failure protection with external signal (5.21) • External TRIP commands (5.20) • Trip circuit supervision (5.26) • DDEY 6: bypassing the synchrocheck by means of the input signal (5.24.4) • Pulse shaper stage (5.24) • Tripped signal from circuit breaker of fuse voltage transformers (5.29.1.1) • Characteristic set change-over via optocoupler (5.30.1) • Externally requested disturbance data logging (5.28) • Blockage of protection modules (described in the protection modules) • Remote reset LED and report • Test mode • Information blocking • Phase rotation change via input signal The mentioned binary input signals are explained in the description of the protection function (chapter number in brackets) or below.

5.31.1.1 Remote reset LED and report The input “51760 Reset LED LCD“ can be used for remote reset of the LED and the report on the display. Setting: The input configuration is performed via “Setting Set / Setting / Inputs / General / Additionals“.

5.31.1.2 Test mode The input signal “51860 Test Mode“ enables identification of the events as test events, if this signal is active. By plugging the test connector into the appropriate test socket or by changing the test switch over into “Check” position, an input signal should be applied to an optocoupler input configured to this effect. Thus, the events are identified with the cause “Test“ (IEC 60870-5-103). Setting: The input configuration is performed via “Setting Set / Setting / Inputs / General / Additionals“.

5.31.1.3 Information blocking Information blocking is part of the interface functions to the control system (e.g. IEC 60870-5-103). The input signal “51660 InformationBlockg.“ enables the blocking of the output of signals and measured values of the protector to the substation control system. If it is intended for use, the information blocking must be selected as “connected“ (enabled) in the submenu “substation control“ “51637 Information Blocking“; the appropriate optocoupler input must subsequently be configured with this function.

Functions


Setting: 1. The "Information Blocking" for the substation control system is announced in the menu “Set-

ting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“. 2. The input configuration is performed via “Setting Set / Setting / Inputs / Com.+SubstCtrl. /

Substation Control“.

5.31.1.4 Phase rotation change via input signal For special cases, it is possible on principle to also change over the phase rotation via an input. Here, the active level of the input signal effects the change-over to the phase rotation contrary to that which is set under Equipment adaptation / System adaptation “533 Phase rotation“. When right-hand phase rotation is set, a change-over to “561 Left Handed (L132)“ and, with the left-hand phase rotation a change-over to “562 Right Handed (L123)“ is effected. To en-sure the appropriate input is available, “534 Phase Rot. Reversal“ “connected“ must be se-lected under "Equipment adaptation / System adaptation“. The currently active phase rotation can be signalled via output commands “571 Left Handed (L132)“, “572 Right Handed (L123)“

5.31.2 Using virtual inputs (vDI) Virtual inputs enable protector output commands to be provided as inputs. They imply a software feedback without requiring necessarily a wire connection from an output relay to an optocoupler. The 15 existing virtual digital inputs (abbreviated as vDI) can be used like a physical optocoupler input on configuring the inputs. However, the logically gated output commands to be "fed back" must be configured onto this input; to this effect, see sect. 5.32.6. In the state as delivered, no output commands are configured to the vDI. The advantage is the straightforward availability of protection relay states which exist as output commands, for logic gating with further input signals. By means of these virtual inputs and the pulse shaper stage, multi-stage logics incl. changes of the time characteristics can be realized. The maximum processing capability is shown in Fig. 5.25-3, page 192.

5.31.3 Using the "inputs 1...4“ The inputs “51661 Aux. Input 1“, “51662 Aux. Input 2“, “51663 Aux. Input 3“ and “51664 Aux. Input 4“ pertain to the setting category "Communication and substation control“ and are arranged in the group substation control. This already points out their purpose: They are used for the configurable signalling to the substation control. In the communication standard IEC 60870-5-103, they are mentioned in the compatible range with the decimal information numbers 27 to 30. Messages can be assigned to the substation control system “Input x“ in two fundamental ways:

• Configuration of an optocoupler input onto the “Input x“ – thus signalling the external optocoupler signal to substation control, or

• configuration of a virtual input (vDI), to which any output command is assigned – thus signalling the output command to the substation control.

The signals assigned to the inputs x are then transferred with the information number pertaining to the input. The logic gates possible in the configurations are, of course, also active in these signals. Setting: The configuration of the inputs is effected under “Setting Set / Setting / Input / Com.+SubstCtrl./ Substation Control“.

Functions


5.31.4 Processing binary input signals The inputs enable binary signals to be transferred which provide information for the various func-tions from the switchgear, from other protection equipment or even messages regarding virtual digital inputs of the device as such.

During input configuration, the following may be specified: • a pickup time and a reset time, e.g. to suppress disturbances or for slight variations in time

characteristics

ton

toff

ton

Input signal

Output

H

H

t Fig. 5.31-1 Principle of setting the pickup and reset times for digital inputs

• Direct effect or negation of logic input level at the input:

Direct effect: High = voltage on optocoupler Input active (Code: “X“) Low = no voltage Input inactive Negation: High = voltage on optocoupler Input active (Code: “N“) Low = no voltage Input inactive

• Combining several input signals using the logic AND or OR function. If only one input is used

for signal allocation, any logic processing function may be set. A signal negation entered un-der the input will be effective in any case. Examples of the effects for three input signals:

Inputs 1 2 3

Logic AND operation Logic OR operation

inactive inactive inactive inactive inactive active inactive inactive inactive active inactive active inactive inactive active inactive inactive active inactive active active active inactive inactive active active inactive active inactive active inactive active active inactive active active active active active active

• The inputs may be used for several functions at the same time (matrix of inputs and logic sig-

nal functions).

Fig. 5.31-2 Principle of input configuration

Software function

Optocoupler 1 ton / toff

Optocoupler x ton / toff

vDI 1 ton / toff

vDI n ton / toff

≥1

&

Functions


Setting: The configuration of the inputs is performed under ”Setting Set / Setting / Input“.

5.31.5 Recommendations regarding the infeed of the input signals Although the non-linear inputs used feature a very high interference immunity, the interference risk can be reduced additionally by relatively simple measures. The measures to prevent interference due to undesired signals influence on principle the interfer-ence immunity of the optocoupler inputs. An optocoupler input is insensitive to common-mode input variables, but sensitive to differential mode interference (voltage differential). An important aspect is the surface F located between the forward and return wire. The smaller this surface, the lower the possibility of interference injection.

F

F

F F

F

Fig. 5.31-3 Wiring of the inputs, from very bad to very good

The twisted cable is unbeatable regarding interference immunity; a screen is helpful, but not re-quired. Even if the lines are just laid side by side, the risk that a voltage differential occurs is clearly reduced.

Functions


5.31.6 Mathematical preprocessing of temperature inputs (optional) If the optional temperature capture board PT100 is present and temperature sensor connected, including all the required enables (see 5.17), the following of the incoming digitized temperature values can be used for further evaluation

• the MAXIMUM, • the MINIMUM or • the AVERAGE

These mathematical functions are activated via several temperature sensors of the same measur-ing task, not by the time sequence of the temperature measurands of one sensor. If only one temperature sensor is connected for a measuring task, any mathematical function may be set.

Fig. 5.31-4 Principle of configuration of temperature inputs Remark:

Implausible temperatures are not weighted. This also applies to the result of mathematical processing of this temperature with a valid one. Instead, the output command “51273 Warn-ing Pt100 TI“ is activated; an entry in the event memory and a report appear.

Setting:

1. The temperature recording and the individual sensors are enabled in the menu “Setting Set / Setting / Setting Values / Equipment Adaptation / Device Adaptation“.

2. The temperature inputs “665 Temperature 1“, “666 Temperature 2“, “667 Tem-perature 3“, “668 Temperature 4“, “669 Temperature 5“ including the mathemati-cal preprocessing are configured via “Setting Set / Setting / Temp.Sensor TI / Equipment Adaptation / Device Adaptation“.

Module PT100

Maximum Average Minimum

TI 1

TI 8

TI 2

665 Temperature 1

669 Temperature 5

632 Temperature 1

connected H &

666 Temperature 2

667 Temperature 3

668 Temperature 4

633 Temperature 2

connected H

634 Temperature 3

connected H

635 Temperature 4

connected H

636 Temperature 5

connected H

&

&

&

&

Functions


5.32 Data outputs

5.32.1 Operating measurand display The operating measurand display is accessible from the protection system main menu. The fol-lowing appears on the display of the DDx 6: • r.m.s value of currents and voltages incl. the negative sequence system • Active (P) and reactive (Q) power of the individual phases and of the three-phase system

The sign depends on the setting under "Equipment adaptation/transformer adaptation“ “339 P,Q Display“. The physically correct sign can be "inverted" on selection of the setting for the operating measurand display and for signalling to the substation control. This setting does not affect the protective functions,

• Apparent power (S) and cos ϕ • System frequency • Earth fault measurands with the weighting factors and the powers • Secondary values for R and X of the selected fault loop and the angle determined for the di-

rection decision (may deviate from the angle determined from the fault loop) Upon enabling of the thermal replica, the following items are displayed regarding the above-mentioned parameters • thermal level in %, • the residual time anticipated until the 100% level (TRIP command) is reached, assuming the

current remains constant, and • after tripping with the reclosing lockout set, the duration of time until possible reclosing. In the DDEY 6 with enabled synchronizing device (Synchrocheck), a specifically suited meas-urand screen is accessible. Remark:

The differential values of the synchrocheck operating measurand display are only determined during a synchronization request.

Upon enabling temperature acquisition (temperature capturing board PT100 existing), the current temperatures are visualized in °C in accordance with the assignment (configuration) of the sen-sors and the mathematical processing operations on the software measuring connectors "Tem-perature 1" to "Temperature 5". The temperatures present at the individual measuring connec-tors X1=TI1/TI11... X8=TI8/TI18 of the board PT100 can be viewed in the menu “Test /Temp.Sensor TI” and in the operating measurand display of COMM-3. To change over to another part of the list or between indication of the primary and secondary variables, actuate the cursor buttons. After pressing any button on the device panel, the display will be lighted for a short time.

Functions


Measurand Display primary A Ineg – negative sequence current I1 300 Ineg. <Imin IEmeas – measured earth current (transformer IN) I2 300 IEmeas. <Imin IEcal – calculated earth current I3 300 IEcalc <Imin primary kV Uneg - negative system voltage U1E 5.7 Uneg. <Umin U2E 5.7 U3E 5.7 primary kV U12 10.0 US2, UNE or U4 – voltage measured on the transformer U4 U23 10.0 U4 -- UNE calculated displacement voltage U31 10.0 UNE <Umin If the frequency is outside of the measuring range Grid Frequency Hz or if no measurement is effected, 0.000 appears f 50.000 Possible motions using the cursor buttons ↑↓ Pri/Sec ←→ change Page

Measurand Display primary kW kVAr Active and reactive power, phase 1 P1 +1732.0 Q1 +0.0 Active and reactive power, phase 2 P2 +1732.0 Q2 +0.0 Active and reactive power, phase 3 P3 +1732.0 Q3 +0.0 primary kW kVAr Active and reactive power, three-phase system P +5196.0 Q +0.0 primary kVA Apparent power and cos(ϕ) S 5196.0 CosPhi 1.0 Current temperatures in °C Temperat.Acquisition °C for the “software” temperatures 1..5 Temperature 1 +40 configured and pre-processed from Temperature 2 -- temperature sensor inputs of board PT100 Temperature 3 -- Temperature 4 +25 Temperature 5 -2 ↑↓ Pri/Sec ←→ change Page

Functions


Measurand Display Remain.Time Thermal TRIP Overload protection: Remaining time till TRIP for I=constant

min:s --

Level of overload protection Thermal Level Primary and secondary display are identical % 0.0 Reclosing Safe Reclose is possible again within the specified time min:s 0.0 ↑↓ Pri/Sec ←→ change Page

The currents undercutting the setting “18108 Imin = Line dead “ are visualized with "<Imin“. In analogy, "<Umin“ appears if voltages fall below “18208 Umin=min. Voltage“. The power indication as secondary value is an artificial variable. It shows the signed powers Pn and Qn, which are referred to the rated variables, as follows: Three-phase power P:

P=1 appears if current and voltage are in phase in the symmetric system, and In, Un are pre-sent. The indication of P=1 corresponds to the three-phase power √3⋅Un⋅In supplied to the protection relay. In case of Un=100V and In=1A , the secondary three-phase power is 100⋅√3 VA, for In=5A, 500⋅√3 VA results.

Phases P1, P2, P3: In the above-mentioned case (In, Un), the secondary individual powers are also displayed with the value 1. The unit has been selected regarding Pn/3 to indicate that the three-phase power consists of 1/3 of these individual powers.

When secondary currents are displayed, different values for the measured and the calculated IE are normal due to different transformer ratios for earth and phase currents. The following applies (Isn and Ipn are the transformer rated currents):

pnEsnL

snEpnLcalcEmeasE II

IIII

⋅

⋅⋅= 5-41: Correlation of measured to calculated secondary IE

The current load angle in the protected object can be determined mathematically from the indi-cated powers, taking the sign into account:

Sign P Angle ϕ

+ ⎟⎠⎞

⎜⎝⎛=

PQarctanϕ

- ⎟

⎠⎞

⎜⎝⎛+°=

PQarctan180ϕ

5-42: Angle determined from powers P and Q

For commissioning and other special cases, earth fault measuring results in case of error are dis-played on the third operating measurand screen:

Functions


Measurand Display EarthFaultMeasurands Weighting factors fp and fu fp -- fu -- primary kW kVAr Active and reactive power from IE and UNE P0 -- Q0 -- primary kV A UNE <Umin IEmeas. <Imin ↑↓ Pri/Sec ←→ change Page

When the parallel switching device in the DDEY 6 is ON, the ratios between reference voltage of the busbar and the outgoing feeder voltage can be observed. The difference values are only dis-played during a synchronization request.

Measurand Display Synchrocheck kV Outgoing feeder voltage used for synchronization U12 <Umin Synchronization voltage US2 (mostly of the busbar) Usync <Umin Grid Frequency Hz Current frequency of outgoing feeder voltage f <> Current frequency of busbar voltage fsync <> Voltage Difference kV Current frequency of busbar voltage Udiff -- Phase Difference Degree Phase differential of both voltages phidiff -- No synchronization in case of zero voltage U Bypass if the selected side is de-energized, then: active not active Synchron Condition if synchronism conditions are complied with: active not active Status of max. synchronization runtime tsynchmax min:s -- ↑↓ Pri/Sec ←→ change Page

In COMM-3, the operating measurand display is enhanced by additional information, such as state of inputs and outputs: Remark:

As is usual with digital protectors, the operating measurand display is less precise in the case of very low currents (<0.1In) due to digitizing (see measuring ranges in section 3.8.1).

Functions


DDEY 6

5.32.2 Report On the occasion of important events in the protector, a report appears in the lower part of the protection system main menu. Normally, this area is blank. The contents of the reports is adapted to their cause.

Remark: With the exception of the fault location (reactance X), the displayed measurands are secon-dary variables (referred to nominal variables). Displayed X values are primary values.

The following causes exist for reports: • power system (grid) faults (with runtime) • alarms and malfunctions and • switched-off protection device.

Functions


Protection – Main Menu Reset LED/Report > Reset Reclose Lockout Measurand Display Statistic Values Event Memory Clear Events Setting Set Identification Test Protection Restart Date/Time Report (example for Distance TRIP) Change Password Date and time 2007-Mai-02 16:27:27,885 TRIP command by distance zone Z1 after specified time TRIP : Z<Z1 0.012 s started loops and direction result 12,23,31 forward Fault location for loop: primary X value, km and % line length X31: +0.12Ohm 0.2km 0.1% measured currents in L1, L2 and L3 I123: 0.99 0.99 0.99 In Current IE specifying whether calculated or measured IEcalc: 0.00 In

Any existing more detailed information on the report are contained in the event memory. Any alarms and malfunctions existing in parallel appear alternately. On the contrary, the report for power system faults always contains only the last power system fault. A report is cleared:

• by reset LED (first menu entry) if the cause is no longer active, • an existing power system fault report along with the occurrence of a new power system

fault • or in case of alarm when the cause disappears.

5.32.3 Statistic values The protection part of the combination device records some important statistic variables auto-matically. This is, in the individual phases, the total of the current level in primary values present at the time of the TRIP command. This is based on the aperiodic component-corrected r.m.s value of the currents. Moreover, the counters for the number of make and break operations of the circuit-breaker initiated by the device are integrated. Further comprehensive statistic values are available from the substation control system.

Statistic Values Current Sum A I1 12783.0 Current Sum A I2 10359.0 Current Sum A I3 9756.0 Number of CB CLOSE 29 Number of CB OPEN 30 C → Cancel

The common reset of the values is possible

• on the device in the "test" submenu of the protection system main menu • by a substation control command.

Functions


5.32.4 LED Max. 24 LEDs are available to display faults, alarms and malfunctions: The status of the display may be, depending on the configuration of the output command (8.3.1): • OFF • steady light, or • flashing slowly; • updating or • latching.

The latching output commands are displayed until one of the following occurs • a new starting, • a new earth fault, • a reset command, or • manual reset via the item ”Reset LED“ of the menu “Protection system – main menu”.

Updating outputs are displayed as long as the output command is activated.

Fig. 5.32-1 Principle of LED configuration

Numbering starts from "one“ (1) in descending order. A strip which can be inserted from below enables labelling of the LED. It makes sense to provide separate labels, according to "steady light" and "flashing". The output command appearing by steady light can be located on the left, and the flashing command on the right.

A template file for Microsoft Word for Windows (SPRECON-E-P-D LED.dot) is provided together with the operating software COMM-3. Using this template, the insertable strips can be created very easily. Each of the LEDs can be assigned to several output functions. The assignment procedure is ex-plained in section 8.3.1. Important:

When configuring the LEDs, note that the flashing light is the dominating one. Two (or more) functions can be assigned to one LED simultaneously, if: 1. the data outputs can never appear at the same time, or 2. the flashing output command has a higher priority compared to the steady light command.

Example of an LED assignment: re 2. Display of overcurrent starting, which is of minor importance in case there is a simultane-

ous heavy-current starting as steady-light output, whereas the heavy-current starting is displayed in the flashing mode. “IE>> starting“ flashing and “IE> starting“ as steady light.

Setting: The configuration of the inputs is performed under “Setting Set / Setting / LED“.

≥1 Output command 1

Output command n

LED

- not on LED - updating - latching - steady light

- flashing - not on LED - updating - latching

Functions


5.32.5 Relays The DDx 6 disposes, for the protection part, of four command output relays, identified with “CO“, and ten signalling relays, identified with “DO“ and “AO“. The switching capabilities can be found in section 3.4. Other designations for "command output relay" are "command relay" and "switching relay". For each relay output, a

• minimum operating time and • logic operation

can be selected. The relay in question is actuated for the specified minimum time, i.e. an activation pulse shorter than the minimum operating time results in pickup of the relay at least with the duration of the minimum operating time. This is necessary so that, after issuing the signal - e.g. to the circuit-breaker - interruption of a high-intensity inductive D.C. circuit by external commands (auxiliary contact of circuit-breaker) is enabled. The functions ”AND“ and “OR“ are available as logic operations linking several output commands to one relay. The effect of the “AND/OR“ function has been described in chapter 5.31.4 under the input configuration. Moreover, each output command may also be used with a negative sign.

Fig. 5.32-2 Principle of the combinatory logic for the configuration of the output relays All relays are freely programmable; more than one function can be assigned to each relay. De-fault programming of the CO1 relay is that of the TRIP relay.

Remark: When ”AR“ is used, the final and non-final TRIP must be configured onto the TRIP command relay.

Relay configuration is explained in chapter 8.3.2. For relay labelling and terminals, refer to the connection diagram (Appendix 8). In Appendix 11, the different assignment functions used for trip and signal relays ("Output commands") are listed. Important:

Consider the breaking capacity of the relays used, especially in case inductances in a DC circuit are cut off. Trip coils should be cut off by auxiliary contacts of the circuit breaker.

A minimum operating time must be set for output commands which may involve physically an excessively short activation of the relays.

Setting: Configuration of the relays is performed under “Setting Set / Setting / Relays“.

Output command 1

Output command n

Minimum hold time Relays

≥1

&

Functions


5.32.6 Virtual digital inputs (vDI) On delivery of the device, no function has been assigned so far to the virtual digital inputs al-ready mentioned in chapter 5.31.2, page 228. To fulfil their task to provide output commands as binary inputs, the output command(s) must be assigned to the vDI. This is realized via the con-figuration “Cmd.->Inputs (vDI)“ in the menu “Setting Set / Setting / Cmd.->Inputs (vDI) / Com.+SubstCtrl./ Substation Control“. The output commands can be routed to the virtual input using the following logic operations: The scope of logic operations comprises

• NEGATION • AND • OR

whose effect has been explained in section 5.31.4. The negation is performed before the AND/OR operation.

Fig. 5.32-3 Principle of the combinatory logic for the configuration of the vDI Chapter 8.3.3 explains in greater detail how the configuration is performed on the device. Setting: The configuration of the virtual inputs is effected under “Setting Set / Setting / Cmd.->Inputs (vDI)“.

Output command 1

Output command n

vDI

≥1

&

Functions


5.33 Remote Parameterization When the operating software COMM-3 is used and a connection established to the protector, e.g. via the LAN interface or a modem, remote control is possible on principle. This involves readout of the setting, the events, disturbance data and measurands, as well as of the setting. For safety reasons, however, remote parameterization is only possible upon enabling: “51630 Remote Setting“ at the protection relay first. This setting is not possible by COMM-3! Setting: Remote parameterization is enabled in the menu “Setting Set / Setting / Setting Values / Com.+SubstCtrl. / Substation Control“.

5.34 Real-time clock, time synchronization Date and time are provided by the protector through the substation control part. Synchronization is effected in the ways existing there. For the exceptional case that no time specifications are provided by the substation control, the device includes a clock circuit which provides the protector with date/time with a resolution of seconds in case the protector is activated. The real time clock IC detects automatically a leap year, but it does not switch over between summer (daylight saving) time and normal time. This hardware real time clock runs additionally to the software clock operated by the microcon-troller. The last one is used for the time regime and the time marking of the events in millisec-onds. A back-up capacitor ensures that date/time in the real-time clock (RTC) is continued for several days without supply voltage. Date and time can be set in the protection system main menu if no time is provided by the sub-station control and if the real-time clock has lost the information. Setting: Date and time can be set in the protection system main menu "Date/Time".

Assembly and connection


6 Assembly and connection

Proper transport and storage, expert mounting and terminal connection are prerequisites for a re-liable operation of the device. Appropriate instructions are included in the User's Manual.

! Warning !

The general installation and safety regulations for operations at power installations, e.g., DIN VDE, EN, IEC, BGV A3 and other provisions applicable at national and international level must be complied with. Negligence of the relevant instructions may result in serious damages and physi-cal injuries (possibly death).

6.1 Unpacking the devices The devices are delivered in a cardboard box. The packing material is recyclable; however, it should be stored and used for returning the device in case of a claim. This manual (and possibly the included updated terminal diagram) informs you on the configuration options and on the re-quired wiring. The terminal diagram for system connection has to be user-specified according to device programming and configuration for each individual case.

6.2 Device identification Please, check whether the device type and the reference number correspond exactly to the or-der. This information can be found on the packaging and the rating plate. For detailed information on rated current, rated voltage and the required auxiliary voltage Uaux, please refer to the protection module PROT. The rated current of 1 or 5 A is selected via connection to the corresponding terminals. As re-gards the measuring-circuit voltages, the inputs can be subjected to the corresponding rated voltages (section 3.3). Each device has its own serial number under which the test data is stored at the manufacturer’s during production. In addition, the rating plate contains the following information essential for the protector: • Structure version (of the firmware) - Important information! • Hardware version • Software version (firmware) This information is displayed via LCD in the protection system main menu under item “Identifica-tion” (refer to section 9.4, page 272).

6.3 Requirements regarding the installation location The protectors are designed and manufactured according to the requirements of the standards EN 60255-6 (IEC 60255-6) and DIN VDE 57435 part 303 (9/84). The ambient conditions prevail-ing at the physical location must comply with the parameters based on the relevant standard. These conditions are listed in chapter 3.2 and correspond at least to those of these provisions. It is essential to ensure that the relative humidity does not result, under any circumstances, in moisture condensation or ice formation, and that the ambient air is not considerably polluted by dust, smoke, gases, vapours or salt. The usual EMV measures for the reduction of the transient overloads should be carried out in the high-voltage installation.

6.4 Assembly Dimensions of the housing and of the securing system are provided in Appendix 2, page 301, for panel surface mounting and with detached HMI control panel, in Appendix 3 with attached con-trol panel, or in Appendix 4 for switchgear installation. This should permit straightforward as-sembly. This should permit straightforward assembly with considering the minimum distances according to Safety & Installation Reference (document 94.2.903.30). The most important dis-tances are shown in Fig. 6.5-1



6.5 Connection of the device

! The explanations according to the leaflet “Safety and Installation Guide“ included in

the packaging shall apply. The protectors shall be connected in the zero-current and zero-voltage state, i.e., for systems be-ing in operation, the secondary circuit of the current transformer must be short-circuited, and the voltage transformer circuits must be disconnected. Auxiliary voltage must also be switched off or disconnected. Connections and start-up of the protective devices must be accomplished by qualified personnel. In this context, the relevant instructions for electrical installations (e.g. VDE) and labour safety instructions (e.g. BGV A3) have to be observed.

The compiled connection diagram for the protection part of the DDx 6 can be found on page 306 (Appendix 8). The connectors are allocated to the two modules “PROT“ and ”PS“, whose de-tailed connection diagrams are shown in Appendix 7.

The optocoupler inputs and the freely selectable contact outputs have to be connected according to the desired operating mode. When configuring the device, the user shall define the input and output assignment.

Important: The terminals may not be exposed to any tensile load by the attached cable. Therefore the wiring harness must be fastened strain-relieved at the device!

Fig. 6.5-1 Eyelet fastener for cables on the front plates

6.5.1 Connecting the Control Panel The Control Panel (CP) has to be connected to the Central Unit in accordance with Fig. 6.5-2 with the connection marked "CP" on the CPU. Connection to an operating Central Unit is al-lowed.



Fig. 6.5-2 Connection of Control Panel to Central Unit

Important: • The cables used for the connection between CP and CPU are identical to the cables used

for Ethernet–LAN. The electrical characteristic is, however, different. To avoid distur-bances in the protection devices and networks, Ethernet LAN networks may be not con-nected with the connection marked with “CP“ and on the other hand the Control Panel be not connected with a LAN connection!

• The Terminal at the Control Panel marked with "LAN" may not get connected. It serves service purposes.

6.5.2 Connection to transformers' secondary circuits

! The current terminals are not pluggable; the two lateral securing bolts must not be re-

leased! Before working on the current terminals, the current transformers must be short-circuited externally! For connection examples regarding the current and voltage inputs, refer to Appendix 9. Usually, copper cables having a cross section of 2.5 mm2 - 4 mm² are suitable as connecting ca-bles between the current transformer and the protective relays. The load impedance of the main transformers (especially in the case of In=5A) requires a larger cross section of cables, if dis-tances are longer. A wire protection is required for the phases. As only small resistive residual currents have to be evaluated during the wattmetric earth fault di-rection detection, a cable-type current transformer must be used. The wrong current flowing in the metallic sheath of the cable must be returned to the earth in the inverse direction and thus be compensated, if it is comprised by the cable-type current transformer. This is shown in Fig. 11.2-1.

For voltage transformer terminals, copper cables of 1.5 mm² are usually sufficient. If very long cables are used, the cross section should be increased so that the voltage drop does not exceed the permissible value.

Remark: The connection of the voltage transformers in a V circuit is not possible for the DDx 6!

Important:

Observance of the instrument transformer's connecting polarity is essential to guarantee a correct functioning. Disturbance voltage interference has to be minimised by appropriate measures, since the pro-tector analyses relatively low voltages in some cases.

L I N K X 4

CPU 7 S E R V L A N 1 CP X 6

R T R

A C T X 5 T

R T

T

L A N 2 L I N K A C T X 3

X 2 R

R T R

X 1 T P 7 STAT Z Z

1 X 12

3 1

10 X 2 3 1

X 9 X 8

2 2 3

PROT 5

78

6

2

43

1

2 1

1

1 X 7 X 6

2 3 2 1 1 X 5 X 4 2

X 11 2

2 1 1

X 3 X 2 2 2 1 10 9

X 1

F

6 X21

3 5 4 2 1

F F

1

DIU 10 C 4

2 X 6 X 7 2

3 1 3

X 5 3 1 2

X 2 2 X 3

X 4 1 3 2 3 6 1 5 4 5 1 2 3 6

X 1 4 3 1 2 C

1

DIU 10 C 4

2 X 6 X 7 2

3 1 3

X 5 3 1 2

X 2 2 X 3

X 4 1 3 2 3 6 1 5 4 5 1 2 3 6

X 1 4 3 1 2 C

1

PS PS - DIU 10 C 4 X 5

2 X 1 6 X 1 7 2

3 1

2 3 1 3

X 1 5 3 1 2

X 1 2 T

X 4

X 3 R 2 X 1 3

X 1 4 1 3 2 3

3 2 1 6 1 5 4 X 2

X 1 5 5

1 2 3 6

1 2 3 6

X 1 1 4 3 1 2

4 3 1 2

S C

max . 10 m

Central Unit Control Panelrear view

fixed address: “1”

SPRECON LAN(CCP)

Connection cable, e.g. STB360P-10



6.5.3 Connection of the signal circuits Copper cables having a cross section of 1.5 mm² are sufficient to connect the binary signal in-puts and the signal circuits. The same cables are usually sufficient for tripping circuits. In case of low control voltages and long cables, the cross section has to be increased, if necessary.

6.5.4 PE conductor The marked earthing terminal on the central bottom side of the casing should be connected with protective earth. The connections should be of low resistance and low inductance, which can be achieved via a ground or earthing strip. The quality of this earthing considerably influences the interference immunity of the device. The conductor cross section must not fall below 4 mm². Connector X5-3 of the power supply module PS must also be connected to protective earth. The conductor cross section must be selected according to the national standards, but must not be smaller than 1.5 mm².

6.5.5 Isolation Once wiring has been completed, it should be checked whether the insulation resistance of the equipment is sufficiently high.

6.6 Connection of a PC Important:

The service interface “SERV“ of the CPU board is not electrically isolated. For safety reasons, permanent connection of devices is not admissible.

A PC or laptop can be connected to the serial interfaces in acc. with RS 232C = ITU-V.24/V.28 on the CPU board

• service interface “SERV“ (RJ45 socket) or better, if available, • X4 – Sub-D connector on the power supply module PS.

Important:

Simultaneous utilization of the service interfaces SERV on CPU9 and X4 on PS is not possible. The connector on X4 is preferable due to electric isolation.

The cables required to this effect can be purchased.

Connection to the "LAN“ – RJ45 Ethernet interface of the CPU board is also possible. Should parameterization be effected via this interface (PC with COMM-3), remote parameterization should be enabled previously for safety reasons in the menu “Setting Set / Setting / Setting Val-ues / Com.+SubstCtrl./ Substation Control“.

6.7 Connection of telecontrol and substation control systems Numerous options of connection to the Sprecher Automation control system are available, using other available data transmission protocols, and using many other remote control and substation control units. The appropriate specifications are realized in the order process and during device configuration. This also includes the definition of the interface on the CPU9 board. This may be realized physically as RS485, fibre optics or RJ45. Remark:

The RS485 interface features a Sub-D socket, and can thus be distinguished from an RS232 interface with Sub-D connector.

Operation of the protection device


7 Operation of the protection device

7.1 Control panel According to the network operator’s requirements, each digital protection relay has to be pro-vided with a local operation option which provides the full scope of operating features without using a PC for assistance. The DDx 6 features a control panel which, apart from the graphic display and the LEDs, com-prises a membrane keyboard equipped with function and cursor buttons for input and selection. This provides both unlimited operation of the protector and direct communication. The menu guidance - starting from the "protection system main menu" in plain text - permits straightfor-ward and clear execution of all operations regarding the protection part. The display of settings and events is directly accessible; settings or the protection function can be changed subject to password protection. Important protection information is automatically displayed as report. The control unit has been described in Appendix 6, page 304.

The screen change button must be actuated to get to the "Protection system main menu". For further button allocation, see Appendix 13, page 413. The assignment of functions to the function buttons <F1>, <F2>, <F3> is effected according to customer’s requirement on project planning of the substation control part. The graphic LCD display ensures local menu guidance via the control panel. On the control page, selected operating measurands can be displayed in the scope of project planning. Moreover, the report can also be issued. The reports are displayed in any case on the screen “Protection system main menu“ (see chapter 5.32.2). From here, access to the event memory of the protection part and the operating meas-urands is possible. The LCD is lit during operation.

7.2 PC-aided operator control The PC enables the protective device to be operated in a more comfortable fashion. It provides a better overview of all possible settings and configurations. Programming can be accomplished more quickly and reliably. Malfunction protocols can on principle only be read via the PC or sub-station control.

Remark: • The unrestricted usability of the protector via the serial interfaces requires not only that

the settings of interfaces and addresses are made correctly, but also that no settings are made on the device’s control panel! While settings are being performed on the control panel, no commands or parameters are accepted through the serial interfaces.

• For setting via PC and COMM-3 via the LAN interface, the remote parameterization in the menu “Setting Set / Setting / Setting Values / Com.+SubstCtrl./ Substation Control“ must be enabled, as this is a safety-related interface.

7.2.1 Interface The PC is connected on the front side of the CPU board by means of special cables on the RJ45 socket identified with "SERV“. If the RS232 service interface X4 is provided on the power sup-ply module PS, it should be used to establish the connection. The settings of the baudrate and the parity check for this interface are effected in the menu "Setting set / Setting / Setting values / Comm.+Subst.Ctrl. / Characteristic setx / Communication“. The selection of the serial interface parameter is: 9600, 19200, 38400 or 57600 baud, 8 data bits, 1 stop bit, even / no parity. The parity check to even "8E1“ is preferable. These parameters have to be set identically in the device and on the PC.

Operation of the protection device


The network can also be connected via the Ethernet interface X4. The IP address and the ports selected in the scope of device project planning for substation control must be entered in the de-vice database of COMM-3 to enable communication.

7.2.2 COMM-3 operating software For the digital EAW D...2 to D...6 protection devices, an operating software COMM-3 is avail-able, which runs under Microsoft operating systems Windows 98, Me, 2000, XP and Vista. This program is used for preparation of the setting in the office, data transmission for protection and storing and archiving of the data by the protection engineer. The relay setting and the event or disturbance data memory can be read out and transferred to the PC. Moreover, it is possible to view, record and print operating measurands and the current states of the binary inputs, LEDs and relays. The settings can be saved as XML file for external use, e.g. as test device. COMM-3 also enables a modem to be included for transmission via telephone lines. The SDA 2 graphic program enables the variables and the digital signals / starting messages to be displayed. In addition, the COMTRADE format (IEEE Standard 1991) is used as an interface for data transfer. Up to 64 analogue and 32 digital channels can be transferred and viewed via the COMTRADE file. Evaluation is effected via statistics functions and the Fourier analysis.

Setting


8 Setting Setting of a protector is divided into several sections: 1. Function switches and settings 2. LED configuration 3. Relay configuration 4. Configuration of the virtual digital inputs vDI and 5. Input configuration

This type of structuring the setting process permits the use of the "function switch" - item 1. Thus, at least two alternative ways are available from each branching point of the menu. This tree is branched into depth in order to realize all the required functions. The decisive advantage of this type of setting is the automatic suppression of the settings of non-relevant submenus, settings and input or output commands. This helps to reduce the number of accessible settings. The operator only needs to handle all the remaining input options.

Example for a function switch: IL> Start 1100Choice between the alternatives “blocked“ and "enabled" is possible enabled

Important: • The function switch principle being used sets priorities for the time sequence of the opera-

tions for editing the above-mentioned setting items. Item 1 must be processed first of all. • Within the function switches, the categories and groups should be completed top-to-bottom. • Before configuring the inputs and outputs, the function switches and settings must be set

first in any case, i.e. setting item 1. Otherwise, possibly necessary settings are no longer accessible, as they are still switched off by the higher-ranking switches.

• The settings under 2. to 5. have the same priority, so that their sequence is optional. • While a setting is made on the protector, setting via the COMM-3 operating software is not

possible. Local setting has priority. The protector is adjusted via the keyboard and the LCD display or the PC operating software COMM-3. Below, please find an explanation of the operations to be effected directly on the de-vice. The starting point for the settings described in this chapter is the “Protection – Main Menu“,

which is accessible by actuating the button : Access to the settings is effected via the entry “Setting set”. The latter is selected via the <↓> button and then opened by actuation of the button <E> or <→>:

Protection – Main Menu Reset LED/Report Reset Reclose Lockout Measurand Display Statistic Values Event Memory Clear Events Access to the settings of the protection part Setting Set > Identification Test Protection Restart Date/Time Change Password

The subsequent prompt “Display“ or “Setting“ must be answered with ”Setting“. Input of the password is effected by scrolling the individual digits using the buttons <↑><↓> until the re-

Setting


quired digit is reached. The digit item is selected via the <→><←> buttons. Once the <E> button has been actuated, the user is within the menu which contains the above-mentioned five items.

Setting Set – Setting Direct access to a setting via address Addressed Value Function switches and settings Setting Values > LED output configuration LED Relay output configuration Relays Output configuration of the virtual inputs Cmd.->Inputs (vDI) Input configuration Inputs Configuration of temperature sensors – if present Temp.Sensor TI

If only one specific setting is to be changed whose address is known, the first menu entry can be used. After input of the address via the cursor buttons and confirmation via <E>, the user gets directly to this setting. In other cases, “Settings“ would have to be selected first:

Setting Set – Setting Setting Values Firmware Equipment Adaptation > Setting set categories System Adaptation Protection Modules General Com.+SubstCtrl.

The setting set categories are made available at choice. They include the setting set groups (5.30). Firmware adaptation has been effected by the manufacturer according to the device equipment. You are not capable of performing other changes. The following example shows the groups pertaining to the equipment adaptation:

Setting


Setting Set – Setting Setting Values Equipment Adaptation Characteristic Set1 Device Adaptation Setting set groups CB Adaptation Transf. Adaptation > Characteristic Set

After selecting the characteristic set to be adjusted (if further characteristic sets have been en-abled) and the required group to be set, the settings are visible in a list. From this list, the func-tion switch or value to be changed can be selected via the cursor buttons <↑><↓>; subse-quently, it can be called up for editing after acknowledgement via <E> or <→>.

Setting Set – Setting Setting Values “Path specification”, i.e. present location Equipment Adaptation Characteristic Set1 Transf. Adaptation Setting value In CT prim. IL Address of this setting value ValIdentAdr 301 Admissible value range with unit > 2 .. 6000 A Current setting with variation option > 300 A Remark: Cursor is negative

The value of the individual digits can be varied by scrolling via the buttons <↑><↓>. Each digit can be reached via the buttons <→><←>. Once setting is finished, this is confirmed by actu-ating the button <E> or cancelled by actuating the button <C>.

To change over between the alternatives of a function switch, change over by means of the but-tons <↑><↓>. The correct option is selected via the button <E>.

Setting Set – Setting Setting Values Equipment Adaptation Characteristic Set1 Transf. Adaptation In CT sec. IL Function switch providing for two alternatives ValIdentAdr 330 In = 1 A In = 5 A

Exiting the menu is possible at any point pressing the <C> button. Important

Each required change of the protection setting must be saved in the PROM. On leaving the setting menu via the <C> button, the following prompts appear before the setting are exited:

Setting


Setting Set – Setting Changes Accept Continue Edit Reject

Once the correct option has been selected and confirmed by pressing (<E>), the settings are complete. When the new values are transferred, they are saved in the PROM and be-come effective. If the change is discarded, the settings in the PROM remain unchanged.

In addition to the settings mentioned above, date and time plus the password can be changed. Access is effected directly in the “Protection system main menu”. The device identification can only be adjusted via COMM-3 as regards the user text fields.

Important: • For setting by PC and COMM-3 via the LAN interface, the “51630 Remote Setting” in

the menu "Setting set / Setting / Setting values / Comm.+SubstCtrl. / Substation Con-trol“ must be enabled at the protection relay first, as this is a safety-related interface.

8.1 Overview of the available submenus for protector setting The setting is structured in accordance with categories and groups as specified under 5.30. This structure applies to the settings and function switches as well as to the inputs and outputs. Regarding the inputs and outputs, a change-over of the settings including the characteristic sets does not make sense and thus has not been provided. The individual submenus are listed up and described in the following. Other menu items of the protection system main menu which are not listed here do not contain any settings.

Setting


1st menu level Main menu

2nd menu level 3rd menu level Categories

4th menu level Groups

5th menu level Settings

Addressed Value ⇒ Direct access

Setting Values Firmware Firmware Adaptation only for manufac-turer

LED Equipment Adaptation Relays CB Adaptation Cmd.->Inputs(vDI) Transf. Adaptation Inputs

Equipment Adapta-tion

Characteristic Set

valid for all charac-teristic sets

Temp.Sensor TI System Adaptation System Adaptation Measurand Check Direction Decision Dist (U-) I Start Z<Start Loop Determination Distance Module Earthfault Detection Reclose Lockout IL> (Emerg.) OTP IE> (Emerg.) OTP Switch-On Protection Negative Sequence I Inrush Restraint Auto-Reclose (AR) Teleprotection Voltage Protection Frequency Protection Power Protection Overload Protection CB TRIP CBFailure Protection Fault Location Synchrocheck Synchrocheck AR Current Annunciation Pulse Shaping

Protection Modules

Temperature Protection

selectable per characteristic set

Alarm/Malfunction Device On/Off Relays Optocoupler Virtual Inputs Disturbance Record

General

Additionals Communication

Setting Set

Com.+SubstCtrl. Substation Control

valid for all characteristic sets

Identification No customer setting possible no device, user text only via COMM-3 Date/Time Date/Time ReadOut Date/Time Setting Change Password Change Password

Setting


8.2 Settings

8.2.1 Category “Firmware adaptation“ This submenu is intended for the manufacturer or for the service. Users cannot access this menu. Here, settings regarding the hardware equipment are made.

8.2.2 Category “Equipment adaptation“ In the menus of the “Equipment adaptation“, the settings are made which concern the object to be protected. These important settings are specified in Appendix 11 Table 10 (page 310).

8.2.2.1 Device Adaptation: Temperature recording If the protector has a temperature acquisition module with connected sensors, which are to be used for temperature protection (5.17), connection thereof must also be indicated.

8.2.2.2 CB Adaptation: CB manual CLOSE and CB CLOSE issued by substation control If it is intended to provide a CB manual close signal, this must be stated. The circuit-breaker’s manual close signal is required for the protection modules Switch-On Protection (5.8) and AR (5.11). The behaviour of the protector is changed in case of manual close.

It can be picked up directly on the CLOSE coil of the switch. CLOSE commands during an AR cy-cle are not considered as “manual close”. The CB manual close signal can also be transferred without external wiring from the control sec-tion of the DDx 6. To this effect, the software coupling “51638 CB Close from SCADA“ must be enabled by “yes“ in the category "Comm.+SubstCtrl.", group "Substation Control". The only disadvantages are

• the possible non-detection of closing procedures which are not performed via the protec-tor and

• this signal can only be activated by the CB with the smallest node number (e.g. Q0 01.-01) in the control system setting.

8.2.2.3 CB Adaptation: CB ready to trip and CB tripping alarm inter-rupted The AR (5.11) requires the CB’s “ready” signal for an AR cycle (TRIP-CLOSE-TRIP). If the AR is used, the connection must be effected and specified. If during an active auto-reclose with a non-final CB TRIP, the message “breaker tripping” to the station is to be interrupted, this intention must also be specified in the submenu “CB adaptation”.

8.2.2.4 CB Adaptation: Trip circuit supervision To monitor the trip circuit for continuity and the presence of auxiliary voltage, one or preferably two binary inputs (optocoupler inputs) can be used “434 TripCircuitSupervision“ (5.26). The timer “411 t TripCircuitSuperv.“ is used to hide the transitions - inevitable during switching operations - and thus short-time false alarms. If necessary, blockage of this function can be selected, which enables the input to be wired ac-cordingly.

8.2.2.5 Transformer adaptation: Rated currents and rated voltages The current values in DDx 6 are referred to rated current, so that for a correct functioning and for correct measurand displays primary and secondary rated currents must be displayed.

Phase current transformers and - in the devices DDE(Y) 6 - an additional earth current trans-former are present. The latter is only required for the earth fault direction decision. It must be

Setting


connected to a cable-type current transformer which mostly has a primary rated current diverging from the phase current transformers.

The distance protection features three terminals per current path, which can be used to realize two different secondary rated currents by means of one device transformer. The terminals must be connected according to the required rated current.

For the current transformer, the analogue data must be entered, which are of equal importance. The DDEY 6 has a fourth voltage transformer used for synchronization. Alternatively, it can be used on the open delta winding to measure the displacement voltage. Thus, its nominal values can be selected separately.

8.2.2.6 Transformer adaptation: Current transformer earthing Indicating the position of the current transformers’ earthing is – separately for phase and earth current transformers – decisive for the direction decision. Changing over between the alterna-tives “line end” and “busbar end” results in a change of the current's phase position by 180° in comparison to the last state, and consequently in a change of direction. If during this start-up test, a wrong direction is signalled for all cases of errors, the direction can be changed via this function switch.

IL1

IL2

IL3

L1

L2

L3 PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-3

1A

5A

1A

5A

1A

5A

DD 6

P1

P2

S1

S2

line-sided

IL1

IL2

IL3

L1

L2

L3PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-3

1A

5A

1A

5A

1A

5A

DD 6

P2

P1 S1

S2

busbar-sided

Fig. 8.2-1 Current transformer earthing on line end - busbar end

8.2.2.7 Transformer adaptation: fuse voltage transformer The safest solution to detect a failure of the voltage transformer (and consequently a change-over to emergency overcurrent time protection) consists in using the output contact of the volt-age transformer’s automatic circuit-breaker. The intended use must be specified.

8.2.2.8 Transformer adaptation: P, Q display inverted For the operating measurand display and signalling to the substation control, the physically cor-rect sign can be "inverted" on request, so that a positive display is obtained for the normal line state. To change the displayed sign, set “339 P,Q Display“ to “inverted“. This setting does not affect the protective functions.

8.2.2.9 Transformer adaptation: Using the voltage transformer U4 The fourth voltage transformer existing in the devices DDEY 6 can be used for two purposes:

a) to connect the synchronization voltage, or b) to measure the displacement voltage UNE

The choice must be made under “336 Usage VT4“. If it is used as instrument transformer for the UNE, the user can specify in the protection modules required by each of them whether the measured or the calculated UNE is to be used. This applies to the protection modules

• Measurand check (UNE monitoring) • Direction decision (earth short-circuit fault direction) • Earth fault detection and

Setting


• Voltage check (UNE monitoring).

Moreover, separate settings of the system rated voltage and utilization of a voltage transformer mcb (fuse) can be specified for this transformer.

The setting for measurement of the "displacement voltage UNE“ can also be used in cases when any external voltage U4 is to be monitored for overvoltage by means of the UNE>(>) protection. In this case, the settings must be set to “calculated“ in the other protection modules which require the displacement voltage UNE:

• Measurand check (UNE monitoring) • Earth fault detection and • Direction decision (earth short-circuit fault direction).

Remarks: • To be able to use the synchronization function of the device, selection of a) is manda-

tory. Thus, the reference voltage is provided. • For the displacement voltage UNE, measurement is not required in most cases due to the

relatively high values. Calculation from the phase-to-earth voltages is sufficient. In systems with resistive earthing, e.g., measurement of small UNE may result in slightly higher accuracy for the zero power direction decision.

8.2.2.10 Characteristic set: number of characteristic sets and selec-tion thereof Up to four characteristic sets can be used. The appropriate setting is stipulated in the group “Characteristic sets”. If several characteristic sets are used, the required one can be activated here. If in deviation from the setting on delivery, the change-over between characteristic sets of the protector is to be effected not locally on the protector or via the substation control, but using op-tocoupler input signals, this must also be specified here. The selected setting “235 CSSwitch at GenStart“ determines whether the characteristic set may be changed over during a general start, or only while no general start is in process.

8.2.3 Category “System adaptation“ All settings of this category can be used differently for each characteristic set used, so that changes of the object to be protected, e.g. the method of neutral connection, can be changed over from isolated to earthed.

8.2.3.1 System neutral The method of neutral connection - earthed, isolated or compensated - must be entered cor-rectly, in order to enable the protection functions adapted to this effect.

8.2.3.2 System adaptation: SDLRE Automatic If a SDLRE automatic is used, it must be entered if the earth short-circuit direction decision is to be used instead of the earth fault direction decision, due to the higher currents and the shorter time available for the decision.

8.2.3.3 System adaptation: Earth factor The earth factor is important for the fault location regarding phase-to-earth faults. If no values are available in extreme cases for the real and the imaginary part, their default set-tings must be left unchanged. This will result in distance measuring errors in case of errors in-volving the earth.

Setting


8.2.3.4 Phase rotation This item enables the adaptation to any left-handed phase sequence which might exist. If the phase sequence is set incorrectly, faults will occur regarding the negative sequence stages and the directional stages! If a change-over of the phase rotation is to be used via an input signal, it must be specified: “534 Phase Rot. Reversal“ “connected“. Subsequently, the required in-put is available for configuration thereof.

8.2.4 Category “Protection modules“ As protection modules, those listed in Appendix 11, Table 12, page 312, are available. They are described in detail in section 5. Remarks:

The function switch principle subdivides the entire protection setting. First, decisions related to protective functions that may be executed in binary form are taken. Then, the settings for the selected remaining protection are entered. Thus, the complete setting of a single protec-tive function is done in several steps. If a protective function that was previously blocked is to be activated, the setting order - starting with Equipment Adaptation and ending with Characteristic sets - has to follow the menu order.

8.2.5 Category “General“

8.2.5.1 Device On/Off The protector can be switched off, respectively switched on via the software. Switching-off blocks all protective functions. The first item of the setting menu of the category “General” is “Device ON/OFF”. Under this item, the function switch can be actuated. Upon confirmation, in case of tripping, the report appears on the protection system main menu:

Protection – Main Menu Reset LED/Report > Reset Reclose Lockout Measurand Display Statistic Values Event Memory Clear Events Setting Set Identification Test Protection Restart Date/Time Change Password Report 2007-Mai-02 16:27:27,885 Protection dead by Operation at device

The report disappears once the protection part is switched on.

8.2.5.2 Relays This menu (menu path: “Setting/Settings/General“) helps assign the features of the output relays

• Logic function, if more than one output command is configured to the relay, and • Minimum operating time

The relay is actuated for the specified minimum operating time (minimum duration) if the output command is accessible for a shorter time. The functions ”AND“ and “OR“ are available as logic operations linking several output commands to one relay.

Remark:

Setting


The same settings are accessible under the output configuration for the relays “Set-ting/Relays“ (see chapter 8.3.2, page 260). They only need be set once in one of the two dia-logs.

8.2.5.3 Optocoupler Here (menu path: “Setting/Settings/General“) helps assign the features of the optocoupler inputs DIx

• Pickup time • Reset time

To suppress unintended signal activations (e.g. bounce, system hum), the pickup and reset times can be selected. On delivery, no pickup and reset delays are set for the optocoupler inputs.

Remark: The same settings are accessible under the input configuration “Setting/inputs“ (see chapter 8.4). They only need be set once in one of the two dialogs.

8.2.5.4 Virtual Inputs In the menu path: “Setting/Settings/General“, the settings of the virtual digital inputs vDI can be defined

• Pickup time • Reset time • Logic function, if more than one output command is to be configured to the vDI

The pickup and reset times can enable signal time offsets to a minor extent. On delivery, both times are set to zero.

Remark: The same settings for the gating logic are accessible under the output configuration for the vDI “Setting/Cmd.->inputs (vDI)“ (see chapter 8.3.3). The pickup and reset times are also accessible under the input configuration “Setting/inputs“ (see chapter 8.4). They only need be set once in one of the dialogs.

8.2.5.5 Disturbance Record For the disturbance record (5.28), the

• Prefault time and • Post-Fault Time

can be set.

8.2.5.6 Moreover: Language switching Here, the setting at the time of delivery, i.e. "German“, can be changed over to "English”.

8.2.6 Category “Communication and Substation Control“

8.2.6.1 Communication

8.2.6.1.1 Baudrate and parity of the RS232 interface “SERV“ The serial RS232 interfaces "SERV“ on the CPU board and, in parallel – if present - the X4 on the PS module, can be set regarding the baudrate “51530 Baudrate Serv. 232“ and parity check “51531 Parity Serv. 232“. The baudrate can be selected between 9600 and 57600 baud, the parity check between even or none. As the parity check provides for enhanced safety, "8,E,1" should be chosen preferably. These parameters have to be selected identically in the de-vice and on the PC.

Setting


8.2.6.1.2 Baudrate and parity of the IEC 60850-5-103 interface The serial fibre optic or RS485 interface on the CPU board which is intended for connection of the substation control, can be set for baudrate and parity check as follows: “51532 Baudrate IEC 103“ and “51533 Parity IEC 103“. The baudrate can be selected between 9600 and 57600 baud, the standardized baudrates being 9600 and 19200. The parity check can be se-lected as "even" or "none". As the parity check provides for enhanced safety, "8,E,1" should be chosen preferably.

8.2.6.1.3 Device address An address “51501 Device Address“ has to be assigned to each relay to establish the com-munication. Default value is the address 1. It is defined for the protection relay in the "Commu-nication" submenu. It can be selected in a range between 1 and 254. Communication to PC or substation control via the interface(s) is only possible under the set address.

8.2.6.2 Substation Control

8.2.6.2.1 Remote setting For enabling any setting operation via LAN interface the “51630 Remote Setting“ must be en-abled at the protection device. Otherwise no setting over Ethernet LAN using COMM-3 is possi-ble.

8.2.6.2.2 Command blocking Commands from substation control equipment influencing the protective function must be per-mitted individually. If the command blocking is active, the command is not executed. Commands are permitted (enabled) in the submenu “substation control“.

8.2.6.2.3 Information blocking “51637 Information Blocking“ is part of the interface functions to the control system (e.g. IEC 60870-5-103). If it is intended for use, it must be selected as “connected“ (enabled) in the submenu “substation control“; the appropriate optocoupler input must subsequently be config-ured with this function. If there is a signal at the optocoupler input, the information blocking prevents the output of mes-sages and measured values from the protector to the control system.

8.2.6.2.4 Transfer of CB Close from the substation control If “51638 CB Close from SCADA“ is selected for “yes“, all ON commands tripped by the con-trol unit of the combination device are transferred to the protector and can provide information for the Switch-On Protection and the AR. This signal can only be activated by the CB with the smallest node number (e.g. Q0 01.-01) in the control system setting.

Setting


8.3 Output Configuration Setting of the device also requires configuration of the output LED, Relays and virtual optocou-plers. They are set in separate menus, as they may obtain various features. Configuration means in this context the assignment (routing) of software functions = "Output commands" to the physical output elements, relays, LED or vDI (this is only virtually a physical output element). The output commands follow the category / group assignment like the function switches and settings. To find an output command, it is important to know which category and group it per-tains to. As there may be ambiguities regarding the assignment, scrolling through all output commands for search and configuration was enabled (<↑><↓> buttons). The path designation reflects the assignment to the category and the group. When configuring the outputs, it must be noted that output commands which are not relevant due to previous decisions related to equipment adaptation and protective functions are not avail-able within the range of output commands offered, and can thus not be configured. The output commands available for configuration of the outputs are compiled in Appendix 11. Table 21, page 384, explains the significance of the signals.

8.3.1 LEDs The 24 LEDs on the left side of the Output command panel are available for configuration. Two features can be assigned to each output command (arrangement in rows): 1. Steady light - shown by "X" or

Flashing slowly - shown by "B". This feature can be selected separately for each LED.

2. Storing (last-up related, latching) – marked “Latched“ or Updating - marked "Non-Latched". This feature can be defined once per output command.

The output commands form the lines and the physical LEDs the columns of a setting matrix. An output command (software function) can be issued to any LED, with the feature ”flashing“ or “steady“ varying. If one LED is configured with two different output commands, i.e. with steady light and flashing light, and both functions are active at the same time, then the flashing light is the dominating one.

Latching output commands are displayed until one of the following occurs: • a new start or earth fault, • a reset command, or • manual reset via the item ”Reset LED“ of the menu “Protection system main menu”. • Updating outputs are displayed as long as the output command is activated. These features can be used to route several output commands to one LED in a way that makes sense. Further instructions concerning the use of LEDs can be found in section 5.32.3, page 237. The list of LED output commands is included in Table 19, page 357.

Setting Set – Setting LED “Path specification”, i.e. present location Equipment Adaptation Transf. Adaptation Output command FuseVoltageTransf. Address of this output command ValIdentAdr 360 Arrow indicates possible cursor directions, LED no. → Latching>Latched<1:X 2: 3:B Remark: Cursor flashing, input field included between > <

Configuration is effected separately for each output command, i.e. each output command can be assigned to one or several of the 24 LEDs. Once the category and group applicable to the output

Setting


command to be configured have been selected and the requested command has been activated via the <E> or <→> button, the user gets to the routing dialog. Each position of the line which comprises 24 LEDs and is thus longer than the display range can be reached via the <→><←> buttons. This feature can be selected in each position via the buttons <↑><↓>. In the example, the output command results in updating LEDs 1 and 3. LED 3 indicates the command as flashing light and LED 1 as steady light. LED 2 is not assigned. If an assignment is to be eliminated, the LED must be selected, then the entry “X“ or “B“ must be changed over into a “blank” entry " " using the <↑><↓> buttons. Once the configuration of the output command to the LED has been completed, the settings must be acknowledged via the button <E> or be discarded via the button <C>. Remark:

Upon completion of the settings, an insertable strip for LED assignment can be created. A template file for Microsoft Word (SPRECON-E-P-D LED.dot) is provided together with the op-erating software COMM-3. Using this template, the insertable strips can be created very easily.

8.3.2 Relays For configuration of the output commands (Table 18, Page 343) to relays, the output relays ac-cessible for the protector are available (see circuit diagram in Appendix 8). Different features can be assigned to relays and LEDs.

1. Minimum operating time 2. Logic operation for the output commands.

The relay is actuated for the specified minimum operating time (minimum duration) if the output command is accessible for a shorter time. The functions ”AND“ and “OR“ are available as logic operations linking several output commands to one relay. Each output command may also be used with a negative sign.

Remark: The same settings are also accessible under "Setting /Setting values /General /Relays“ (see chapter 8.2.5.2, Page 256). They only need be set once in one of the two menus.

All relays are freely programmable; more than one function can be assigned to each relay. De-fault programming of the CO1 relay is that of the TRIP relay.

The minimum operating time is set in the submenu “Minimum operating time“ of the relay con-figuration separately for each individual relay. The value to be set can be varied via the cursor buttons like any other setting. Setting Set – Setting Relays Min. operat. time Setting of minimum operation time for CO1 of module PS Oper. Time PS-CO1 Address of setting value ValIdentAdr 32201 Admissible range of values > 0 .. 500 ms Setting value > 200 ms

The gating logic for the case of several output commands to a relay is defined in the submenu "Logic" of the relay configuration. Two alternatives are available for selection via the cursor but-tons.

Setting


Setting Set – Setting Relays Logic Setting the logic operation for CO1 or module PS Logic PS-CO1 Address of setting value ValIdentAdr 32101 Option 1 and Option 2 or Remark: Cursor makes line appear negative

On delivery of the device, the “OR” function has been preset. Once the minimum operating time and – if necessary – the gating logic per relay has been set, the output commands can be assigned to the relays. There are more relays than can be displayed in the visible line. Thus, the required relay must be selected via the arrow cursor buttons <→>, <←>. For utilization of the output command in conjunction with the selected relay, three states can be selected via the buttons <↑><↓>:

• Not used – field is empty • Use of output command not negated – “X“ • Use of output command negated – “N“

Each output command can be assigned to several relays. Accordingly, a relay can also be as-signed several output commands. Setting Set – Setting Relays “Path specification”, i.e. present location Equipment Adaptation Transf. Adaptation Output command FuseVoltageTransf. Address of this output command ValIdentAdr 360 Arrow indicates possible cursor directions, relay identifier → PS-CO1>X< PS-CO2: Remark: Cursor flashing, input field included between > <

Once the configuration of the output command to the relays has been completed, the settings must be acknowledged via the button <E> or be discarded via the button <C>. Important:

• If "AR" is used, not only “9280 TRIP final“ but also “9270 TRIP not final“ must be configured to the trip relay for the circuit-breaker's TRIP coil.

8.3.3 Assignment of Output Commands to Virtual Digital Inputs (vDI) Virtual inputs enable protector output commands to be provided as inputs. They imply a software feedback without requiring necessarily a wire connection from an output relay to an optocoupler. The virtual digital inputs (abbreviated as vDI) can be used, depending on the output commands assigned to them, like a physical optocoupler input on configuring the inputs. Thus, the use of a vDI requires two steps:

1. configuration of output commands to the vDI - output configuration 2. configuration of the vDI to a software function – input configuration.

The following description refers to the output configuration. The input configuration does not dif-fer from that of “normal” optocoupler inputs (digital inputs). The output configuration is made in the submenu “Cmd.->Inputs (vDI)”.

Setting


A logic operation can be assigned to a virtual input for the case of assignment of several output commands. If only one output command is to be routed to a vDI, the set logic operation is irrele-vant. The required logic function is selected in the first subitem of the setting menu “Logic”. The available vDIs are displayed and the vDI to be set can be selected. Setting Set – Setting Cmd.->Inputs (vDI) Logic Setting of the logic operation for vDI1 Logic Cmd.->vDI1 Address of setting value ValIdentAdr 35101 Option 1 and Option 2 or Remark: Cursor makes line appear negative

Once the required operation is selected, this setting is exited via the <E> button. On delivery of the device, the “OR” function has been preset.

Remark: The logic operation can also be defined under “Setting / Setting values / General / Virtual in-puts“ (chapter 8.2.5.4). It only needs to be set once in one of the dialogs.

An output command is assigned to a virtual digital input by selecting the required output com-mand and by routing it to the vDI. To find the command, the subdivision into category and group applies as in case of all settings. Setting Set – Setting Cmd.->Inputs (vDI) “Path specification”, i.e. present location Equipment Adaptation Transf. Adaptation Output command FuseVoltageTransf. Address of this output command ValIdentAdr 360 Arrow indicates possible cursor directions, vDI no. → 1>N< 2: 3: 4: 5: 6: 7: Remark: Cursor flashing, input field included between > <

Three states can be selected via the buttons <↑>, <↓>: • Not used – field is empty • Use of output command not negated – “X“ • Use of output command negated – “N“

In the example, the negated signal of the fuse voltage transformer has been routed to vDI1. Important:

Since the vDI also exist as an output command, they can be configured on another vDI to reach a multistage logic. A vDI may under no circumstances be configured on itself!

As mentioned above, several logic output commands can be routed to one vDI. To this effect, the further output commands must be routed to the vDI in the same fashion. The selected logic operation becomes effective for this purpose. If a negation of the output commands has been en-tered, this will take effect before the logic operation. In the state as delivered, no output commands are configured on the vDI.

Setting


8.4 Configuration of Digital Inputs (DI) In configuring the inputs, the (software) functions offered can be linked to one or several digital inputs (DI, optocoupler) or virtual digital inputs (vDI). An active signal on the DI or vDI activates the software functions pertaining to it. The input signal can be used additionally in negated form. A negated signal is “low” active. If several inputs are assigned to a function, the logic gating of the inputs – OR or AND - will be active. Moreover, an appropriately configured input can trip several software functions. The software functions follow the category / group assignment like the function switches and settings. To find a function, it is important to know to which category and group it pertains. As there may be ambiguities regarding the assignment, scrolling through all functions for search and configuration was enabled (<↑><↓> buttons). The path designation reflects the assignment to the category and the group. When configuring the inputs, it must be noted that software functions which are not relevant due to previous decisions related to equipment adaptation and protective modules are not avail-able within the range of input commands offered, and can thus not be configured. The functions available for configuration of the inputs are compiled in Appendix 11, Table 15. Table 16, Page 341, explains the significance of the functions. To suppress unintended signal activations (e.g. bounce, system hum), the pickup and reset times can be selected. On delivery, no pickup and reset delays are set for the optocoupler inputs. The virtual inputs are not delivered with a delay either. The setting menu for the inputs is the first submenu entry to contain this setting option: Setting Set – Setting Inputs Pickup Time Pickup time setting for DI1 of the module PS Pickup Time PS-DI1 Address of setting value ValIdentAdr 33201 Admissible range of values > 0 .. 250 ms Setting value > 11 ms

The value to be set can be varied via the cursor buttons like any other setting.

Remark: The same time settings are also accessible under "Setting / Settings / General / Optocoupler“ (see chapter 8.2.5.3) or “Setting / Setting Values / General / Virtual Inputs“ (chapter 8.2.5.4). They only need be set once in one of the dialogs.

After selecting the pickup and reset, the inputs are assigned to the software functions. The line with the 15 optocoupler inputs and the 15 virtual digital inputs is too long to fit into the visual area of the display. Use the arrow buttons <→>, <←> to search the line for the input to be configured. Three states can be selected for an input via the buttons <↑>, <↓>:

• Not used – field is empty • Use of output command not negated – “X“ • Use of output command negated – “N“

Remark: The vDIs are the last inputs to be listed in the line, after the inputs. Regarding the input con-figuration, there are no differences between them and optocoupler inputs.

Setting


Setting Set – Setting Inputs “Path specification”, i.e. present location Equipment Adaptation Transf. Adaptation Output command FuseVoltageTransf. Address of this output command ValIdentAdr 360 Arrow indicates possible cursor directions, input → Logic>and < PS-DI1:N Remark: Cursor flashing, input field included between > <

In the example, the negated signal of the DI1 of the power supply module PS results in an active signal “Fuse voltage transformer”. Once the configuration has been completed, the settings must be acknowledged via the button <E> or be discarded via the button <C>.

Setting


8.5 Configuration of analogue temperature sensors (module PT100) In configuring the temperature sensors, the (software) temperature measuring locations offered (see Table 17, Page 342) can be linked to one or several physical temperature sensors of module PT100 (Fig. 5.31-4). In this context, 1 corresponds to input TI1 (connectors X1/X11) and 8 to the input TI8 (connectors X8/X18) of this module. For four wire measurement both terminals are necessary, e.g. X1 and X11. If several physical temperature measuring locations are assigned to one software temperature, the digitized temperature output values of module PT100 can be pre-processed mathematically:

• MAXIMUM, • MINIMUM or • AVERAGE.

Thus, for ex., several Pt100 measuring locations can be distributed in the winding of an object to be protected, and these can be assigned to the software measuring location “665 Temperature 1“.

These mathematical functions are activated via several temperature sensors of the same measur-ing task, not by the time sequence of the temperature measurands of one sensor.

If only one temperature sensor is connected for a measuring task, any mathematical function may be set.

When assigning the temperature sensors, it must be noted that software temperature measuring locations which have not been enabled due to previous decisions related to equipment adaptation / device adaptation, are not available within the range of the software temperature measuring lo-cations offered, and can thus not be configured.

Under "Setting set / Setting / Temp. sensor TI / Equipment adaptation / Device adaptation“, the sensor inputs are assigned to a software measuring location. The line with the eight optocoupler inputs is too long to fit into the visual area of the display. Use the arrow buttons <→>, <←> to search the line for the sensor input to be configured. The following two states can be selected for an input via the buttons <↑>, <↓>:

• not used – field is empty • use of temperature sensor – “X“

The mathematical processing function located next to "Logic" is also selected by means of these buttons. Once the configuration has been completed, the settings must be acknowledged via the button <E> (or be discarded via the button <C>).

Setting


8.6 Operator control in main menu, resets The "Protection system main menu" offers, apart from settings and reading out the settings, several important functions which are described briefly below.

Protection – Main Menu Reset LED/Report > Reset Reclose Lockout Measurand Display Statistic Values Event Memory Clear Events Setting Set Identification Test Protection Restart Date/Time Change Password

8.6.1 Reset LED and report The first menu entry in the protection system main menu enables the LED signals generated by the protection part to be reset simultaneously with the report. If the cause of LED activation or the report is not eliminated, the output remains unchanged. Access to resetting is made without password and warning signal (in analogy to button actua-tion), but is recorded in the event memory.

8.6.2 Reset RC lockout (reclosing lockout) This password-protected menu item permits cancelling of a reclosing lockout set by protection modules (see also section Fehler! Verweisquelle konnte nicht gefunden werden.). The reclosing lockouts set by the following protection modules cannot be cancelled automatically, but must be reset by operations:

• temperature monitoring by temperature sensors ("Temperature protection") • the RC lockout initiated via the input signal “4560 Set RecloseLockout“.

Important: Resetting the RC lockout requires precise knowledge whether reclosing can be permitted to the equipment, e.g. whether causes of faults have been eliminated and equipment cooled down sufficiently. Otherwise, there is a risk of overload, destruction or major damage!

Remark: The level of the thermal replica can be reset as for the reclosing lockout in the test menu (5.29.3.11), taking the same hazards into account.

8.6.3 Clear Event-Memory In this menu item, the event memory and the fault disturbance data memory can be deleted. This is only possible upon entry of the password. The time of deleting is recorded in the event mem-ory. This does not reset the grid fault number and fault number (5.29.3.4).

8.6.4 Identification Important device information is displayed in this menu. In addition, four text fields are existing which can be filled by the user.

Setting


Entries into the text fields by the user can only be effected via COMM-3. The identification menu of COMM-3 has been provided to this effect. During transmission to the device, only the changes of the text fields are transferred; the other data remain unchanged. Only the manufacturer can change the device settings on the device.

8.6.5 Protection restart and software reset If access to the protector is no longer possible or if the protection does not operate correctly any longer, a

• protection restart ("protection system main menu") and, if it is not successful, a • software reset (in the test menu)

can be triggered. In both cases, the device’s protection part is initialized. While it is present, the protector for the substation control enters into malfunction state with subsequent restart. The "restart" is less comprehensive than a software reset. Important:

A “Protection restart“ does not change the events or settings. A software reset clears the event memory, the fault data, the fault and grid fault number, the thermal level and the LED with the report.

After input of the password and actuation of the <E> button, the restart or software reset are effected. This will take approx. 40 seconds.

8.6.6 Date/Time The current date/time representation is visualized by setting the cursor to “Date/Time“ and by pressing <E>. To correct the displayed time, enter the settings by actuating the button <E>. The password is required for setting the watch. Date and time are set in separate steps. Once the date has been set, the button <E> must be actuated as acknowledgement. Only now is time setting possible, which in turn must be exited by actuating the button <E>. Regarding the time setting, the first cursor position on the outer left side is provided for the se-lection of ”S“ (for summer time). To exit the setting menu, actuate the button <C>. Remark:

Date and time can also be set via the PC operating software COMM-3.

8.6.7 Password The password is pre-set by the manufacturer to 3333. This is simultaneously the most important password by means of which a forgotten password can be reset (5.29.3.16.1). To change the password, first enter the former password, then the new one. To this effect, ac-tuate the <←>, <→> buttons to approach the decimal position and set the latter to the re-quired value via the buttons <↑>, <↓>; then, after having entered the new password, ac-knowledge via <E>, then repeat this new password and acknowledge again. Thus, the former password is no longer used.

Change Password Password > 0000

Setting


8.6.8 Further resets To reset the fault and grid fault number of the events or to reset the statistic values of the pro-tector, use the submenu "Test". To this effect, see section 5.29.3.

8.7 Determination of setting data, configuration and connection The protection devices are delivered with a preliminary setting, see Appendix 11 as of Page 310. This default setting stored in the ROM has to be modified according to the individual case of ap-plication and then stored again in the ROM. Each project determines the desired mode of protector functioning (protective and supplementary functions) and, thereby, the necessary input and output configuration. For example, the settings result from the calculation of the short-circuit current and the determi-nation of tripping times from the time grading schedules. The zone reach and the direction deci-sion concerned must be taken into account according to the required effect in the time grading scheme. Functional descriptions and instructions given in section 5 should also be considered. Before preparing the settings, it should be defined • which protective and supplementary functions are to be realized, • which input and output signals are required, • to which terminals the required signals should be applied. An appropriate terminal diagram should be drawn up to be used as an auxiliary means in the preparation and realisation of setting. At the same time, Appendix 11: Settings DDx 6 can be completed as a basis.

Readout


9 Readout

All settings, operating measurands and events as well as supplementary information can be dis-played. Operating measurands according to the determinations made during substation control project planning are already visualized on the control page which is used as basic page. Moreover, the protection pages display an ample choice of measurands and derived variables. The starting point for the settings described in this chapter is the “Protection – Main Menu“,

which is accessible by actuating the button : Protection – Main Menu Reset LED/Report > Reset Reclose Lockout Displaying the current operating measurands Measurand Display Display of cumulated statistic values Statistic Values Displaying the event memory Event Memory Clear Events Displaying options for all settings Setting Set Displaying the identification Identification Test Protection Restart Displaying the identification Date/Time Change Password

Setting and reading out of the settings of the protection part are effected on principle by the same approach. After selecting the entry “Setting set“ via <↑>, <↓> buttons and acknowl-edgement via the <E> or <→> buttons, “Display“ must be selected in the following screen. Access is possible without a password; changing of values is not possible. Once the <E> or <→> button has been actuated, the user is within the menu which contains the above-mentioned five items.

Setting Set – ReadOut Direct access to a setting via address Addressed Value Function switches and settings Setting Values > LED output configuration LED Relay output configuration Relays Output configuration of the virtual inputs Cmd.->Inputs (vDI) Input configuration Inputs Configuration of temperature sensors (if present) Temp.Sensor TI

If only one specific setting is to be checked whose address is known, the first menu entry can be used. After input of the address via the cursor buttons and confirmation via <E>, the user gets directly to this setting. The settings are arranged by categories and groups. First of all, the category has to be selected:

Readout


Setting Set - ReadOut Setting Values Refer to 9.5 Firmware Important settings relating to the protected object Equipment Adaptation > Important settings relating to the protected object Protection Modules Important settings relating to the protected object General Protector address, information blocking Com.+SubstCtrl.

Once the required category and the required characteristic set (if further characteristic sets have been enabled) has been reached, the groups are available from which the group to be displayed must be selected:

Setting Set – ReadOut Setting Values Equipment Adaptation Characteristic Set1 System Adaptation Setting set groups Transf. Adaptation > CB Adaptation Characteristic Set

The settings of the selected group are displayed in a list. If this list is longer than the visible dis-play field, they can be moved line by line via the cursor buttons <↓> <↑>. The end of the list has been reached if the cursor is in the last but one line.

Setting Set – ReadOut Setting Values “Path specification”, i.e. present location Equipment Adaptation Characteristic Set1 Transf. Adaptation IL CT Earthing 331 Line End In CT sec. IE 332 In = 1 A In CT prim. IE 302 60 A IE CT Earthing 333 Line End Un VT sec. 334 100V Un VT prim . 303 10.0 kV Cursor has reached last line Fuse Voltage Transf. 335 connected

The visualization always shows the menu or submenu which the user has accessed. For this pur-pose, the present state is indicated in the upper lines, analogously to a PC directory. To exit the display menu, actuate the button <C>.

Readout


9.1 Operating measurand display The operating measurands are displayed in the menu “Operating measurands“. The measurands are displayed in a list which is longer than the visible window. All currents, voltages, power val-ues, system frequencies and levels can be displayed via the <→>- or <←> buttons. To change over from viewing between primary / secondary values, use the <↓>, <↑> buttons. Calculated variables are displayed in addition to measured ones. For further information regarding the operating measurand display, refer to 5.32.1 on page 232.

Measurand Display primary A Ineg – negative sequence current I1 300 Ineg. <Imin IEmeas – measured earth current (transformer IN) I2 300 IEmeas. <Imin IEcal – calculated earth current I3 300 IEcalc <Imin primary kV

Uneg - negative system voltage U1E 5.7 Uneg. <Umin U2E 5.7 U3E 5.7 primary kV U12 10.0 US2, UNE or U4 – voltage measured on the transformer U4 U23 10.0 U4 -- UNE calculated displacement voltage U31 10.0 UNE <Umin Grid Frequency Hz f 50.000 Possible motions using the cursor buttons ↑↓ Pri/Sec ←→ change Page

9.2 Displaying the current statistic values The saved statistic values can be displayed via the menu entry "Statistic values" of the pro-tection system main menu. For further details, refer to 5.32.3.

9.3 Displaying the event memory In the event memory, such events are filed as may be useful both to detect power system faults and to contain a documentation of manipulations or recorded malfunctions in the relay. The event memory is called up from the “Protection system main menu“ via the input ”Event mem-ory“. As the events are assigned to event groups, a dialog is displayed for selection of a group to be displayed or even of all events. After this selection, the user gets to the last (most recent) main event. Within the event memory, scrolling is possible in the following way:

• Only main events (absolute time event) direction ”past“ – button <↑> • Only main events, direction ”present“ – button <↓> • Main and sub-events (relative time event) direction ”past“ – button <←> • Main and sub-events direction ”present“ – button <→>

The end of the event memory in the direction of the present is identified with “No newer Event“ or “No newer Main Event“, and in the direction of the past, with “No older Event“ or “No older Main Event“. In the events, “c“ means “incoming“ and “g“ means “outgoing”.

Readout


Event Memory - ReadOut Main event Absolute time “S“ means summer time 2007-Mai-23S11:48:27,979 General Start c Subevents Relative time to absolute time + 0ms Disturb.Data Record. FltNo 3 GrdFlt 3 + 0ms “c” stands for comes, “g” for goes Start IL2 c + 0ms I2> Start c + 4ms Start IE c + 4ms IE> Start c + 1000ms Further subevents only accessible via <→> ! tIL> expired Possible motions using the cursor buttons ←→Event ↑↓Main Event

For a power system fault resulting in switching off, the secondary currents measured at the time of the TRIP command that have to be multiplied by the rated current In or Un, are entered.

Remark: Different values for IEmeas and IEcal result from different current transformer ratios (see equa-tion 5-41).

The fault number “FltNo“ and the grid fault number “GrdFlt“ are indicated in the subevent “Disturb.Data Record.“.

After an earth fault, a message of the following type is in the event memory: Event Memory - ReadOut

Passed time referred to main event + 216ms

measured secondary active and reactive power (from UNE,IE) P +0.132 Q +0.678

secondary measured earth current and displacement voltage IE 0.694 UNE 0.9999

Weighting factor fb=fP⋅fU fp: 1.50 fu: 1.00

9.4 Display of device identification The device identification contains important device information for settings and service. It is ac-cessible under ”Identification / Display/“. The following is displayed:

• Protection type • Serial number • Structure version • Firmware version • Hardware version • Device address • Baud rates • Four text fields which can be filled in by the user via the PC software COMM-3.

9.5 Display of device type (firmware adaptation) The device type is indicated on the control panel above the LED labelling. The hardware equip-ment as regards earth current transformer and temperature capture module (PT100) is included in the firmware adaptation of the device. The following indications can be selected: “Setting set / Setting / Setting values / Firmware / Firmware adaptation“:

Readout


Setting Set - ReadOut Setting Values Firmware Characteristic Set1 Path information Firmware Adaptation

Type of Device: 1

Device type 4I+4U=DDEY6

IE Device CT 2

Equipment variant earth current transformer sensitive 20x

Temperature Inputs 3

no

The firmware adaptation is entered by the manufacturer and must not be changed, as it is hard-ware-related. This indication is, of course, independent of the characteristic set.

9.6 Display of device address The address set in the protector is stored in the protection system main menu under “Identifica-tion“ or in the “Setting set / Display / Setting values / Comm.+SubstCtrl. / Communication“. Press <C> to exit the menu.

Start-up


10 Start-up

Before an initial start-up can be performed, all works mentioned in section 6 must be done.

10.1 Preparations

! Warning !

The general installation and safety regulations for operations at power installations, e.g., the standards IEC, EN, ÖVE, ÖNORM, DIN VDE and BGV A3, must be complied with. When operating electrical devices including protective equipment, parts of these devices may conduct dangerous voltages. Non-observance of the relevant instructions may result in serious damage and physical injuries (possibly even death). This is why only qualified staff are allowed to work on these protection systems, who are famil-iar with the dangers on the device and the system to which it is connected, and with the appro-priate safety provisions, precautions and warning information provided in this user manual. It must be taken into account that • prior to connection of any terminal, the device must be connected to earth via the protective

conductor terminal, • dangerous voltage may occur on all parts of the circuitry which are connected to the auxiliary

voltage or the measuring or control variables; • dangerous voltages may still be present for a short time after disconnecting the device from

the supply voltage, due to the memory effect. Before checking the device using a test equipment, it should be considered that • no other measured variables are applied, • the protective TRIP and CLOSE signals to the circuit breaker are disconnected (unless any

other check of the CB is intended), • signal communication to upstream circuit-breakers and to protection devices located on the

opposite side are deactivated, • during the test, the permissible limits - according to the specifications – must not be ex-

ceeded.

! Attention!

Before disconnecting the current terminals from the device, the secondary circuits of the current transformers have to be short-circuited! If a test switch is existing, the latter must be in position “Check”; in case a test socket is avail-able, the test connector must be inserted to ensure that the condition for short-circuiting of the secondary current transformer circuits and for opening the voltage transformer circuit is fulfilled. If the input “51860 Test Mode“ is used, this enables the events occurring during the test to be identified as test results. The input “51660 InformationBlockg.“ prevents transmission to the control system. To perform functional tests, testing equipment with a three-phase balanced voltage and current source is required, each phase of which can be adjusted separately. During the test with unbalanced variables, the unbalance monitoring may react and thus change the device over to emergency overcurrent time protection. To prevent this influence

• the measurand check can be switched off, or • the test can be performed with physically real measuring variables (U unbalance together

with I unbalance). The timers for signalling current and voltage path faults can be set to sufficiently high values. Correct verification of the measurand check is only possible on three phases.

Start-up


The measuring accuracy which can be obtained in the test is determined by the test and measur-ing equipment used. To check the tolerance conditions, the reference conditions according to EN 60255-6 must be complied with. To evaluate the test, it is necessary to check the output signals and the indicator messages (LED and LCD) and to compare them to the expectations. If a serial interface is connected, the error-free communication between the protector and the connected device (substation control unit/ telecontrol unit; PC or modem) has to be included into the test. Local reset of indication on the relay, and, if configured, remote reset, should be part of the tests.

10.2 Checking the terminals During the preparatory start-up work, all required protective and supplementary functions as well as the configuration of inputs and outputs were defined and entered into the terminal connection diagram. The following checks can be made based on these.

10.2.1 Checking the nominal values of the protector The nominal values of the protector used have to be checked with regard to the individual case of application. The identification on the protection module includes the most important nominal values: • Rated current and rated voltage • Auxiliary voltage

10.2.2 Checking the power supply terminal First of all, check whether the available auxiliary voltage corresponds to that of the device being used, and ensure correct polarity. The terminal X5-3 applied to protective conductor potential deserves particular testing.

10.2.3 Checking the current transformer terminals Terminals for nominal current 1A or 5A have to be assigned according to the terminal connection diagram Appendix 7, Appendix 8, Appendix 9 as of page 305. In this context, it is essential that the marking of the winding start is observed. Check according to terminal connection diagram: • Are the terminal connections of the current transformers in accordance with the rated current

and polarity? • Are the connection and the setting regarding the current transformer earthing correct? • Is the phase assignment of the current transformers correct? • Cable type current transformer: is the cable screen wire returned through the cable type trans-

former, and has earthing been effected? • Is the cable-type current transformer mounted without air gap and displacement?

10.2.4 Checking the voltage transformer terminals In accordance with the connection diagram in Appendix 8, Appendix 9, the terminals must be assigned. In this context, it is essential that the marking of the winding start is observed. Check according to terminal connection diagram: • Is polarity of the voltage transformers correct? • Is the connection in reference to voltage transformer earthing correct? • Is the phase assignment of the voltage transformers correct?

10.2.5 Checking the signal circuits' terminal connections All signal circuit connections have to be checked according to the terminal connection and wiring diagrams, Appendix 8.

Start-up


If the auxiliary voltage is switched off, check the • Tripping lines to the circuit-breaker and to the in-line auxiliary CB contact • Connection lines to other devices • Signalling lines • Correct terminal assignment on the modules PROT, PS and PT100, if provided.

Start-up


10.3 Protection check The field test, which may be performed e.g. on commissioning the protector, cannot be meant to prove the correct software version of the protection module. In the scope of the device aptitude tests, the user should verify that reality meets his expectations. This applies especially to func-tions created by himself in the scope of configuration (pulse shaper stage, logic operations etc.). The manufacturer is responsible for checking the characteristics and functions of the protector in the scope of type testing. This proven feature of the software is not subject to aging and change as it is used in the system. However, the hardware function can change; thus it is the main tar-get of the tests in the system. Taking this target into consideration, we suggest that the test should focus on the measurands (analogue inputs), the inputs and outputs. This has the positive side effect that the test complexity is reduced versus static or electro-mechanical relays without sacrificing reliability and safety! Regarding the function of the protection relay, the test of pickup values is not mandatory, but it reassures the operator that his settings have been selected correctly. Certain fed-in test variables call for an appropriate response.

10.3.1 Applying the auxiliary voltage The start and supervision routines are started upon switching on the supply voltage. If the result is positive, the system goes onto ready-to-operate mode and the green LED “Ready” goes on. Once the system has been started up successfully, it is recommended to select the operating measurand display for visualization. If no measured variables are applied, at a current and voltage indication of <Imin, <Umin will appear. The powers are 0. A switched-on thermal replica starts with the level 0%.

10.3.2 Checking the settings and the configuration The setting set can be read out of the protector, and printed, via PC and COMM-3. With COMM-3, a comparison of the setting set in the protector with the required setting set can be effected easily.

10.3.3 LED test The operativeness of the LEDs of the control panel is established by pressing the <C> button on the control panel for more than 2 s. All LEDs must be lit. At the same time, the displayed status is not reset.

10.3.4 Test of the communication connections The operativeness of the communication with the PC and the operating software COMM-3 is to be verified by connecting the PC to the interface provided to this effect and after starting the dis-tance protection device software in COMM-3. To this effect, the identification and the setting set should be read out and compared to the anticipated values. Comparison between the setting set in the device and the prepared one is possible. It is useful to read the event memory and to verify it for unexpected entries.

! Warning !

When signals are sent via the system interface, the substation control equipment will receive the sent information. This might trip switching operations! These in turn may result in death, injuries or material damage! Before using this test function, all the required measures to avoid hazards must have been taken! Communication with a substation control equipment can be checked using the telegram test pro-vided in the test menu, see section 5.29.3.13.

Start-up


10.3.5 Check date and time The date and the time available at present in the device can be checked in the menu Date/Time of the protection system main menu. Checking by means of the COMM-3 operating measurand menu provides additionally the infor-mation whether synchronization has taken place:

A question mark following the time, as in the above screen, points out that the time has not been synchronized during the past 23 hours.

10.3.6 Check with secondary values

! Attention! Important!

When checking with secondary variables • TRIP commands may be issued, and • a teleprotection signal may be sent to the remote station

to the configured relays in question. When the teleprotection function "Intertripping“ is used (5.12.6, page 147)

• a TRIP command is issued regarding the protector on the remote station! • a TRIP command is issued due to a signal received without starting!

When checking the AR, CLOSE commands may be issued to the circuit-breaker, in addition to the TRIP command. When the circuit-breaker failure protection is used, TRIP commands to upstream circuit-breakers can be issued during tests. It must be ensured that no danger can occur, e.g. by preventing the issue of the TRIP and the CLOSE command to the circuit-breaker and deactivation of the signal communication to the op-posite protector or upstream circuit-breakers during the tests. The secondary value check is a functional check of the protection equipment. The quality of the test instrument influences the quality of the test results. The configured functions relevant for the specific case of application are tested. By evaluating the results such as the LED and LCD indications, output signals of the relays, event memory, signal memory of a connected control system, complete functioning of the protector is checked.

10.3.6.1 Checking the input signals ⇒ This is an important check that should not be omitted in the scope of repeat tests. The physical input levels which have been detected at present by the protector on the optocou-pler inputs can be checked. To this effect, the subitem “inputs“ in the test menu or the ”operat-ing measurands“ (in case the operating software COMM-3 is used) can be called up. The states of the inputs are displayed. The optocoupler levels are represented by “1” for voltage on the op-tocoupler and “0” for “no voltage at the input”. Thus, a software ”Negation“ which might be configured for the specific optocoupler input is not displayed.

! Warning !

Danger of electric shock when applying voltages to the inputs in order to check the complete function of the inputs.

Start-up


The function of the inputs may result in tripping, outputs to further output relays and conse-quently danger! To complete the hardware test of the inputs, the alternative level can be applied in each case to the inputs, which are then checked in the test menu.

10.3.6.2 Checking the output relays ⇒ This is an important check that should not be omitted in the scope of repeat tests. Each output relay used for a function can be checked for contact-making independently of the configured function. To this effect, the input ”Relays“ in the test menu must be used.

! Warning !

Before using the relay test, all the required safety measures, e.g. disconnecting external connec-tions, must be taken to avoid hazards and undesired operating states. The contacts of the activated relays are actuated and can activate the equipment connected to them.

10.3.6.3 Connecting the current and voltage measurement ⇒ This is an important check that should not be omitted in the scope of repeat. The measurement is made in the protector in a wide area whose linearity can be checked for ac-curacy at two or three meaningful points. The check is made by means of the operating meas-urand display. The measuring ranges can be found in section 3.8.1 on page 25. All voltage and current inputs must be checked including the anticipated primary value display. In order to get some information regarding possible phase angle errors, the indicated values for P and Q are to be checked while supplied with active or reactive power.

Important: During the test, the admissible loads (3.3) of the current and voltage inputs must not be ex-ceeded.

10.3.6.4 Checking the effect of the fuse voltage transformer ⇒ This is an important test which should not be omitted in the case of repeat tests, if a fuse

voltage transformer is included in the voltage path monitoring. The miniature circuit-breaker of the voltage transformer must be switched off, so that the protec-tor's input thus configured is activated. In the report, the warning "Error voltage path" is displayed immediately. In the event memory, the entry “I> Backup Operation“ must be pre-sent.

10.3.6.5 Checking the current and voltage starts ⇒ This is an important check that should not be omitted in the scope of repeat tests. If testing with currents, it has to be considered that • the continuous load imposed on the current inputs is not exceeded, • higher-value currents for the setting values are permitted to be passed only for a short time,

possibly with appropriate dead times, • in case of tests in no-voltage condition or in case of unbalances of the input variables, the

measurand test can be started and affect the behaviour (5.29.1). If necessary, it must be de-activated during the test,

• in the case of single-pole tests, delays by t1p may occur (5.5.2.2, 5.6.2.1) Safe starting of overcurrent and overvoltage starts should be checked at 1.05 times the setting value, and fall back at 0.95 times the setting value. Underimpedance Z< and undervoltage starts should be checked at 0.95 times the setting value, and fall back at 1.05 times the setting value. For the reset check of the starts, the adjusted reset ratio must be taken into account. Within the

Start-up


earth circuit, any set stabilization of the pickup value depending on the phase currents must be considered. During and after start pick up, it must be checked that the relay outputs, event memories and LED indicators correspond to the checked case of error.

Remark: Current versions of the U-I starting test modules of some numeric test devices do not simu-late precisely the physical state for double earth faults in the non-earthed system. The sup-plementary fault criterion – voltage overshoot of an ULE to 0.6⋅ULLmax – for the change-over to phase-to-earth loops can thus not be generated correctly! If “4932 EarthFault if“ has been selected for “IE>and UNE>EFC+asym“, only phase-to-phase loops can pick up. To verify the preset characteristic by means of such test modules, “4932 EarthFault if“ can be set to “IE> and UNE>EFC“ or “IE> or UNE>EFC+asym“. In this case, for change-over to the phase-to-earth loops, exceeding of “4901 IE>EFC“ is sufficient. After the test, the switch must be reset.

The starting check can also be effected in conjunction with the distance zone test. The set times are mere delay times. They do not include the inherent delays of the measuring circuits. The change-over to the emergency overcurrent time protection in case of a voltage path fault (e.g. signal on input "fuse voltage transformer“) and the current pickup values applicable in this case can also be checked. An UNE> start can also be checked be a single-phase voltage, e.g. applied to UL1E. To this effect, the “Supervision U Path“ must be switched off during the measurand check, or the timer for the fault in the voltage path “tU Time Malf. U Path“ must be set to a high value in order to pre-vent error messages regarding the voltage path. In this case, the following applies (two phase-to-earth voltages are 0 V):

ENE UU 131

⋅= 10-1: UNE of one voltage

Evaluation can be effected e.g. by an LED configured via the output command “UNE>“ or via re-lay.

10.3.6.6 Checking impedance starting Z< ⇒ This is an important test which should not be omitted in case of repeat tests if the Z< start is

used. To check the distance zones, an error-free (rotating field), three-phase voltage and current sys-tem is required. The (U) I current start must be switched OFF in order not to influence the results. A three-phase test equipment is recommended. The setting of test variables depends on the test equipment ap-plied. In COMM-3, characteristics can be issued in XML format. This file format is suitable for transfer of the settings to test equipment, e.g. of OMICRON electronics GmbH (together with the XRIO converter). Due to the polygonal Z< characteristic starting cure, the following conditional equations may be useful for the corners of the characteristic curve (in case of R < “5909 Rsmax...“, “5919 Rsmax..“).

Start-up


Fig. 10.3-1 Determination of Z< characteristic curve corners

10.3.6.7 Checking the distance zones ⇒ This is an important check that should not be omitted in the scope of repeat tests. To check the distance zones, an error-free (rotating field), three-phase voltage and current sys-tem is required. A three-phase test equipment is recommended. The setting of test variables de-pends on the test equipment applied. The pickup limit of the distance starting in question must be exceeded for the test. In COMM-3, characteristics can be issued in XML format. This file format is suitable for transfer of the settings to test equipment, e.g. of OMICRON electronics GmbH together with the XRIO converter "Sprecher P94 DD(EY)6 Converter DEU.xrio“ (integral part of COMM-3, on the website of Sprecher Automation). This saves calculation and manual input of the characteristic. The following conditional equations for the corners of the characteristic curve might be useful to calculate the fed variables. In Fig. 10.3-2, the angle α corresponds to the setting “5001 In-clin.Angle Polygon“, β to the setting “1905 Charact.Angle SCD“ and RE or XE to the ap-propriate distance zone settings.

Fig. 10.3-2 Determination of the zone characteristic curve corners

X

α R

Direction line β

EX X ERX

ERR

− = +−°

⋅⋅−=

+−°

⋅⋅=

max 1 ; ) 90sin(

cossin1

)90sin(

sinsin1

βα

β α

βα

βα

1 4

1 4

X X

R R

− =

− = RE

X E EXX

EX

ERR

=

⋅+=

2

cot 2 α

E X X

ER R R

=

⋅ − =

3

2 2 3

⎟⎟⎠

⎞⎜⎜⎝

⎛−−°

⋅⋅−=

σαασ

σ 180sin(sinsinE

ERXX

ασσ cot⋅+= XRR E

σ

X

R ϕ 4 ϕ 3 ϕ 2 ϕ 1

X v

X r

Z setting

R=Xv ⋅ cot ϕ1 < RmaxX=Xv

X=-Xr

R=-Xv ⋅ cot ϕ2 < -Rmax

R=-Xr ⋅ cot ϕ3 < -Rmax R=Xr ⋅ cot ϕ4 < RmaxX=-Xr

X=Xv

Start-up


10.3.6.8 Checking the direction decision Short-circuit direction The short-circuit direction can already be checked in the scope of the above-mentioned tests. Thus, please find below just a few additional instructions. When checking the direction decision "short circuit direction", the principle of the 90°-circuit (fault-external voltages, see sections 5.5.2.3, 5.4.2) has to be observed in order to assign the correct terminals with the correspondingly phase-displaced test variable if a single-pole testing unit is used. When using three-phase testing equipment, the fault variables are provided in a correct fashion, the check concerning a certain short-circuit angle can be performed by phase displacement of one system. If no voltage was applied before a three-phase short-line fault (U<“1908 Umem if ULL <“), no direction decision is possible on principle. Remark:

The direction decision forward is generated, if • in three-phase systems the selected current IL is applied to the identically named voltage ULE,

i.e. lagging in the range of 90°+ ϕi leading over 0° to 90°- ϕi (ϕi is the characteristic angle set in “1905 Charact.Angle SCD“).

• in case of individual supply of the current and the voltage (at a 90° angle), the current IL is present, with regard to the voltage ULL, lagging in the range of ϕi and leading over 0° to 180°- ϕi.

Zero power direction (earth current limited, earthed system) The test of the zero power direction is effected in case of current start exclusively in the zero path (exceeding “2101 IE> Definite Time“, “2102 IE> Inverse Time“, “2201 IE>>“, “2301 IE>>>“ or “2401 IE>>>>“) and when a displacement voltage is present which exceeds the setting “2902 UNEmin ESCD“. This may be done by single-phase connection to one current and to the corresponding voltage. If three-phase testing equipment is used, it is necessary to re-duce for example the amplitude of the voltage UL1E to an extent that “2902 UNEmin ESCD“ re-acts (see equation 10-1). Then the current IE has to be generated by a sufficient IL1 without ex-ceeding the starting limit of the distance protection. Remark:

The direction decision forward is generated, if • in three-phase systems simulating the earth short-circuit fault, the selected current IL is ap-

plied to the identically named voltage ULE, i.e. lagging in the range of 90°+ ϕi leading over 0° to 90°- ϕi (ϕi is the characteristic angle set in “2905 Charact.Angle SCD“).

• If a single-phase test only is performed e.g. with IL1 and UL1E, the IL1 angle range is offset by 180°, i.e. lagging from 90°+ϕi over 180° to 90°- ϕi leading versus UL1E

Earth fault direction in the compensated system As the explanations regarding the function "earth-fault direction decision" show, the total factor fb is non-linear, while the requests of assessing the procedure as an earth-fault are simultane-ously satisfied. That renders verification of the pickup value and the release value with artificial measured variables rather complicated. The test of the earth fault direction function is limited to checking the operate value and the release value. It can be effected most easily in the way de-scribed in the following. Prerequisites:

• Symmetric voltage system ULE=Un/√3, for Un=100V: 100/√3=57.74 V • Earth-fault on L1, to this effect open the neutral (leading to terminal X21-6) of the test

equipment and connect it to UL1E (leading to terminal X12-1). • This results in UNE=100 V and corresponding overshooting of the ULE voltages not con-

cerned by the earth fault to 100 V.

Start-up


• Supply test current IE in the protector’s earth current transformer (terminals X21-4+X21-6 or X21-5+X21-6 for In=5A), phase angle with regard to UL1E: 0° for “forward”, 180° for “reverse”.

• For the check, an LED or relay with output command of the earth-fault direction decision must be configured - "Earth-fault forward" or "Earth-fault reverse".

Operate value Pop: If only active power is available and UNE=100 V, the resulting total factor fb is 4.0. Thus, the pickup value according to the equation 5-25 on page 93, becomes

4>

=PPop

.

Since UNE=1⋅Un, the measured power P corresponds to the value of the test current IE/In. Starting and direction output must take place with

4>

=P

II

n

E .

Release value: Pre ≈ 0.8⋅Pop applies, what can be proven in analogy to the pickup value determination.

Earth fault direction in the isolated system Checking of the pickup threshold and the release value can be effected in the following way. Pre-requisites:

• Symmetric voltage system ULE=Un/√3, for Un=100V: 100/√3=57.74 V • Earth-fault on L1, to this effect open the neutral of the test equipment and connect it to UL1E.

This results in UNE=100 V and corresponding overshooting of the ULE voltages not con-cerned by the earth fault to 100 V.

• Supply test current IE in protector’s earth current transformer, phase angle with reference to UL1E: 90° for “forward”, 270° for “reverse”.

• For the check, an LED or a relay must be configured with output command of the earth-fault direction decision.

Operate value Qop:

when UNE=100V, the factor fU is 1. Thus, the pickup value becomes 1>

=QQop .

(Remark: the smaller UNE, the bigger the factor fU) Since UNE=1⋅Un, the measured power Q corresponds to the value of the test current IE/In. Starting and direction output must take place with IE/In=Q>.

Release value:

Qre ≈ 0.8⋅Qop applies, what can be proven in analogy to the pickup value determination.

10.3.6.9 Checking the power pickup value (earth fault) The pick-up threshold “7001 P> resp. Q> pickup“ must be verified taking the effect of the weighting factor fb into consideration. Compensated system: If only the active power is present and UNE=Un, a total factor fb of 4 results. Thus, the pickup value in accordance with the equation 5-25 becomes

4>

=PPop

.

Isolated system: The check must be performed with the full displacement of – UNE=Un –. This applies for the pickup value Qop=Q>.

10.3.6.10 Checking the output signal circuits ⇒ This is an important check that should not be omitted in the scope of repeat tests. According to the configuration, the relay outputs (trip and signal relays) have to be checked. They must close or open their contacts during the fault simulation in question in line with their function. The best check is provided by the digital inputs of the test equipment. Straightforward checks can be done by measuring the voltage or the current flow.

Start-up


10.3.6.11 Check of CB TRIP command ⇒ This is an important check that should not be omitted in the scope of repeat tests. The output of the TRIP command must be performed on the trip relay configured accordingly. The connection from this relay to the circuit breaker should be interrupted. As test, a start is to be generated which leads to a TRIP command. When a digital input of the test equipment is used, the grading time can be measured simultaneously. (At the same time, the dielectric strength of the inputs of the test equipment and the available auxiliary voltage must be taken into consideration!) If applicable, a measurement on the floating contact must be per-formed. The inclusion of the circuits up to the trip coil of the circuit-breaker and its functioning can be performed via a "trial AR" or "trial TRIP" as described in 10.3.7.5).

10.3.6.12 Checking the pulse shaper stage Due to the highly versatile applications of this function group, it is mandatory to prove the cor-rect execution of the required function. All the possible input conditions and their effect on execution of the function must be checked.

10.3.6.13 Checking the teleprotection function

! Important:

When the teleprotection function "Intertripping" is used, • a TRIP command is issued due to a signal received without starting! • a TRIP command is issued at the protector on the remote station due to the transmit

signal! During the test, the transmit relay for transfer to the opposite protector is actuated. To avoid un-intended effects, the teleprotection line must be deactivated in an appropriate fashion. ⇒ This is an important check that should not be omitted in the scope of repeat tests. The minimum check of the selected teleprotection function should include the functioning of the receive and transmit circuits. It should be taken into consideration that only the receiving circuit (optocoupler input) exists for reverse interlock and at the receiver in the "Unidirectional mode". In contrast, the transmitter in the "Unidirectional operation" has configured only one transmit re-lay and does not have a receive input. In the following, only the minimum scope is described. A complete function testing according to the function description given in section Fehler! Verweisquelle konnte nicht gefunden werden. is to be preferred, if applicable. The evaluation of the sequence of operations stored in the event memory permits to check the operations for correct working order.

10.3.6.13.1 Reverse Interlock Function If the reverse interlock is used, it must be checked by means of test equipment. The operating time “19014 topTP Operating Time“ is set to a value shorter than the grading time. • The starting and input signal “19060 TP Signal Input“ arrive at the same time (i.e. down-

stream protector detects error) and result in tripping in grading time. The event memory must contain the message “TP Signal received“.

• Starting without “incoming input signal” (lower-ranking protector does not detect error) re-sults in tripping within the operating time.

10.3.6.13.2 H2 Logic If the H2 logic is used, it must be checked by means of test equipment.

Start-up


The basic time (“19014 topTP Operating Time“) is set to a value shorter than the grading time. • Starting in forward direction and input signal “19060 TP Signal Input“ arrive at the same

time (i.e. the protector arranged opposite on the line detects error in reverse direction) and re-sult in tripping in grading time. The signal must have been indicated as received in the event memory.

• Starting in forward direction and input signal “19062 H2:Subst.BlockSignal“ arrive simul-taneously (i.e. the DDx 6 has generated itself the blocking signal for the station blocking bus) and result in tripping in the basic time topTP. No signal receipt must be recorded in the event memory.

• Starting in forward direction arrives without input signal (no blockage signal is applied): results in tripping in the basic time topTP.

• Starting in reverse direction arrives without input signal (no blockage signal is applied): results in tripping in the basic time topTP.

• Starting in reverse direction and input signal “H2:Subst.BlockSignal” arrive and result in tripping in grading time. Signal receipt must be indicated in the event memory.

10.3.6.13.3 Two-wire comparison If the opposite protector is not to be included in the test, a closed signal loop must be simulated. Short-time interruption of the current flow via the “19060 TP Signal Input“ (< 15 s) causes signal receipt to be communicated to the event memory. Interruption of the current flow for more than 15 s generates a malfunction message which applies until current flow recovery. At the same time, the output elements configured by the output command “19073 TP Con-nect.disturbed“ are activated or deactivated. When starting is generated with correct transmit condition, the current flow interruption must be effected in the loop by the transmit relay. When starting is reset, this results - in addition to the starting messages - in the messages "Signal transmit." and "Signal received" in the event mem-ory.

10.3.6.13.4 Unidirectional operation Receiver: Check of signal reception by applying a voltage to that optocoupler input that is configured with the signal function “19060 TP Signal Input“. Subsequently, the message "Signal received" including the correct time has to be present in the event memory. Transmitter: To check the correct operation of the output relay configured with “19071 TP Send Signal“, the measured variables current and voltage have to be applied to three phases according to the selected settings and the transmit condition has to be generated. The transmit relay has to close its NO contact as long as the transmit condition is fulfilled.

10.3.6.13.5 POP mode / BOP mode Check of signal reception by applying a voltage to that optocoupler input that is configured with the signal function “19060 TP Signal Input“. Subsequently, the message "Signal received" including the correct time has to be present in the event memory. To check the correct operation of the output relay configured with “19071 TP Send Signal“, the measured variables current and voltage have to be applied to three phases according to the selected settings and the transmit condition has to be generated. The transmit relay has to close its NO contact as long as the transmit condition is fulfilled. (In case of BOP mode, the transmit condition is always the detected reverse direction.)

10.3.6.14 Checking the AR Before checking the AR, make sure that

• the TRIP and CLOSE commands to the circuit breaker are disconnected

Start-up


• if the CB function is to be included nevertheless, this must not create any hazard for staff or switchgear.

Before checking the AR, the latter must be switched on and ready; to this effect, it may be nec-essary to supply the input configured with “9963 CB ready” with the active signal. According to the selected AR start condition and the number of permissible cycles,

• compliance with the start condition, • the failed AR (final TRIP after reaching the permissible number of shots without the

fault being eliminated) and • the successful AR can be tested.

The testing should also include • prohibition of AR and final tripping caused by

- "CB closed manually“ (blocking time not yet expired) - failure to fulfil programmed pickup condition - “CB ready” is not applied - Input signal "AR blocking" (if used) During the AR test, both the dead times, rapid and delayed reclosure, and the tripping times, e.g. not final tripping undelayed, final tripping in grading time, must be determined. Without test equipment, one-time AR can be tripped via

• the test menu entry “AR test” or • a configured input signal “9960 AR External Start”.

10.3.6.15 Checking the thermal replica Three methods are available to check thermal replicas: 1. - Specification of a test current, e.g. in case of simple determination of τ, a current can be

used which results in tripping at 0.1⋅τ:

1052.0%100

1052.1 F

IkI n

−⋅⋅= 10-2: Current for tripping after 0.1⋅τ

- Reading the level F at the beginning of the test (taking account of the preload), - Logging the trip time and - Comparing with the calculated trip time (equation 5-36, page 162). For the automation of time measurement, the start level F (= setting of warning level) can be indicated e.g. via the signalling contact of a warning level. The TRIP command stops the measurement.

2. Set a fixed level by preloading an object to be protected: a) Level 0%: If no current is flowing, switch off and reconnect the supply voltage. Another method consists in blocking and re-enabling the thermal replica. b) Any level: When connecting the supply voltage for the protector, the level of the thermal rep-lica is set to the value which corresponds to the presently flowing current (according to equation 5-35). Or: first apply a higher current (e.g. 5-fold Ip) up to 5% below the level to be reached, then an-

other τ+100ms (dead time) with Ip %100

FIkI np ⋅⋅= . A possibly existing level is irrelevant then,

but it may take long to reach the level according to the specified preload in steady state. Based on the level which has been reached, the following equation can be used to determine a current which results in tripping within a specified time

1

%100

−

−⋅⋅=

τ

τ

a

a

t

t

n

e

FeIkI 10-3: Current for tripping after a specified time

. 3. Determination of the time between 2 different levels at a specified current:

Start-up


⎪⎪

⎭

⎪⎪

⎬

⎫

⎪⎪

⎩

⎪⎪

⎨

⎧

⎥⎥⎥⎥⎥

⎦

⎤

⎢⎢⎢⎢⎢

⎣

⎡

−⎟⎟⎠

⎞⎜⎜⎝

⎛

⋅−⎟⎟⎠

⎞⎜⎜⎝

⎛

−

⎥⎥⎥⎥⎥

⎦

⎤

⎢⎢⎢⎢⎢

⎣

⎡

−⎟⎟⎠

⎞⎜⎜⎝

⎛

⋅−⎟⎟⎠

⎞⎜⎜⎝

⎛

⋅=2

2

222

22

122

%100ln

%100ln

kII

FkII

kII

FkII

t

n

n

n

nF τ

10-4: Time from level F1 to F2

For the duration for reaching level F2 when starting from F1 at constant current, equation 10-4 applies. It contains the special case of a trip time from the preload F (F2=100%). Likewise, by changing over to I, a required current can be calculated which leads to level F2 starting from level F1 within tF:

⎟⎟⎠

⎞⎜⎜⎝

⎛−

−⋅⋅⋅=

1%100

12

τ

τ

F

F

t

t

n

e

FeFIkI

10-5: Current for raising level F1 to F2 within a specific time

After tripping through the thermal replica, the enabled reclose blockage must be set, so that a signalling relay configured accordingly must have opened the CB CLOSE circuit. Cooling (at I=0) can be checked via the duration until a certain level is reached. In this context, the following applies

τt

eFF−

⋅= 12 10-6: Cooling to level F2

For resetting the level to 0% during the tests, the following applies:

• in the test menu, set the level to 0%, or • block and subsequently enable the thermal replica or • connect the supply voltage for the protector at current I = 0 A.

10.3.6.16 Check of temperature acquisition PT100 Checking of the correct temperature sensor assignment to the measuring location number on the PT100 board (TI1... TI8) is required. The incoming measured temperatures - assigned to the appropriate measuring location of module PT100 X1/X11=TI1, to X8/X18=TI8 in the menu “Test / Temp.Sensor TI” - can be checked. The temperatures processed in accordance with the configuration, as they are used in the pro-tection module, can be checked for plausibility in the operating measurand display. To simulate temperatures, the Pt100 probes can be replaced by potentiometers. The setting of the potentiometer should be in the range from 90...150 Ω. 100 Ω corresponds to the tempera-ture 20 °C, the resistance of platinum varies by +3.8% at a temperature fluctuation of +10°C.

10.3.6.17 Checking the switch-on protection To check the switch-on protection, the following deserves special attention:

• the effect of impedances only within the set starting condition and • the function (limited in time) after a manual CLOSE signal.

As the check can be performed in analogy to the starting checks, an impedance must be supplied according to the required function and the expected trip time proved. If the overcurrent time protection is used, a starting and/or TRIP suppression which may be re-quired can also be verified.

10.3.6.18 Checking the voltage protection The essential part of the test consists in checking the voltage measurands in the operating measurand display. In addition, the individual functions of the voltage protection which can be selected by setting can be checked by applying the voltages required to this effect.

Start-up


10.3.6.19 Checking the frequency protection ⇒ This is an important check that should not be omitted in the scope of repeat tests. The required checks can be performed by means of a test equipment. The currently measured frequency can be found in the operating measurand display. The set frequency stages can also be verified.

10.3.6.20 Checking the power protection By means of a three-phase test equipment, the required active or reactive powers can be gener-ated. The expectations - especially regarding the power direction - must be checked. The deter-mined powers are indicated in the operating measurand display.

10.3.6.21 Checking the circuit-breaker failure protection

! Important:

When the circuit-breaker failure protection is used and checked, TRIP commands to upstream circuit-breakers can be issued during tests. If this connection is not to be checked, it must be deactivated. All the modes of the circuit-breaker failure protection used must be checked. A TRIP command which is not executed is simulated by a current which is greater than the setting “9308 IminCBF“ and flows for more than the time “9311 tCBF internal“ or “9312 tCBF exter-nal“ after TRIP. The relay outputs selected according to the chosen method of operation of the failure protection must be activated subsequently and be verifiable at the target (e.g. upstream switch). If enabled, a TRIP command can also be generated via the input “9360 Signal CBF exter-nal“. If the TRIP position signal of the switch is integrated in the monitoring, its correct functioning must be checked.

Start-up


10.3.7 Check with primary values The work in accordance with sections 6 and 10.3 must be complete. The secondary test equip-ment must be disconnected.

! Warning!

Only qualified and well-instructed personnel should accomplish tests and trials in connection with primary values. These persons must be familiar with the start-up of protective devices, the operation of high-voltage equipment, network operation and the relevant safety rules and instructions. If testing is performed with primary values, the outgoing feeder to be tested must be switched on.

10.3.7.1 Checking the rotating field and balance For the check with primary values, the operating current must be greater than the value set for “18108 Imin = Line dead“, to enable the staff to evaluate the operating measurands. A rotating voltage field error is signalled once the appropriate timer has expired. A wrong rotating field (in current) can be recognized by the measured negative system current Ineg. The value of the Ineg in this case is approximately equal to the flowing current. The power measurands or the cos φ are well suited to point out a distortion between U and I. An excessive reactive power content or an insufficient cos φ suggest an offset between U and I. In case of unbalances, check whether they correspond to normal operation. If so, the measurand test functions for unbalance must be set to a lower sensitivity. If a wrong rotating voltage field (anti-clockwise) is applied, the voltage terminal connections must be checked and corrected, if necessary. If the calculated earth current IEcalc is unexpectedly high, the winding direction of the current transformer terminals must be checked.

10.3.7.2 Checking the operating measurand display The values displayed on the protector must be compared to the actual operating values. To this effect, the primary values should be displayed. Otherwise, an appropriate conversion of the sec-ondary values is required. For the first putting into operation, the control of the indicated power values is of particular meaning, since phase transposition and distortion of the U and I systems are clearly visible. With correct connection, an approximate ohmic load and power-flow in forward-direction, a positive active power is indicated at a small reactive power. Following transposition mistakes may occur: 1. Connections in voltage path (U system) exchanged

- amongst other things alarm "Phase sequence fault" by voltage path measurand check. 2. Connections in I-system to U-system 180° turned

- negative active power at low reactive power. 3. Connections in I-system to U-system - L1, L2, L3 - cyclically exchanged

4. Connections in I-system exchanged acyclically to U-system

- Ineg is high, P and Q are signalled with value ”0“. 5. One current missing

- Display of insufficient power 6. One current transformer connection is turned 180°

- An earth-fault current IE is generated that leads to an "I-Path disturbed.

D.. 6 IL1 IL2 IL3 Pdisplay Qdisplay L3 L1 L2 negative negative, relatively big connected to L2 L3 L1 negative positive, relatively big

Start-up


10.3.7.3 Checking the direction and other ratings At a load current greater than 0.1⋅In, the image of the power flow direction can be checked. In any case, the power flow existing at present in the system must be known. Set the measurand display so as to display powers. The powers displayed are signed values, so that the power flow is indicated by the sign.

10.3.7.4 Checking the earth fault direction

10.3.7.4.1 Auxiliary solution using the voltage transformer Using the primary system would be the best method to check the correct connection of the sys-tem transformers for the earth-fault direction decision. If the power system management so per-mits, an earth fault has to be inserted. Unfortunately, this is not always possible. In order to nevertheless specify a defined direction, proceed as follows - to this effect, refer to the connec-tion circuits in Fig. 10.3-3 and, for the case that the transformer U4 is used for the displacement voltage, Fig. 10.3-4. Attention - this method requires switching off the earth fault criteria in the protector

• the voltage overshoot of sound phases and • minimum line-to-line voltage.

This is possible in the test menu under "earth fault test".

! Warning!

Perform work only in off circuit and earthed switchgear components! When handling current and voltage transformers, the safety rules must be adhered to! Especially in the case of interfacing in acc. with Fig. 10.3-4, risk prevention measures must be taken, as the busbar voltage transformers can be energized while the outgoing feeder is switched OFF.

• Reports of the measurand check appearing during the test must not be taken into ac-count; optimally the “Supervision U Path” should be switched off. On the other hand, the "Supervision UNE" must be enabled.

• A phase (normally L1) is bypassed in the voltage measurement (see Fig. 10.3-3). This can occur by turning off the fuse voltage transformer or by interrupting the supply to the pro-tection device. A displacement voltage UNE results therefrom, which is lower by approx. the factor 3 (max. 33V) than in case of a full earth fault. (see vector diagram).

• An ohmic current is generated as earth current by means of the auxiliary wire threaded through the cable-type current transformer in Fig. 10.3-3 from the ULE voltage of the subsequent phase L2 and in Fig. 10.3-4 from the UL23 To ensure that the earth current generated artificially has the negative sign like in the system, make sure the threading is in the direction from the cable end in busbar direc-tion. To increase the secondary current and accordingly the resistor value, several turns w can be routed through the cable-type current transformer.

• The series resistor should be selected as follows (value in Ω) to receive a direction output (condition a)):

a) within the compensated system: pn

sn

II

PwR ⋅

>⋅<200 Isolated system:

pn

sn

II

QwR ⋅

>⋅<

80

Ipn, Isn are the rated currents of the cable-type current transformer; P> or Q> are the set values of the earth-fault direction decision, w is number of turns routed through the transformer.

Start-up


For a sufficiently high secondary current, R must at the same time meet the following supplementary condition. This condition is adequate for the evaluation of the sign of the power:

b) Compensated sys-tem: pn

sn

IIwR ⋅⋅< 19000 Isolated sys-

tem: pn

sn

IIwR ⋅⋅< 16000

The dissipation power (in W) for the resistance (in Ω) is determined in general with

RP 3334

> .

Important: The voltage transformer is additionally loaded with this dissipation power!

In the isolated-neutral system and at high set values for the earth-fault direction decision, the direction decision and output thereof via the relay can be omitted. In this case, the sign of the measured power has to be evaluated manually. The advantage of following the above-mentioned method consists in a higher-impedance resistor and thus a lower dissipation power. It only needs the resistor values according supplementary condition b).

Example: compensated system, cable-type current transformer 60/1 and setting P>=0.005 results in R<666 Ω. The supplementary condition requires R<316 Ω. A 270 Ω resistor is selected. Its dissipation power and that of the voltage transformer must be at least 12.4 W. At w= 3 turns a triple resistance value is the result so that R=910 Ω and P>3.7 W can be chosen.

• In the test menu, deactivate the criteria for earth fault.

• In the test menu, track the earth fault measurands.

•

! Warning!

Now switch on the line to generate voltage at the voltage transformer. If the busbar volt-age transformer is used, the line need not be switched on, but only the voltage trans-former.

Important:

In case of interfacing in accordance with Fig. 10.3-4 no reactive power is present due to the phase shift of 0°; thus, no direction can be determined when system adaptation “531 Sys-tem Neutral“ “insulated“ is selected (reactive power direction is evaluated). To test polarity, only the sign of the active power (+ for correct phase angle) can be evaluated in the earth fault test menu.

Evaluation: If both conditions for dimensioning of the series resistor R are complied with, direction output (except selection for "isolated system neutral" and interfacing acc. to Fig. 10.3-4) is possible. . If only condition b) is complied with, the direction can only be determined manually by evaluating the signs of active or reactive power represented on the display. The expected direction accord-ing to the vector diagram is in the present case “forward”. The indication of the signed active and reactive power enables a check of the correct connection to be performed. The sign of the active power is decisive. It should be positive for forward direction (in the direc-tion of the line/load). The sign of the reactive power is also indicative in case of isolated sys-tems. Here, for forward direction (capacitive behaviour), a negative sign should be present. The circuitry acc. to Fig. 10.3-3 generates a positive active and a negative reactive component (oh-mic capacitive behaviour). If this is not confirmed on the operating measurand display, this sug-gests a faulty polarity of a transformer.

Remark: The specified circuitry neglects existing fault currents or existing earth faults. To this effect,

Start-up


fault-free operation or a switched-off line should be a prerequisite (in case of busbar voltage transformers).

After the test, the line is to be switched off, to be earthed and the initial status to be restored. All changes in the device configuration, such as blocking the measurand check and setting the earth-fault criterion in the test menu, must be reset. (As the test menu is exited, the correct earth-fault criterion is activated automatically).

Fig. 10.3-3 Circuitry to check the earth fault direction with UNE calculated

L1

L2

L3

R

X11-6X11-5

X11-2X11-1

X11-3X11-4

U1

U2

U3

IL1

IL2

IL3

DI 1

AO 2

IN

X12-2X12-1

X12-5X12-6

X12-3X12-4

PS

X3-3

X2-2 X2-1

X3-1 X2-3

X3-2

AO 1

PROT

X11-6X11-5

X11-2X11-1

X11-3X11-4

X21-2X21-1

X21-5X21-6

X21-3X21-4

X12-6X12-5

X12-2X12-1

X12-3X12-4

X12-8X12-7

X1-1 X1-2

U4

1A

5A

1A

5A

1A

5A

1A

5A

CO 1

CO 2

CO 3

CO

UL2E

UL1E

UL2E

UL3E

√3*UNE

IE

Σ

P1 S1

P2 S2

P1 S1

P2 S2

A N

a n

Start-up


Fig. 10.3-4 Circuitry to check the earth fault direction, if UNE via transformer U4

10.3.7.4.2 Test by producing a real earth fault

! Warning!

This test makes only sense in systems whose earth current is so small that dangers are ruled out (mostly compensated systems). However, the dangers caused for the insulation of the operating equipment by voltage overshoots in case of an earth fault must be assessed. The remote line end should remain open during the verification. A single-phase earth fault bridge must be attached in an arbitrary place on the line (downstream of the current transformers). After closing the circuit breaker at the end of the line to be checked, the LED display has to be checked for the earth fault direction, or the relay output or the event entry have to be checked regarding the correct direction. If no direction report is to be generated (as the power does not exceed the pickup value), the op-erating measurand display set to the power indication during the earth fault, or the appropriate

L1

L2

L3

R

UL2E UL3E

UNE

IEΣ

P1 S1

P2 S2

P1 S1

P2 S2

A N

a n U1

U2

U3

IL1

IL2

IL3

DI 1

IN

PROT

X11-6X11-5

X11-2X11-1

X11-3X11-4

X21-2X21-1

X21-5X21-6

X21-3X21-4

X12-6X12-5

X12-2X12-1

X12-3X12-4

X12-8X12-7

X1-1 X1-2

U4

1A

5A

1A

5A

1A

5A

1A

5A

A

N

da

dn

Start-up


entry of P and Q in the event memory can also be used for determination of the correct connec-tion. The following applies to the sign relationships of P and Q:

System type setting Direction Sign of P Sign of Q Compensated system forward + any Compensated system reverse - any Isolated system forward any - (capacitive) Isolated system reverse any + (capacitive)

After the test, the line is to be switched off, to be earthed and the initial status to be restored.

10.3.7.5 Checking the voltage transformer polarity U4 = US2 In the case of single-sided supply on the busbar side, the de-energized outgoing feeder can be connected without synchronization. The correct phase angle of the measuring voltage on trans-former U4 for synchronization can be checked by triggering a disturbance record in the test menu (section 5.29.3.1) and subsequent evaluation. In the disturbance record, no phase and amplitude differences between US2 and the appropriate reference voltage must be visible.

Exception: due to phase-rotating operating equipment, the phase was adapted via the software with the setting “9710 phi Correction US2“. This software phase rotation is not effected in the dis-turbance record!

! Important!

For the following test, the CLOSE and TRIP to the circuit-breaker must be interrupted in order to prevent any unintended actuation of the circuit-breaker. Please note that dangerous voltages are applied and comply with the resulting safety provisions for these works.

The following procedure is helpful for settings “9710 phi Correction US2“ deviating from 0°.

The fundamental idea is the tripping of a measuring request by a trial AR. During the synchroni-zation request by this AR, the synchronization measurands can be observed or recorded in COMM-3.

If AR is not already activated, a prerequisite for the trial AR is that • the signal “432 Signal CB ready“ is entered as “connected“ • the AR is enabled • the input “9963 CB ready“ is assigned or, if no AR is used and/or the active signal is

not available, o in the input configuration, the input “9963 CB ready“ - a non-used input - is set

to "N“ negated (which generates an active signal without requiring application of a voltage)

Subsequently - unless already done -, • the function “9800 Synchrocheck AR“ must be enabled • the possibilities to bypass the synchronization “9832 Bypass US1....“, “9833...“,

“9834....“ must be deactivated • the timer “9811 tsync AR“ and the timer “9812 tsyncmax AR“ must be set to a big

value in order to obtain sufficient time to observe the measurands. On the measurand end of the COMM-3 device software, the synchronization measurands can be observed during the trial AR by means of a PC connected to the protector.

Start-up


The relevant differential phase angle appears on the right-hand outside. If CLOSE and TRIP of the circuit-breaker are disconnected, a trial AR can be performed with the outgoing feeder switched ON. To this effect, the menu item “Test / CB Tests“ in the protection system main menu can be used to this effect. If the settings have been performed correctly, the entry “Trial AR“ is available. After starting the trial AR, the measured phase angles and voltage levels, amongst other values, are displayed directly in the COMM-3 measurand window, so that amplitude and phase coinci-dence can be checked. Continuous recording of the measurands (tab "Measurand list") enables semi-automatic logging if recording is adjusted accordingly (operating measurands / settings). Important:

After the check has been completed, the original setting must be re-established.

10.3.7.6 Checking the CB TRIP and CLOSE

! Warning!

When including the circuit-breaker in the check, make sure to avoid any hazards to persons, con-sumers and operating equipment. After a trial AR, the circuit-breaker is normally switched on! ⇒ This is an important check that should not be omitted in the scope of repeat tests. The menu item “Test / CB Tests“ in the protection system main menu provides for a circuit-breaker test in the versions • Trial TRIP and – if possible - • Trial AR. The trial AR is a single-shot TRIP-CLOSE operation, which can only be started under the follow-ing conditions: • Signal “CB ready“ is applied • AR is switched on, does not run and is not blocked. During this test, the connection to the circuit breaker and its functioning is tested entirely using the trip relays.

10.3.7.7 Checking the thermal replica The behaviour of the thermal replica based on its level signalled at the display must be checked under normal conditions at relatively constant currents. The stable final value for the level must be compared to expectations.

Start-up


10.4 Making protector ready for operation After completing all tests, the setting values must be checked once more to make sure that no changes have been made during the test compared to the setpoint values. In the protection system main menu, “Clear events“ can be used to remove the data entered dur-ing the check. Via ”Reset LED“, the protection system’s LEDs and LCDs are set to idle state. If a start is to be performed with the fault and grid fault numbers 0 in the test menu, a ”Reset FltNo/ GrdFlt“ must be performed. If a test switch is available, it must be set to position “operation“ or the test connector must be removed. The secondary circuits of the current paths to the protector must not be provided with a shorting jumper. The protector is ready to operate if – apart from the readiness signal via the green LED “Ready“ and signal contact “51171 Protection ready“, no report is displayed in the protection system main menu and the operating measurand display shows the current values.

Maintenance


11 Maintenance

! Warning !

Before the power supply module PS is removed, its auxiliary supply must be switched off for min. 10 s. Otherwise, there is a risk of an electric shock. Digital protection devices do not require any special maintenance. They do not comprise any bat-tery which might require replacement. In case of hardware or software faults, the self-monitoring system of the device automatically releases an alarm. This guarantees a high availability of the protector that allows extending the inspection cycles to 3 or 5 years. After initial operation, check the device after 0.5...1 year to detect early faults. In case of internal faults detected by the protector, the latter signals them or – in case of serious faults – blocks itself. This state is signalled via the missing readiness or by a warn-ing/malfunction message, i.e. green ”Ready“ LED does not show steady light, reset of signalling relay ”protection available“, red LED flashing (if this default setting, which makes sense, has not been changed), this state is signalled. If it is still possible, the detected faults are saved with time assigned to them in the event memory, and are available for quicker fault analysis. Despite the integrated monitoring features, not all elements of the device can be checked com-pletely. Thus, the above-mentioned cyclic repeat tests and – on inspection of the switchgear, a routine check – should be performed.

11.1 Routine check Thanks to the continuous software and hardware control, a routine check with respect to the characteristics or the operation values can be omitted. Some hardware functions which are not 100% checked by the self-monitoring should be checked manually. An important check is the comparison between the measurands expected and those shown on the protector. Even after the protection starts, a functional check of the protectors can be performed via read-out and analysis of the event and disturbance data memories. Any malfunction messages which may have occurred and warnings are displayed via the LCDs, LEDs or can be recognized in the event memory. The time (clock) of the protector can be checked in the protection system main menu. The cur-rent state of the optocoupler inputs and relay outputs can be checked in the test menu. It is advisable that the time intervals for maintenance of the system be used for protection test as well. After the start-up testing, the first functional check should be performed at the latest after one year, and further checks at intervals of 3 to 5 years. In the following, the minimum tests required are listed: • Accuracy in measuring range: two values of the characteristic of each phase should be

checked, e.g. 0.1⋅In or Un and 1⋅In or Un • Checking the starts in acc. with 10.3.6.5 • Checking the optocoupler inputs in acc. with 10.3.6.1 • Checking the output relay contact circuits; especially the TRIP and CLOSE circuits must be

checked acc. to 10.3.7.5 and 10.3.6.2 • Test communication with PC via serial interfaces • Check the device terminals. It is useful in the scope of tests to identify the events that have been generated during the tests in the protection device and the events signalled to the control system as "test events". For this purpose, the binary signal input "test mode" is to be activated, for example, via the test switch or the test connector. The transferred values are marked with the 'test mode' cause of transmis-sion.

Maintenance


If this activation via the signal input is not enabled, all data items are transferred to the control system as real faults or as operating measurands.

11.2 Troubleshooting If the protector signals a defect, it is advisable to perform the following procedure. 1. First, document the detected state: all LED, LCD indications have to be recorded, and, if pos-

sible, event and disturbance data memories have to be read. 2. Depending on the LED malfunction indication:

• red malfunction LED is lit or flashes, green “Ready” LED is not lit If “protector active by self-monitoring“ is signalled, it must be attempted to switch it

on again (“Setting set/ Setting/ Setting values/ General/ Protector ON/OFF“), other-wise Initialisation of a new run-up by switching off the auxiliary voltage for at least 30 s or by performing a restart of the protector, or a software reset.

• green LED has gone out, no LED lit Check the auxiliary voltage for correct connection and size. If OK, initialisation of a new start-up is effected by switching off the auxiliary voltage for at least 30 s or by a protector restart.

Most malfunction messages will require replacement of the module or repair at the manufac-turer's or supplier's. If no communication can be established through the interface, check the following: • The settings of the interface (Baudrate, parity, address, device address, network address,

ports) on the PC in the management routine of the operating software COMM-3 menu “Edit/change interface data“ must be adjusted to those on the protector (visible in menu ”Identification“).

• When the LAN interface is used, remote parameterization must have been enabled in the menu "Setting set/ Setting / Setting values / Comm.+Subst.Ctrl. / Substation Control“.

• Attempt to read out the identification by means of COMM-3. If the device address, the net-work address, the ports or the baudrate and parity are correct, an information pointing out the connected structure version might appear. This structure version can only communicate with the device software pertaining to it.

12 Storage Devices should be stored in clean and dry rooms in the packaging they have been delivered with. For storage, the specifications in sect. 3.2, page 20, are applicable. It is important that the rela-tive humidity is not allowed to form condensation or ice.

Order data for the PC software COMM-3, SDA 2


13 Order data for the PC software COMM-3, SDA 2

PC Operating Software COMM-3 • Management program (CD) Pl.-No.: 1744 990 00- Design: 10th digit

Full version 0 Upgrade from COMM-2 to 3 1 Update of COMM-3 2 Demo version 9

The CD delivered contains the User Manual as a pdf file.

• Device software Pl.-No.: 1744 991 --- Device type: 8th + 9th digit

All devices [structure versions] 0 0 DM 2 [1004] 1 0 DSRZ(W) 2 [2001] 2 0 DSZ(W) 2 [3007] 3 0 DSZW 4 [3104] 3 1 DSZ 4 [3204] 3 2 DQ2S 2, DQ3S 2 [4008] 4 0 DD 2 [5033] 5 0 DD.. 6 [5601] 5 6 DDS(E) 2 [6002] 6 0 DSRZE 2 [7000] 7 0 DS.. 6 [7603] 7 6

Model 10th digit Current structure version 0 Former structure version 1

When reordering device software, the structure version number of the device to be operated by it must be specified in addition to the above-mentioned PI-No. This structure version can be found on the device nameplate or in the identification menu. Example DSZ 2, Structure version 3001: Pl.-No. 1744 991 301-3001

Graphic software SDA 2 (on COMM-3 - CD) Pl.-No.: 1744 992 000

The CD delivered contains the User Manual as a pdf file.

Manual COMM-3, SDA 2 printed Pl.-No.: 1744 993 0-- Language: 9th digit

German 0 English 1

Manual: 10th digit COMM-3 0 SDA 2 1

SPRECO

N-E-Pxx-D

Dx6 U


300

Sprecher A

utomation D

eutschland Gm

bH

Appendix 1

Appendix 1: Overview of mounting variants

Surface-mounted central unitwith attached control panel

IP40

IP20

IP51

IP40

IP20

IP40 IP40IP40

IP51

IP20IP40IP20 IP 40

Surface-mounted central unitwith detached control panel

IP40

IP20

IP51

Flush-mounted central unit with attached control panel

Appendix 2


25 mm

177

mm

222 mm

14 mm

100 mm

163

mm

Ø4.5 mm

4 mm

14 mm

100 mm

Ø18 mm

Mounting plate

Control unit

160 mm

257 mm

176

mm

212 mm

200 mm

163

mm

M4

M4

M4

M4

LINKX4

CPU7

SERV

LAN1

CP

X6

R

TR

ACT

X5T

RT

T

LAN2

LINK

ACT

X3

X2

R

R

T R

X1

T

P7STAT

1

PS DIU10C4

X5

2X6

X72

3

1

23

13

X531

2

X2

T

X4

X3

R 2X3

X41

32

3

321

61

54

X2

X1

55

123

6123

6

X143

12

43

12

S CZZ Z Z

1

X331

10X 2

3

1X9

X8

2

23

PROT

5

78

6

2

43

1

21

1

1X7

X6

2

32

1

1

X5

X4

2X11

2

21

1X3

X2

2

2

1

109

X1

F

6

X21

3

5

4

2

1

F F

M4

Appendix 2: Dimensional diagram, surface-mounted with separately mounted control panel

Appendix 3


Appendix 3: Dimensional diagram, with attached hinged mounted control panel

232/2571) mm 25 mm

Control panel

Control unit

Mounting plate

Hinged control panel

M 4

M 4

M4

M4

M4

M4

200 mm

163

mm

M4

25 mm

!

1) 232 mm (standard) part-no.: 94.2.008.52.01/02 (left/right), 257 mm (for RS422/485) part-no.: 94.2.008.52.01/02 (left/right)

Appendix 4 + Appendix 5


Cabinet door

Control unit

Control panel

160 mm

257 mm

14 mm

100 mm

163

mm

Ø4.5 mm

4 mm

14 mm

100 mm

Ø18 mm

M4

M4

M4

M4

M4

Appendix 4: Dimensional diagram, control unit, flush-mounted with attached control panel

1

PS DIU10C4

X5

2X6

X72

3

1

23

13

X531

2

X2

T

X4

X3

R2X3

X41

32

3

321

61

54

X2

X1

55

123

6

123

6

X143

12

43

12

S CZ

LIN K

X4

CPU9

SER

VLA

N1

CP

X6

R

T

R

AC T

X5T

RT

T

X2

R

R

T R

X1

T

P9STAT M4

M4

M6

M6

Position 1

Position 3

Position 2

24 TE: 159 mm / 40 TE: 240 mm / 84 TE: 464 mm

Position 1Position 2Position 3

24 HP: 159 mm / 40 HP: 240 mm / 84 HP: 464 mm

105

mm

60 mm

90 mm1

X331

10X 2

3

1X9

X8

2

23

PROT

5

78

6

2

43

1

21

1

1X7

X6

2

32

1

1

X5

X4

2X11

2

21

1X3

X2

2

2

1

109

X1

F

6

X21

3

5

4

2

1

F FZ

Appendix 5: Dimensional diagram, control unit with variable mounting brackets

Appendix 6


Device is in service LED

Communication error LED

Local control LED

24 free con-figurable LED

Insert strip

Opening for insertion

Selection of display

pages

free configurable keylock switch

Control keys

Appendix 6: View of control panel Remark:

A template file for Microsoft Word for Windows as of version 7 (SPRECON-E-P-D LED.dot) is provided together with the operating software COMM-3. Using this template the insertable strips can be made easily. Thus, the LED assignment may be printed, e.g. on solid paper (>80g) and subsequently by cut in stripes. The stripes are then inserted from the bottom by slight to-and-fro movements. This template file can be made available on request.

SPRECO

N-E-Pxx-D

Dx6 U


305

Sprecher A

utomation D

eutschland Gm

bH

Appendix 7

1) not accessible for protector

Appendix 7: Terminal arrangement of the modules relevant for protection

Protection module

P RO T F FF Current

transformer

Digital outputs

Universal digital inputs

DO 7 DO 8

DO 5 DO 6

DO 3 DO 4

DO 2

DO 1

I 1A

I L1

I 5A

I 1A

I L2

I 5A

I 1A I N

I 5 A

I 1A I L3

I 5 A

UL1

UL2

UL3

U4

- + U E

- + U E

- + U E

DI 2 - + U E

DI 1 - + U E 1

2

3

4

5

6

X21

PINPIN 1 2 3

4 5 6

X11

1

2

3

4

5

6

7

8

X12

X10

1

2

3

X9

1

2

3

X8

1

2

3

X71

2

1

2

3

X6

X5

X4

X3

X2

X1

PIN

1

2

1

2

1

2

1

2

1

2

Current transformer

Voltagetransformer

DI 3

DI 4

DI 5

PSS C

X 1 7

X 1 6

X 1 5

X 1 4

X 1 3

X 1 2

X 1 1

1 2 3 4

6 5

1 2 3

PIN

1 2 3

1 2 3

1 2 3

1 2 3

1 2 3 4

6 5

CO 3

CO 4

DI 7

DI 8

DI 5

DI 6

DI 3

DI 4

DI 1

DI 2

CO 1

CO 2

DI 9

DI 10

Universal digital inputs

Command outputs

-VI

-VI

-VI

-VI

-VI

-VI

-VI

-VI

-VI

-VI

RS232

PIN

X14

5

6

1

2

3

3

2

1

X5

X4

X2

1

2

3

1

2

3

X3

Power supply

PO1*)

PO2*)

AO 1

AO 1

SUB D 9 m

Alarm-/command

outputs AO

Remote service

Power relayoutputs PO 1)

+

--

Vaux

Power supply module(incl. Command module)

X2

X1

X3

X6

X5

X8

X7

PT100 inputs

123

123

123

123

X 1 2

X 1 1

X 1 4

X 1 3

X 1 6

X 1 5

X 1 8

X 1 7

PT100 inputs

1 2 3

1 2 3

1 2 3

1 2 3

ϑ

TI5

ϑ

ϑ

TI6

ϑ

ϑ

TI7

ϑ

ϑ

TI 8

ϑ

123

1 2 3 ϑ

TI4

ϑ

123

1 2 3 ϑ

TI3

ϑ

123

1 2 3 ϑ

TI 2

ϑ

123

4 wire r 1 2 3 ϑ ϑ

4 wire w2/4 wire r2/4 wire wTGND1

TI1

Temperature capture module

PT100N

Pin Pin

4 wire r4 wire w

4 wire r4 wire w

4 wire r4 wire w

4 wire r4 wire w

4 wire r4 wire w

4 wire r4 wire w

4 wire r4 wire w

X4

TI1

TI5

TI6

TI7

TI 8

TI 4

TI3

TI22/4 wire r2/4 wire wTGND2

2/4 wire r2/4 wire wTGND3






Appendix 8


CO 1

CO 2

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

U1

U2

auxiliary voltageUaux

U3

IL1

IL2

IL3

DI 1

DI 2

DI 3

DI 4

DI 5

AO 2

L(+) L(-)

Protection relevant connections only and without module PT100

IN

L1

L2

L3

X12-2 X12-1

X12-5 X12-6

X12-3 X12-4

PS

X3-3

X2-2 X2-1

X3-1 X2-3

X3-2

AO 1

DO 2

DO 3DO 4

DO 5DO 6

DO 1X6-3

PROT X6-1 X6-2

X7-1 X7-2 X8-1 X8-2 X8-3 X9-1 X9-2 X9-3

X10-1 X10-2 X10-3

DO 7DO 8

PROT

X11-6X11-5

X11-2X11-1

X11-3X11-4

X21-2X21-1

X21-5X21-6

X21-3X21-4

X12-6X12-5

X12-2X12-1

X12-3X12-4

X12-8X12-7

X2-1 X2-2

X1-1 X1-2

U4

1A

5A

1A

5A

1A

5A

1A

5A

X5-2 X5-1

X3-2 X3-1

X4-1 X4-2

X13-1PS

X14-1X14-2

X13-2X13-3

DI 1

DI 2

DI 3

DI 4

DI 5

DI 6

DI 7

DI 8

DI 9

DI 10+-

(~)

X14-3

X15-3X16-1

X15-1X15-2

X16-2

X17-2X17-3

X16-3X17-1

X5-2 X5-3

X5-1

CO 3

CO 4

Σ P1 S1

P2 S2

P1 S1

P2 S2

A N

a n

Appendix 8: Connection diagram with connection example In=1 A

Appendix 9


IL1

IL2

IL3

L1

L2

L3 PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-3

1A

5A

1A

5A

1A

5A

DD 6

P1

P2

S1

S2

Appendix 9: Connection versions in measuring circuits

Fig. 11.2-1 Connection to current transformer

Fig. 11.2-2 Connection to two phase-current transformers – inadmissible for earthed systems

In Figures connections are shown for In=1 A. For In= 5 A

connect upper wire to instead to X11-2 X11-1 X11-5 X11-4 X21-2 X21-1 X21-5 X21-4

Common return wires (X11-3, -6, X21-3, -6) stay at the drawn positions.

IL1

IL2

IL3

IN

L1

L2

L3PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-5 X21-6

X21-3 X21-4

1A

5A

1A

5A

1A

5A

1A

5A

DDE 6, DDEY 6

Earthing of cable shield needs to be carried out as displayed!

P1

P2

P1

P2

S1

S2

S1

S2

Use only for earth-fault direction decision

IL1

IL2

IL3

IN

PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-5 X21-6

X21-3 X21-4

1A

5A

1A

5A

1A

5A

1A

5A

IL1

IL2

IL3

L1

L2

L3 PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-3

1A

5A

1A

5A

1A

5A

DD 6

P1

P2

S1

S2

L1

L2

L3

P1

P2

S1

S2

DDE 6, DDEY 6

insensitive

This connection is not to be favoured. Secure starting conditions for double earth-faults are required.

IL1

IL2

IL3

IN

L1

L2

L3PROT

X11-6 X11-5

X11-2 X11-1

X11-3 X11-4

X21-2 X21-1

X21-5 X21-6

X21-3 X21-4

1A

5A

1A

5A

1A

5A

1A

5A

DDE 6, DDEY 6

Earthing of cable shield needs to be carried out as displayed!

P1

P2

P1

P2

S1

S2

S1

S2

Appendix 9


PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DD 6, DDE 6, DDEY 6

a

n

A

N

Advantage: voltage memory is available at switch on to a short-line fault

Fig. 11.2-3 Variants for connection to voltage transformers

da da da

dn dn dn

PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DDEY 6

336 Usage VT4: UNE

A A A

N N N

a n A N

a n A N

a n A N

da

da

da

dn

dn

dn

L1

L2

L3

PROT

U1

U2

U3X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DDEY 6 336 Usage VT4: UNE

A

A

A

N

N

N

a

a

a

n

n

n

Fig. 11.2-4 Variants for connection to voltage transformers for DDEY 6

PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

a n A N

DD 6, DDE 6, DDEY 6

a n A N

a n A N

Appendix 9


a

n

PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DDEY 6

arbitrary L-E vol tage

336 Usage VT4: Usync

a n A N

A

N

a

n

PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DDEY 6

Arbitrary linked voltage considering order at X12- 7-8: L1-L2 / L2-L3 / L3-L1


a n A N

A

N

PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DDEY 6


a b

A B

a n A N

connection for voltage UL1-2

analogue for voltage UL2- 3

PROT

U1

U2

U3

L1

L2

L3

X12-6 X12-5

X12-2 X12-1

X12-3 X12-4

X12-8 X12-7

U4

DDEY 6

connection for voltage UL3-1


a b

A B

a n A N

Fig. 11.2-5 Examples for connection of synchronization voltage US2 for DDEY 6

Appendix 10: Connection of temperature sensors to PT100 module

Fig. 11.2-6 Connection of temperature sensors to the PT100 module

Xn 1

2

3

X1n

GND

PT 100Sensor

Xn 1

2

3

X1n

GND

PT100Sensor

1 2 3

1 2 3

4-wire Connection for a more exact measuring

2-wire Connection

Appendix 11


Appendix 11: Settings DDx 6

Data regarding the protection part Type SPRECON-E-P__-DD__ 6 Order No.: SPRECON-E-P- - DD Serial number: Hardware version: changed:

Software version: changed:

Structure version: 5601 changed:

Device address: User password:

Table 10 Equipment adaptation

Limit value Function module Ad-dress Setting

lower upper Alternatives Delivery Selec-

tion Device 631 Temperature Sensors connected Adaptation not connected (X) 632 Temperature 1 connected not connected (X) 633 Temperature 2 connected not connected (X) 634 Temperature 3 connected not connected (X) 635 Temperature 4 connected not connected (X) 636 Temperature 5 connected not connected (X) CB Adaptation 430 Sig. CB Manual Close available X not available 432 Signal CB ready connected X not connected 433 CB Tripped Signal connected not connected X 434 TripCircuitSupervision disabled X with 1DI with 2DI 498 BlockageTripCircSv connected not connected (X) 411 t TripCircuitSuperv. 0.5 s 600.0 s 2.0 s sTransformer 330 In CT sec. IL 1 A X Adaptation 5 A Part 1 301 In CT prim. IL 2 A 6000 A 300 A A 331 IL CT Earthing Line End X Busbar End 332 In CT sec. IE 1 A X 5 A 302 In CT prim. IE 2 A 6000 A 60 A A 333 IE CT Earthing Line End X Busbar End 334 Un VT sec. 100 V X 110 V 115 V 120 V 303 Un VT prim. 1.0 kV 400 kV 10 kV kV 335 Fuse Voltage Transf. connected X not connected 339 P,Q Display normal X inverted

Appendix 11


Limit value Function module Ad-dress Setting


tion Transf. 336 Usage VT4 Synchronisation Usync (X) Adaptation Residual Voltage UNE Part 2 337 Un VT sec. U4 100 V (X) 110 V 115 V 120 V 304 Un VT prim. U4 1.0 kV 400 kV (10 kV) kV 338 Fuse Voltage Transf. U4 connected (X) not connected Characteristic 230 No.of Character.Sets 1 X Set 2 3 231 CharSetSelectByInput enabled disabled (X) 232 Characteristic Set 1 active (X) 2 o. 3 o. 4 active 233 Characteristic Set 2 active 3 o. 4 active 234 Characteristic Set 3 active 4 active 235 CSSwitch at GenStart enabled (X) disabled

Table 11 System Adaptation

Limit value Function module

Ad-dress Setting lower upper Alternatives Delivery

Selection

Func-tion

group

Ad-dress

Set-ting

System- 530 Grid Frequency 50Hz (X) Adaptation 60Hz 531 System Neutral earthed insulated X compensated 532 SDLRE Automatic connected not connected X 501 Real Part Earth Fact 0 9.99 1.00 502 Imag.Part Earth Fact -9.99 9.99 0.00 533 Phase Rotation Right Handed (L123) X Left Handed (L132) 534 Phase Rot. Reversal connected not connected X

Appendix 11


Table 12 Protection Modules


Ad-dress Setting lower upper Alternatives Delivery 1st

Set 2nd Set

3rd Set

4th Set

Measurand 18108 Imin = Line dead 0.03 0.30 In 0.10 In Check 18100 Supervision I Path enabled X disabled 18198 Blockage Check IPath connected not connected X 18109 Imin Unbalance 0.10 1.00 In 0.3 In 18101 ILmax/ILmin=Unbalanc 1.10 1.50 1.20 18130 Supervision I Sum enabled X disabled 18102 Isum> 0.10 2.00 0.20 In 18107 fstab Isum> 0.10 0.90 0.50 18111 tI Time Malf. I Path 0.1 60.0s 10 s 18208 Umin=min. Voltage 0.005Un 0.060Un 0.02⋅Un 18200 Supervision U-Path enabled X disabled 18298 Blockage Check UPath connected not connected X 18209 Umin Unbalance 0.10⋅Un 1.00⋅Un 0.30⋅Un 18201 ULLmax/ULLmin Unbal. 1.10 1.50 1.40 18300 Supervision UNE enabled X disabled 18398 Blockage Check UNE connected not connected X 18335 Value for UNE Check calculated (X) measured 18301 UNE>Check 0.05⋅Un 1.00⋅Un 0.50⋅Un 18211 tU Time Malf. U Path 0.1 s 90.0 s 10 s Direction 1900 Short Circ.Direction enabled X Decision disabled 1998 Blockage SCD connected not connected X 1905 Charact.Angle SCD 10° 80° 45 ° 1908 Umem if ULL < 0.001Un 0.06⋅Un 0.01⋅Un 1911 Validity Umem 0.10 s 5.00 s 2.00 s 2900 Earth SC Direction enabled (X) disabled 2998 Blockage ESCD connected not connected (X) 2905 Charact.Angle ESCD 10° 80° (45 °) 2930 SDLRE:TRIP by IE Dir enabled disabled (X) 2933 Value for IE ESCD calculated (X) measured 2935 Value for UNE ESCD calculated (X) measured 2902 UNEmin ESCD 0.003Un 0.10⋅Un 0.003⋅Un

Appendix 11




Set 2nd Set

3rd Set

4th Set

Dist (U-) 5800 Dist (U-)I Start enabled X I-Start disabled 5898 Blockage(U-) I Start connected not connected X 5830 (U-) I Start Program voltage independent X LL:ULL LE:ULE LL:ULL LE:ULL

LL:ULE LE:ULE LL:I>> LE:ULE

5831 I>>Dist Start independent of Imax (X)

depending on Imax 5801 I> 0.10 In 4.00 In (0.50 In) 5802 ULL(I>) 0.10 Un 1.10 Un (0.20 Un) 5803 ULE(I>) 0.10 1.1 Un/√3 Attention:LL:Un,LE:Un /√3 (0.2Un/√3) 5811 I>> 0.20 In 10.00 In 2.00 In 5812 ULL(I>>) 0.10 Un 1.10 Un (0.70 Un) 5813 ULE(I>>) 0.10 1.5 Un/√3 Attention:LL:Un,LE:Un /√3 (0.7Un/√3) Z<-Start 5900 Z< Impedance Start enabled disabled X 5998 Blockage Z< connected not connected (X) 5904 Imin Z< 0.10 In 1.00 In (0.30 In) 5901 Zs*In/A 10.0 Ω 200.0 Ω (40.0 Ω) 5902 Xs*In/A forward 10.0 Ω 400.0 Ω (100.0 Ω) 5903 Xs*In/A reverse 10.0 Ω 400.0 Ω (60.0 Ω) 5930 Z< Monitoring of: LL+LE loops only LL loops (X) only LE loops 5905 Angle ZLL I.Quadr. 20° 80° (40°) 5906 Angle ZLL II.Quadr. 20° 80° (70°) 5907 Angle ZLL III.Quadr. 20° 80° (40°) 5908 Angle ZLL IV.Quadr. 20° 80° (70°) 5909 RsmaxLL*In/A Resist. 10.0 Ω 400.0 Ω (100.0 Ω) 5915 Angle ZLE I.Quadr. 20° 80° (40°) 5916 Angle ZLE II.Quadr. 20° 80° (70°) 5917 Angle ZLE III.Quadr. 20° 80° (40°) 5918 Angle ZLE IV.Quadr. 20° 80° (70°) 5919 RsmaxLE*In/A Resist. 10.0 Ω 400.0 Ω (100.0 Ω)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Loop 4900 IE> EarthFaultCrit. enabled X Determina- disabled tion 4998 Blockage IE>EFC connected not connected X 4901 IE>EFC 0.05 In 25.00 In 0.50 In 4902 Bias.IE>EFC from IL 0.20 In 10.00 In 2.00 In 4903 Bias.Factor IE>EFC 0.00 0.50 0.40 4904 Reset Ratio IE>EFC 0.20 0.97 0.95 4930 UNE>EarthFaultCrit. enabled X disabled 4996 Blockage UNE>EFC connected not connected X 4905 UNE>EFC 0.02 Un 1.00 Un 0.10 Un 4906 ULLmax/ULLmin asym. 1.10 2.00 1.25 4931 EarthFault if IE>EFC and UNE>EFC IE>EFC or UNE>EFC (X) 4932 EarthFault if IE>and UNE>EFC+asym X IE> and UNE>EFC IE> or UNE>EFC+asym 4933 Loop 2pol.+E Smallest Impedance (X) LL Loop LE Loop Leading Ph. LE Loop Lagging Ph. 4934 Loop 3pol. Smallest Impedance (X) Always L3-L1 3xLE:L1-E else L3-L1 3xLE:L3-E else L3-L1 4935 Loop 2pol. Smallest Impedance L3-L1-L2 non-cyclic X L1-L3-L2 non-cyclic L2-L1-L3 non-cyclic L1-L2-L3 non-cyclic L3-L2-L1 non-cyclic L2-L3-L1 non-cyclic L3-L1-L2-L3 cyclic L1-L3-L2-L1 cyclic 4936 Loop 3pol. Smallest Impedance X Program as 2pol. 4911 t1p at 1pole Start 0.00 s 9.99 s 0.05 s Distance 5000 Distance Detection enabled X Module disabled Part1 5030 Time Start with General Start X with Zone Start 5001 Inclin.Angle Polygon 45° 90° 45° 5002 Red.AnglePolygonZ1(x) 0° 40° 0° 5100 Zone Z1,t1 enabled X disabled 5198 Blockage Z1,t1 enabled disabled X 5131 Direction Z1,t1 forward X reverse non-directional 5101 X1s*In/A Reactance 0.05 Ω 240.0 Ω 2.00 Ω 5102 R1sLL*In/A Resist. 0.05 Ω 240.0 Ω 1.50 Ω 5103 R1sLE*In/A Resist. 0.05 Ω 240.0 Ω 2.00 Ω 5111 t1 Time Zone Z1 0.00 s 15.00 s 0.00 s

Appendix 11




Set 2nd Set

3rd Set

4th Set

Distance 5200 Zone Z1x,t1x enabled Module disabled X Part2 5298 Blockage Z1x,t1x enabled disabled (X) 5231 Direction Z1x,t1x forward (X) reverse non-directional 5201 X1xs*In/A Reactance 0.05 Ω 240.0 Ω (3.00 Ω) 5202 R1xsLL*In/A Resist. 0.05 Ω 240.0 Ω (2.25 Ω) 5203 R1xsLE*In/A Resist. 0.05 Ω 240.0 Ω (3.00 Ω) 5211 t1x Time Zone Z1x 0.00 s 15.00 s (0.00 s) 5230 Signal Z1x,t1x connected not connected (X) 5300 Zone Z2,t2 enabled disabled X 5398 Blockage Z2,t2 enabled disabled (X) 5331 Direction Z2,t2 forward (X) reverse non-directional 5301 X2s*In/A Reactance 0.05 Ω 240.0 Ω (4.00 Ω) 5302 R2sLL*In/A Resist. 0.05 Ω 240.0 Ω (3.00 Ω) 5303 R2sLE*In/A Resist. 0.05 Ω 240.0 Ω (4.00 Ω) 5311 t2 Time Zone Z2 0.00 s 15.00 s (0.50 s) 5400 Zone Z3,t3 enabled disabled X 5498 Blockage Z3,t3 enabled disabled (X) 5431 Direction Z3,t3 forward (X) reverse non-directional 5401 X3s*In/A Reactance 0.05 Ω 240.0 Ω (10.00 Ω) 5402 R3sLL*In/A Resist. 0.05 Ω 240.0 Ω (8.00 Ω) 5403 R3sLE*In/A Resist. 0.05 Ω 240.0 Ω (10.00 Ω) 5411 t3 Time Zone Z3 0.00 s 15.00 s (2.00 s) 5500 Zone Z4,t4 enabled disabled X 5598 Blockage Z4,t4 enabled disabled (X) 5531 Direction Z4,t4 forward (X) reverse non-directional 5501 X4s*In/A Reactance 0.05 Ω 240.0 Ω (20.00 Ω) 5502 R4sLL*In/A Resist. 0.05 Ω 240.0 Ω (16.00 Ω) 5503 R4sLE*In/A Resist. 0.05 Ω 240.0 Ω (20.00 Ω) 5511 t4 Time Zone Z4 0.00 s 15.00 s (3.00 s) 5600 Direct.BackupTime t5 enabled X disabled 5698 Blockage t5 enabled disabled X 5631 Direction t5 forward X reverse non-directional 5611 t5 Dir.Backup Time 0.00 s 15.00 s 5.00 s

Appendix 11




Set 2nd Set

3rd Set

4th Set

Distance 5700 Undir. Time Limit t6 enabled X Module disabled Part 3 5798 Blockage t6 enabled disabled X 5711 t6 Time Limit 0.00 s 15.00 s 7.50 s Earthfault 7000 Earthfault Detection enabled X Detection disabled 7098 Blockage Earthf.Det. connected not connected X 7035 Value for UNE EF calculated (X) measured 7002 UNE>EF 0.01 Un 1.00 Un 0.30 Un 7014 tUNE>EF Time f. UNE> 0.0 s 60.0 s 2.5 s 7030 TRIP at Earthfault enabled disabled X 7031 EarthFaultDirection enabled X disabled 7032 TRIP at Earthfault forward (X) reverse non-directional 7033 TRIP at Earthfault only if P>/fb o. Q>/fb (X) indep. of power 7001 P> resp. Q> pickup 0.002 2.5 In⋅Un 0.1 In⋅Un 7011 tTRIP if Earthfault 0.00 s 60.00 s (1.00 s) 7034 Earthf.Direct. ERER connected not connected (X) Reclose 4500 Reclose Lockout enabled Lockout disabled X 4598 Blockage ReclLockout connected not connected (X)

Appendix 11




Set 2nd Set

3rd Set

4th Set

IL> (Emerg.) 1100 IL> Start enabled X OTP disabled Part 1 1198 Blockage IL> connected not connected X 1115 t1p at 1pole IL> 0.00 s 9.99 s 0.00 s 1132 IL> Timer Module Definite Time X long-time inverse inverse very inverse extremely inverse 1134 ILx> Phase Start independent von Imax (X) only if ILx >2/3Imax 1136 IL>+ErrorUPath/EOTP not if error U path even if error U path only ifErrorU path X 1131 IL> Direction forward X reverse non-directional 1101 IL> Definite Time 0.10 In 40.00 In 2.00 In 1102 IL> Inverse Time 0.10 In 4.00 In (2.00 In) 1104 Reset Ratio IL> 0.20 0.97 0.95 1111 tIL> Time 0.00 s 60.00 s 5.00 s 1112 tL> Time Factor 0.05 3.50 (0.20) 1113 tIL>max Time Delay 10.0 s 4200.0s (60.0 s) 1200 IL>> Start enabled disabled X 1298 Blockage IL>> connected not connected (X) 1234 ILx>> Phase Start independent von Imax (X) only if ILx >2/3Imax 1236 IL>>+ ErrorUPath/EOTP not if error U path even if error U path (X) only ifErrorU path 1231 IL>> Direction forward (X) reverse non-directional 1201 IL>> 0.10 In 40.00 In (5.00 In) 1204 Reset Ratio IL>> 0.20 0.97 (0.95) 1211 tIL>> Time 0.00 s 60.00 s (0.00 s) 1300 IL>>> Start enabled disabled X 1398 Blockage IL>>> connected not connected (X) 1334 ILx>>> Phase Start independent von Imax (X) only if ILx >2/3Imax 1336 IL>>>+ ErrorUPath/EOTP not if error U path even if error U path (X) only ifErrorU path 1331 IL>>> Direction forward (X) reverse non-directional 1301 IL>>> 0.10 In 40.00 In (15 In) 1304 Reset Ratio IL>>> 0.20 0.97 (0.95) 1311 tIL>>> Time 0.00 s 60.00 s (0 s)

Appendix 11




Set 2nd Set

3rd Set

4th Set

IL> (Emerg.) 1400 IL>>>> Start enabled OTP disabled X Part 2 1498 Blockage IL>>>> connected not connected (X) 1434 ILx>>>> Phase Start independent von Imax (X) only if ILx >2/3Imax 1436 IL>>>>+ErrorUPath/EOTP not if error U path even if error U path (X) only ifErrorU path 1431 IL>>>> Direction forward reverse non-directional (X) 1401 IL>>>> 0.10 In 40.00 In (30 In) 1404 Reset Ratio IL>>>> 0.20 0.97 (0.95) 1411 tIL>>>> Time 0.00 s 60.00 s (0 s) IE> (Emerg.) 2100 IE> Start enabled X OTP disabled Part 1 2198 Blockage IE> connected not connected X 2137 IE> Start not if IL/Dist Start X even if IL/DistStart only if IL/DistStart 2138 IE> Start indep. of tUNE>EF after tUNE>EF (X) 2133 Value for IE> measured calculated X 2132 IE> Timer Module Definite Time X long-time inverse inverse very inverse extremely inverse 2136 IE>+ ErrorUPath/EOTP not if error U path even if error U path X only ifErrorU path 2131 IE> Direction forward X reverse non-directional 2101 IE> Definite Time 1 0.05 In 25.00 In 0.50 In 2109 Bias.IE> from IL 0.20 In 10.00 In 2.00 In 2107 Biasing Factor IE> 0.00 0.50 0.40 2103 IE>Definit. Time sens 1 0.010 In 5.000 In (0.1 In) 2105 IE>Definit. Time sens 1 0.005 In 2.500 In (0.05 In) 2102 IE> Inverse Time 1 0.05 In 4.00 In (0.50 In) 2106 IE> Inv. Time sens. 1 0.010 In 0.800 In (0.10 In) 2108 IE> Inv. Time sens. 1 0.005 In 0.400 In (0.05 In) 2104 Reset Ratio IE> 0.20 0.97 0.95 2111 tIE> Time 0.00 s 60.00 s 5.00 s 2112 tE> Time Factor 0.05 3.50 (0.20) 2113 tIE>max Time Delay 10.0 s 4200.0s (60.0 s)

1 depends on IE current transformer in the device

Appendix 11




Set 2nd Set

3rd Set

4th Set

IE> (Emerg.) 2200 IE>> Start enabled OTP disabled X Part 2 2298 Blockage IE>> connected not connected (X) 2237 IE>> Start not if IL/Dist Start (X) even if IL/DistStart only if IL/DistStart 2238 IE>> Start indep. of tUNE>EF after tUNE>EF (X) 2233 Value for IE>> measured calculated (X) 2236 IE>>+ErrorUPath/EOTP not if error U path even if error U path (X) only ifErrorU path 2231 IE>> Direction forward (X) reverse non-directional 2201 IE>> 1 0.05 In 25.00 In (2.50 In) 2203 IE>> sensitive 1 0.010 In 5.000 In (0.5 In) 2205 IE>> sensitive 1 0.005 In 2.500 In (0.25 In) 2204 Reset Ratio IE>> 0.20 0.97 (0.95) 2211 tIE>> Time 0.00 s 60.00 s (0.10 s) 2300 IE>>> Start enabled disabled X 2398 Blockage IE>>> connected not connected (X) 2337 IE>>> Start not if IL/Dist Start (X) even if IL/DistStart only if IL/DistStart 2338 IE>>> Start indep. of tUNE>EF after tUNE>EF (X) 2333 Value for IE>>> measured calculated (X) 2336 IE>>>+ ErrorUPath/EOTP not if error U path even if error U path (X) only ifErrorU path 2331 IE>>> Direction forward (X) reverse non-directional 2301 IE>>> 1 0.05 In 25.00 In (5.00 In) 2303 IE>>> sensitive 1 0.010 In 5.000 In (1.0 In) 2305 IE>>> sensitive 1 0.005 In 2.500 In (0.50 In) 2304 Reset Ratio IE>>> 0.20 0.97 (0.95) 2311 tIE>>> Time 0.00 s 60.00 s (0.00 s)


Appendix 11




Set 2nd Set

3rd Set

4th Set

IE> (Emerg.) 2400 IE>>>> Start enabled OTP disabled X Part 3 2498 BlockageIE>>>> connected not connected (X) 2437 IE>>>> Start not if IL/Dist Start (X) even if IL/DistStart only if IL/DistStart 2438 IE>>>> Start indep. of tUNE>EF after tUNE>EF (X) 2433 Value for IE>>>> measured calculated (X) 2436 IE>>>>+ ErrorU-

Path/EOTP not if error U path

even if error U path (X) only ifErrorU path 2431 IE>>>> Direction forward (X) reverse non-directional 2401 IE>>>> 1 0.05 In 25.00 In (10.0 In) 2403 IE>>>> sensitive1 0.010 In 5.000 In (2.00 In) 2405 IE>>>> sensitive1 0.005 In 2.500 In (1.00 In) 2404 Reset Ratio E>>>> 0.20 0.97 (0.95) 2411 tIE>>>> Time 0.00 s 60.00 s (0.00 s) 2800 IE>int, interm. fault enabled disabled X 2898 BlockageIE>int connected not connected (X) 2833 Value for E>int calculated measured (X) 2801 IE>int 0.05 In 25.00 In (0.50 In) 2803 IE>int sensitive 0.010 In 5.000 In (0.100 In) 2805 IE>int sensitive 0.005 In 2.500 In (0.050 In) 2804 Reset Ratio IE>int 0.20 0.97 (0.95) 2811 tIE>int Time 0.00 s 60.00 s (15.00 s) 2816 tIE>intProlong. Time 0.00 s 5.00 s (0.10 s) 2817 tIE>intSumReset Time 0.1 s 600.0 s (300.0 s) 2808 IE>int EntryCounter 1 9 (3)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Switch-On 8000 Switch-On Protection enabled X Protection disabled 8098 Blockage SOTF connected not connected X 8005 top Operat.Time SOTF 0.01 s 60.00 s 3.00 s 8400 Distance TRIP SOTF enabled X disabled 8430 TRIP SOTF undelayed if Distance Start if Z in Z1 if Z in Z1x if Z in Z2 X 8100 IL>SOTF Start enabled disabled X 8134 ILx>SOTF Phase Start independent of Imax (X) only if ILx >2/3Imax 8136 IL>SOTF if ErrorUPath not if error U path even if error U path (X) only ifErrorU path 8131 IL>SOTF Direction forward reverse (X) 8101 IL>SOTF 0.10 In 40.00 In (5.00 In) 8104 Reset Ratio IL>SOTF 0.20 0.97 (0.95) 8111 tIL>SOTF Time 0.00 s 9.99 s (0.01 s) 8200 IE>SOTF Start enabled disabled X 8237 IE>SOTF Start not if IL/Dist Start (X) even if IL/Dist Start only if IL/Dist Start 8238 IE>SOTF Start indep. of tUNE>EF after tUNE>EF (X) 8233 Value for IE>SOTF measured calculated (X) 8236 IE>SOTF if ErrorUPath not if error U path even if error U path (X) only ifErrorU path 8231 IE>SOTF Direction forward reverse (X) non-directional 8201 IE>SOTF1 0.05 In 25.00 In (2.50 In) 8203 IE>SOTF sensitive1 0.010 In 5.000 In (0.500 In) 8205 IE>SOTF sensitive1 0.005 In 2.500 In (0.250 In) 8204 Reset Ratio IE>SOTF 0.20 0.97 (0.95) 8211 tIE>SOTF Time 0.00 s 9.99 s (0.10 s) 8300 Ineg>SOTF Start enabled disabled X 8301 Ineg>SOTF 0.10 In 3.50 In (0.80 In) 8304 Reset Ratio Ineg>SOTF 0.20 0.97 (0.95) 8311 tIneg>SOTF Time 0.00 s 9.99 s (0.50 s) 8030 ISOTF: Suppression Trip by I> X Start by I>

Appendix 11




Set 2nd Set

3rd Set

4th Set

Negative 3100 Ineg> Start enabled Sequence I disabled X 3198 Blockage Ineg> connected not connected (X) 3132 Ineg> Timer Module Definite Time (X) long-time inverse inverse very inverse extremely inverse 3101 Ineg> Definite Time 0.10 In 3.50 In (0.20 In) 3102 Ineg> Inverse Time 0.10 In 3.50 In (0.20 In) 3104 Reset Ratio Ineg > 0.20 0.97 (0.95) 3111 tIneg> Time 0.00 s 60.00 s (3.00 s) 3112 tIneg> Time Factor 0.05 3.50 (0.20) 3113 tIneg>max Time Delay 10.0 s 4200.0s (60.0 s) 3200 Ineg>> Start enabled disabled X 3298 Blockage Ineg>> connected not connected (X) 3201 Ineg>> 0.10 In 3.50 In (0.60 In) 3204 Reset Ratio Ineg>> 0.20 0.97 (0.95) 3211 tIneg>> Time 0.00 s 60.00 s (1.00 s) Inrush 6800 Inrush Restraint enabled Restraint disabled X 6898 Blockage Inrushrest. connected not connected (X) 6830 Inrushrest. IL Singleblock Crossblock (X) 6814 top Crossblock 0.10 s 60.00 s (1.50 s) 6801 I2f/1f> (IL) 0.10 0.45 (0.20) 6808 Inrushrest. up to IL 0.50 In 25.00 In (4.00 In) 6831 Inrushrest. IL> enabled (X) disabled 6832 Inrushrest. IL>> enabled disabled (X) 6833 Inrushrest. IL>>> enabled disabled (X) 6834 Inrushrest. IL>>>> enabled disabled (X) 6835 Inrushrest. IE> not (X) with Inrushrest.IL 6836 Inrushrest. IE>> not (X) with Inrushrest.IL 6837 Inrushrest. IE>>> not (X) with Inrushrest.IL 6838 Inrushrest. IE>>>> not (X) with Inrushrest.IL 6839 Inrushrest. Ieint> not (X) with Inrushrest.IL 6840 Inrushrest. Ineg> not (X) with Inrushrest.IL 6841 Inrushrest. Ineg>> not (X) with Inrushrest.IL

Appendix 11




Set 2nd Set

3rd Set

4th Set

Auto-Reclose 9900 Auto-Reclosing AR enabled (AR) disabled X Part 1 prepared 9998 Blockage AR connected not connected (X) 9949 CB Pos for AR Ready consider not considered (X) 9905 tblockAR CBC CB Close 0.01 s 60.00 s (1.00 s) 9930 Number of AR Shots 1 AR Shot 2 AR Shots (X) 3 AR Shots 4 AR Shots 5 AR Shots 9948 Distance AR Start disabled if Distance Start Dist.Start+forward Dist.Start+reverse homog. line Z1x,t1x (X) inhomog. section 1 inhomog. section 2 9918 Section Factor f*X1xs 0.01 1.00 (1.00) 9931 IL> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9932 IL>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9933 IL>>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9934 IL>>>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9935 IE> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9936 IE>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9937 IE>>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9938 IE>>>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9940 Ineg> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9941 Ineg>> AR Start Pickup(+Direction) Pickup+TRIP disabled (X) 9942 Earthfault AR Start enabled disabled (X) 9943 External AR Start enabled disabled (X) 9944 AR TRIP undelayed only 1st TRIP all non-final TRIPS (X)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Auto-Reclose 9945 First Dead Time(tD) short:rapid reclose (X) (AR) long:delayed reclose Part 2 9914 top1Time1st DeadTime 0.05 s 9.99 s (0.40 s) 9946 CB ready at tDshort necessary not necessary (X) 9911 Dead Time rapid Recl 0.05 s 9.99 s (0.80 s) 9919 top2 from 2ndDeadTime 0.05 s 9.99 s (1.00 s) 9947 CB ready at tDlong necessary (X) not necessary 9912 Dead Time delayed R. 1 s 300 s (6 s) 9917 tcl Duration CBCLOSE 0.05 s 0.50 s (0.10 s) 9916 tr Reclaim Time AR 1 s 300 s (8 s) 9915 tb Blocking Time AR 1 s 300 s (8 s) Tele- 19000 Teleprotection enabled protection prepared closed X 19098 Blockage TP connected not connected (X) 19035 Start TP with EF/IE enabled disabled (X) 19030 Mode Teleprotection reverse interlock (X) rev.intlock/H2 logic unidirect.:transmit unidirect.:receive pilot wire POP (POTT) mode BOP mode PUB (PUTT) mode 19031 Start topTP if Start. Z, IL,(EF/IE) (X) Direction forward Direction reverse 19032 Transmiss. Condition Direction forward Direction reverse Z<Z1x,t1x (X) 19033 Reception Condition Direction forward Direction reverse Z<Z1x,t1x (X) 19014 topTP Operating Time 0.02 s 9.99 s (0.10 s) 19034 Intertrippg no Start enabled disabled (X) 19011 tTRIP Delay TP 10 ms 999 ms (30 ms)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Voltage 14100 U> Stage enabled Protection disabled X Part 1 14198 Blockage U> connected not connected (X) 14131 U> Mode Phase-to-Phase (LL) (X) Phase-to-Earth (LE) 14130 TRIP at tU> enabled disabled (X) 14101 U> 0.20⋅Un 2.00⋅Un Note: LL:Un,LE:Un /√3 (1.20⋅Un) 14104 Reset Ratio U> 0.20 0.99 0.95 14111 tU> Time 0.00 s 60.00 s (2.00 s) 14200 U>> Stage enabled disabled X 14298 Blockage U>> connected not connected (X) 14231 U>> Mode Phase-to-Phase (LL) (X) Phase-to-Earth (LE) 14230 TRIP at tU>> enabled disabled (X) 14201 U>> 0.20⋅Un 2.00⋅Un Note: LL:Un,LE:Un /√3 (1.40⋅Un) 14204 Reset Ratio U>> 0.20 0.99 (0.95) 14211 tU>> Time 0.00 s 60.00 s (1.00 s) 15100 U< Stage enabled disabled X 15198 Blockage U< connected not connected (X) 15131 U< Mode Phase-to-Phase (LL) (X) Phase-to-Earth (LE) 15133 U< Stage blocked if IL<Imin (X) blocked if CB Open indep. of Criteria 15130 TRIP at tU< enabled disabled (X) 15101 U< 0.20⋅Un 2.00⋅Un Note: LL:Un,LE:Un /√3 (0.8⋅Un) 15104 Reset Ratio U< 1.01 5.00 (1.05) 15111 tU< Time 0.00 s 60.00 s (20.0 s) 15200 U<< Stage enabled disabled X 15298 Blockage U<< connected not connected (X) 15231 U<< Mode Phase-to-Phase (LL) (X) Phase-to-Earth (LE) 15233 U<< Stage blocked if IL<Imin (X) blocked if CB Open indep. of Criteria 15230 TRIP at tU<< enabled disabled (X) 15201 U<< 0.20⋅Un 2.00⋅Un Note: LL:Un,LE:Un /√3 (0.6⋅Un) 15204 Reset Ratio U<< 1.01 5.00 (1.05) 15211 tU<< Time 0.00 s 60.00 s (15.0 s)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Voltage 14300 UNE> Stage enabled Protection disabled X Part 2 14398 Blockage UNE> connected not connected (X) 14335 Value for UNE> calculated (X) measured 14330 TRIP at tUNE> enabled disabled (X) 14301 UNE> 0.02⋅Un 1.00⋅Un (0.3⋅Un) 14304 Reset Ratio UNE> 0.20 0.99 (0.95) 14311 tUNE> Time 0.00 s 60.00 s (2.00 s) 14400 UNE>> Stage enabled disabled X 14498 Blockage UNE>> connected not connected (X) 14435 Value for UNE>> calculated (X) measured 14430 TRIP at tUNE>> enabled disabled (X) 14401 UNE>> 0.02⋅Un 1.00⋅Un (0.5⋅Un) 14404 Reset Ratio UNE>> 0.20 0.99 (0.95) 14411 tUNE>> Time 0.00 s 60.00 s (1.00 s)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Frequency 16100 f1>< Start enabled Protect. disabled X 16198 Blockage f1>< connected not connected (X) 16130 TRIP at tf1>< enabled disabled (X) 16101 f1>< 45.50Hz 54.40Hz at fn=50 Hz (49.5Hz) 16102 f1>< 55.50Hz 64.50Hz at fn=60 Hz (59.5Hz) 16111 tf1>< Time 0.00 s 60.00 s (60.0 s) 16200 f2>< Start enabled disabled X 16298 Blockage f2>< connected not connected (X) 16230 TRIP at tf2>< enabled disabled (X) 16201 f2>< 45.50Hz 54.40Hz at fn=50 Hz (49.0Hz) 16202 f2>< 55.50Hz 64.50Hz at fn=60 Hz (59.0Hz) 16211 tf2>< Time 0.00 s 60.00 s (30.0 s) 16300 f3>< Start enabled disabled X 16398 Blockage f3>< connected not connected (X) 16330 TRIP at tf3>< enabled disabled (X) 16301 f3>< 45.50Hz 54.40Hz at fn=50 Hz (47.5Hz) 16302 f3>< 55.50Hz 64.50Hz at fn=60 Hz (57.5Hz) 16311 tf3>< Time 0.00 s 60.00 s (3.0 s) 16400 f4>< Start enabled disabled X 16498 Blockage f4>< connected not connected (X) 16430 TRIP at tf4>< enabled disabled (X) 16401 f4>< 45.50Hz 54.40Hz at fn=50 Hz (51.0Hz) 16402 f4>< 55.50Hz 64.50Hz at fn=60 Hz (61.0Hz) 16411 tf4>< Time 0.00 s 60.00 s (30.0 s) 16008 ULLmin for fx>< 0.20⋅Un 1.00⋅Un (0.4⋅Un)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Power 17100 P>Stage enabled Protection disabled X 17198 Blockage P> connected not connected (X) 17130 TRIP at tP> enabled disabled (X) 17131 P>Direction forward (X) reverse non-directional 17101 P> 0.010 Sn 1.500 Sn (0.500 Sn) 17104 Reset Ratio P> 0.20 0.97 (0.95) 17110 tO P>> Operate Delay 0.00 s 60.00 s (0.10 s) 17111 tP>TRIP Delay 0.00 s 60.00 s (2.00 s) 17112 tR P>Release Delay 0.00 s 60.00 s (0.00 s) 17200 P>> Stage enabled disabled X 17298 Blockage P>> connected not connected (X) 17230 TRIP at tP>> enabled disabled (X) 17231 P>> Direction forward (X) reverse non-directional 17201 P>> 0.01 Sn 1.50 Sn (1.00 Sn) 17204 Reset Ratio P>> 0.20 0.97 (0.95) 17210 tO P>> Operate Delay 0.00 s 60.00 s (0.10 s) 17211 tP>> TRIP Delay 0.00 s 60.00 s (1.00 s) 17212 tR P>> Release Delay 0.00 s 60.00 s (0.00 s) 17300 Q> Stage enabled disabled X 17398 Blockage Q> connected not connected (X) 17330 TRIP at tQ> enabled disabled (X) 17331 Q> Direction forward (X) reverse non-directional 17301 Q> 0.01 Sn 1.50 Sn (0.50 Sn) 17304 Reset Ratio Q> 0.20 0.97 (0.95) 17310 tO Q> Operate Delay 0.00 s 60.00 s (0.10 s) 17311 tQ> TRIP Delay 0.00 s 60.00 s (2.00 s) 17312 tR Q> Release Delay 0.00 s 60.00 s (0.00 s) 17400 Q>> Stage enabled disabled X 17498 Blockage Q>> connected not connected (X) 17430 TRIP at tQ>> enabled disabled (X) 17431 Q>> Direction forward (X) reverse non-directional 17401 Q>> 0.01 Sn 1.50 Sn 1.00 Sn 17404 Reset Ratio Q>> 0.20 0.97 0.95 17410 tO Q>> Operate Delay 0.00 s 60.00 s 0.10 s 17411 tQ>> TRIP Delay 0.00 s 60.00 s 1.00 s 17412 tR Q>> Release Delay 0.00 s 60.00 s 0.00 s

Appendix 11




Set 2nd Set

3rd Set

4th Set

Overload 4100 Overload Protection enabled Protection disabled X 4101 k Pickup Factor 0.20 2.00 (1.10) 4102 tau therm.Timeconst. 1 min 960 min (15 min) 4111 OLoadProt. up to ILmax 0.25 In 40.00 In (2.00 In) 4130 Gen.TRIP at>=100% disabled (X) not if Dist/I start even if Dist/I start 4196 Blockage therm. TRIP connected not connected (X) 4133 ReclLockout Overload enabled (X) disabled 4103 ReclLock Ovload from 10.0 % 100.0 % (100 %) 4104 ResetReclLock Ovload 10.0 % 90.0 % (88.0 %) 4131 Therm. Warn.Level 1 enabled (X) disabled 4108 Therm. Warn.Level 1 40.0 % 98.0 % (92.0 %) 4132 Therm. Warn.Level 2 enabled disabled (X) 4109 Therm. Warn.Level 2 40.0 % 98.0 % (96.0 %) 4135 Record Therm.Level enabled disabled (X) CB TRIP 9298 Blockage TRIP connected not connected X 9230 Extern. TRIP Commands disabled X 1 external TRIP 2 external TRIPS CBFailure 9300 CB Fail.Protect. CBF enabled Protection disabled X 9398 Blockage CBF connected not connected (X) 9330 CB Check Pos Open enabled disabled (X) 9308 IminCBF 0.05 In 2.00 In (0.30 In) 9311 tCBF intern 0.00 s 1.99 s (0.30 s) 9331 External CB Failure enabled disabled (X) 9332 TRIP at CBF external enabled disabled (X) 9312 tCBF external 0.00 s 1.99 s (0.30 s) Fault 9400 Fault Location FL enabled X Location disabled 9498 Blockage FL connected not connected X 9401 XLs*In/A React.100% 0.1 Ω 150 Ω 10.0 Ω 9402 100 % Line Length 0.1 km 200 km 20.0 km

Appendix 11




Set 2nd Set

3rd Set

4th Set

Synchro- 9700 Synchrocheck enabled check disabled (X) 9798 Blockage Sync.Check connected not connected (X) 9730 If BlockageSync. Refuse CLOSE (X) Enable CLOSE 9731 US2 connected as UL1E UL2E UL3E UL12 (X) UL23 UL31 9714 tCB Inherent Delay 0 ms 500 ms 0ms 9710 phi Correction US2 -180 ° 180 ° (0 °) 9706 Usync min limit 0.2 Un 1.00 Un Note: LL:Un,LE:Un /√3 (0.90 Un) 9707 Usync max limit 0.2 Un 1.15 Un Note: LL:Un,LE:Un /√3 (1.10 Un) 9701 Udiff max 0.005Un 0.50 Un Note: LL:Un,LE:Un /√3 (0.05 Un) 9702 fdiff max 0.010Hz 2.00 Hz (0.10 Hz) 9703 phidiff max 2 ° 80 ° (10 °) 9711 tsync delay CLOSE 0.00 s 60.00 s (0 s) 9712 tsyncmax time 0.01 s 1200 s (60 s) 9736 Messages/Events M. during Synccheck M/E.during Synccheck (X) M. after Synccheck M./E. after Synccheck 9732 Bypass US1D/US2D enabled disabled (X) 9733 Bypass US1L/US2D enabled disabled (X) 9734 Bypass US1D/US2L enabled disabled (X) 9704 Udead Dead Value 0.01 Un 0.60 Un Note: LL:Un,LE:Un /√3 (0.05 Un) 9705 Ulive Live Value 0.20 Un 1.15 Un Note: LL:Un,LE:Un /√3 (0.80 Un) 9713 tdeadlive Bypass 0.00 s 60.00 s (0.1 s) 9735 US2 3~ connected not connected (X) Synchro- 9800 Synchrocheck AR enabled check AR disabled (X) 9830 Synchrocheck AR rapid reclose only delayed reclose only rapid+delayed recl. (X) 9806 Usync AR min 0.20 Un 1.00 Un Note: LL:Un,LE:Un /√3 (0.90 Un) 9807 Usync AR max 0.20 Un 1.15 Un Note: LL:Un,LE:Un /√3 (1.10 Un) 9801 Udiff AR max 0.005Un 0.50 Un Note: LL:Un,LE:Un /√3 (0.05 Un) 9802 fdiff AR max 0.010Hz 2.00 Hz (0.10 Hz) 9803 phidiff AR max 2 ° 80 ° (10 °) 9811 tsync AR 0.00 s 60.00 s (0 s) 9812 tsyncmax AR 0.01 s 1200 s (60 s) 9832 Bypass US1D/US2D AR enabled disabled (X) 9833 Bypass US1L/US2D AR enabled disabled (X) 9834 Bypass US1D/US2L AR enabled disabled (X) 9813 tdeadlive Bypass AR 0.00 s 60.00 s (0.1 s)

Appendix 11




Set 2nd Set

3rd Set

4th Set

Current 11100 Annunciation IL>an enabled Annunciation disabled X 11198 Blockage IL>an connected not connected (X) 11101 IL>an 0.10 In 40.00 In (0.50 In) 11111 tIL>an Time 0.00 s 60.00 s (1.00 s) 11200 Annunciation IL>>an enabled disabled X 11298 Blockage IL>>an connected not connected (X) 11201 IL>>an 0.10 In 40.00 In (1.00 In) 11211 tIL>>an Time 0.00 s 60.00 s (0.50 s) 12100 Annunciation IE>an enabled disabled X 12198 Blockage IE>an connected not connected (X) 12133 Value for IE>an measured calculated (X) 12101 IE>an 1 0.05 In 25.00 In (0.25 In) 12103 IE>an sensitive 0.010 In 5.000 In (0.050 In) 12105 IE> an sensitive 1 0.005 In 2.500 In (0.025 In) 12111 tIE>an Time 0.00 s 60.00 s (1.00 s) Pulse 19100 Signal1 enabled Shaping disabled X 19130 Signal1,Start with On-Edge of Ui (X) Off-Edge of Ui 19111 Signal1 On-Delay 0.00 s 3600 s (0.00 s) 19131 Signal1 On-Delay restart possible not to restart (X) 19132 Signal1,ends with On-Edge of Ui Off-Edge of Ui (X) sep.Reset Signal 19112 Signal1 Off-Delay 0.00 s 3600 s (0.00 s) 19133 Signal1 Off-Delay restart possible not to restart (X) 19198 Blockage I/O coupl.1 connected not connected (X) 19200 Signal2 enabled disabled X 19230 Signal2,Start with On-Edge of Ui (X) Off-Edge of Ui 19211 Signal2 On-Delay 0.00 s 3600 s (0.00 s) 19231 Signal2 On-Delay restart possible not to restart (X) 19232 Signal2,End with On-Edge of Ui Off-Edge of Ui (X) sep.Reset Signal 19212 Signal2 Off-Delay 0.00 s 3600 s (0.00 s) 19233 Signal2 Off-Delay restart possible not to restart (X) 19298 Blockage I/O Coupl.2 connected not connected (X)


Appendix 11




Set 2nd Set

3rd Set

4th Set

Temperature 4400 Temp.Monitoring enabled Protection disabled (X) (Option) 4498 Blockage Temp.Monit. connected not connected (X) 4430 Warn.Level Temp.1 enabled (X) disabled 4401 Warning Temp.1 0 °C 250 °C (100 °C) 4402 Limit Temp.1 0 °C 250 °C (140 °C) 4431 TRIP Temperature 1 enabled disabled (X) 4432 If TRIP by Temp.1 set reclose lockout set no recl. lockout (X) 4433 Warn.Level1Temp. 2 enabled (X) disabled 4403 Warn.Level1 Temp.2 0 °C 250 °C (110 °C) 4434 Warn.Level2 Temp.2 enabled (X) disabled 4404 Warn.Level2 Temp.2 0 °C 250 °C (130 °C) 4405 Limit Temp.2 0 °C 250 °C (140 °C) 4435 TRIP Temperature 2 enabled disabled (X) 4436 If TRIP by Temp.2 set reclose lockout set no recl. lockout (X) 4437 Warn.Level Temp.3 enabled (X) disabled 4406 Warn.Level Temp.3 0 °C 250 °C (50 °C) 4407 Limit Temp.3 0 °C 250 °C (60 °C) 4438 TRIP Temperature 3 enabled disabled (X) 4439 If TRIP by Temp.3 set reclose lockout (X) set no recl. lockout 4440 Warn.Level Temp.4 enabled (X) disabled 4408 Warn.Level Temp.4 0 °C 250 °C (40 °C) 4409 Limit Temp.4 0 °C 250 °C (50 °C) 4441 TRIP Temp.4 enabled disabled (X) 4442 If TRIP by Temp.4 set reclose lockout set no recl. lockout (X) 4443 Warn.Level Temp.5 enabled (X) disabled 4410 Warn.Level Temp.5 0 °C 250 °C (40 °C) 4411 Limit Temp.5 0 °C 250 °C (50 °C) 4444 TRIP Temperature 5 enabled disabled (X) 4445 If TRIP byTemp.5 set reclose lockout set no recl. lockout (X)

Appendix 11


Table 13 General

Limit value Function group Ad-dress Setting


tion Device On/Off * 51300 Device On/Off on X off Relays 32101 Logic PS-CO1 or X and 32102 Logic PS-CO2 or X and 32103 Logic PS-CO3 or X and 32104 Logic PS-CO4 or X and 32105 Logic PS-AO1 or X and 32106 Logic PS-AO2 or X and 32107 Logic PROT-DO1 or X and 32108 Logic PROT-DO2 or X and 32109 Logic PROT-DO3 or X and 32110 Logic PROT-DO4 or X and 32111 Logic PROT-DO5 or X and 32112 Logic PROT-DO6 or X and 32113 Logic PROT-DO7 or X and 32114 Logic PROT-DO8 or X and 32201 Oper. Time PS-CO1 0 ms 500 ms 200 ms ms 32202 Oper. Time PS-CO2 0 ms 500 ms 200 ms ms 32203 Oper. Time PS-CO3 0 ms 500 ms 200 ms ms 32204 Oper. Time PS-CO4 0 ms 500 ms 200 ms ms 32205 Oper. Time PS-AO1 0 ms 500 ms 20 ms ms 32206 Oper. Time PS-AO2 0 ms 500 ms 20 ms ms 32207 Oper. Time PROT-DO1 0 ms 500 ms 20 ms ms 32208 Oper. Time PROT-DO2 0 ms 500 ms 20 ms ms 32209 Oper. Time PROT-DO3 0 ms 500 ms 20 ms ms 32210 Oper. Time PROT-DO4 0 ms 500 ms 20 ms ms 32211 Oper. Time PROT-DO5 0 ms 500 ms 20 ms ms 32212 Oper. Time PROT-DO6 0 ms 500 ms 20 ms ms 32213 Oper. Time PROT-DO7 0 ms 500 ms 20 ms ms 32214 Oper. Time PROT-DO8 0 ms 500 ms 20 ms ms

* Protection relay can be switched off / on with this setting.

Appendix 11




tion Optocoupler 33201 Pickup Time PS-DI1 0 ms 250 ms 0 ms ms 33301 Reset Time PS-DI1 0 ms 250 ms 0 ms ms 33202 Pickup Time PS-DI2 0 ms 250 ms 0 ms ms 33302 Reset Time PS-DI2 0 ms 250 ms 0 ms ms 33203 Pickup Time PS-DI3 0 ms 250 ms 0 ms ms 33303 Reset Time PS-DI3 0 ms 250 ms 0 ms ms 33204 Pickup Time PS-DI4 0 ms 250 ms 0 ms ms 33304 Reset Time PS-DI4 0 ms 250 ms 0 ms ms 33205 Pickup Time PS-DI5 0 ms 250 ms 0 ms ms 33305 Reset Time PS-DI5 0 ms 250 ms 0 ms ms 33206 Pickup Time PS-DI6 0 ms 250 ms 0 ms ms 33306 Reset Time PS-DI6 0 ms 250 ms 0 ms ms 33207 Pickup Time PS-DI7 0 ms 250 ms 0 ms ms 33307 Reset Time PS-DI7 0 ms 250 ms 0 ms ms 33208 Pickup Time PS-DI8 0 ms 250 ms 0 ms ms 33308 Reset Time PS-DI8 0 ms 250 ms 0 ms ms 33209 Pickup Time PS-DI9 0 ms 250 ms 0 ms ms 33309 Reset Time PS-DI9 0 ms 250 ms 0 ms ms 33210 Pickup Time PS-DI10 0 ms 250 ms 0 ms ms 33310 Reset Time PS-DI10 0 ms 250 ms 0 ms ms 33211 Pickup Time PROT-DI1 0 ms 250 ms 0 ms ms 33311 Reset Time PROT-DI1 0 ms 250 ms 0 ms ms 33212 Pickup Time PROT-DI2 0 ms 250 ms 0 ms ms 33312 Reset Time PROT-DI2 0 ms 250 ms 0 ms ms 33213 Pickup Time PROT-DI3 0 ms 250 ms 0 ms ms 33313 Reset Time PROT-DI3 0 ms 250 ms 0 ms ms 33214 Pickup Time PROT-DI4 0 ms 250 ms 0 ms ms 33314 Reset Time PROT-DI4 0 ms 250 ms 0 ms ms 33215 Pickup Time PROT-DI5 0 ms 250 ms 0 ms ms 33315 Reset Time PROT-DI5 0 ms 250 ms 0 ms msVirtual 35101 Logic Cmd.->vDI1 or X Inputs and Part 1 35102 Logic Cmd.->vDI2 or X and 35103 Logic Cmd.->vDI3 or X and 35104 Logic Cmd.->vDI4 or X and 35105 Logic Cmd.->vDI5 or X and 35106 Logic Cmd.->vDI6 or X and 35107 Logic Cmd.->vDI7 or X and 35108 Logic Cmd.->vDI8 or X and 35109 Logic Cmd.->vDI9 or X and 35110 Logic Cmd.->vDI10 or X and 35111 Logic Cmd.->vDI11 or X and 35112 Logic Cmd.->vDI12 or X and 35113 Logic Cmd.->vDI13 or X and 35114 Logic Cmd.->vDI14 or X and 35115 Logic Cmd.->vDI15 or X and

Appendix 11




tion Virtual 35201 Pickup Time vDI1 0 ms 250 ms 0 ms msInputs 35301 Reset Time vDI1 0 ms 250 ms 0 ms msPart 1 35202 Pickup Time vDI2 0 ms 250 ms 0 ms ms 35302 Reset Time vDI2 0 ms 250 ms 0 ms ms 35203 Pickup Time vDI3 0 ms 250 ms 0 ms ms 35303 Reset Time vDI3 0 ms 250 ms 0 ms ms 35204 Pickup Time vDI4 0 ms 250 ms 0 ms ms 35304 Reset Time vDI4 0 ms 250 ms 0 ms ms 35205 Pickup Time vDI5 0 ms 250 ms 0 ms ms 35305 Reset Time vDI5 0 ms 250 ms 0 ms ms 35206 Pickup Time vDI6 0 ms 250 ms 0 ms ms 35306 Reset Time vDI6 0 ms 250 ms 0 ms ms 35207 Pickup Time vDI7 0 ms 250 ms 0 ms ms 35307 Reset Time vDI7 0 ms 250 ms 0 ms ms 35208 Pickup Time vDI8 0 ms 250 ms 0 ms ms 35308 Reset Time vDI8 0 ms 250 ms 0 ms ms 35209 Pickup Time vDI9 0 ms 250 ms 0 ms ms 35309 Reset Time vDI9 0 ms 250 ms 0 ms ms 35210 Pickup Time vDI10 0 ms 250 ms 0 ms ms 35310 Reset Time vDI10 0 ms 250 ms 0 ms ms 35211 Pickup Time vDI11 0 ms 250 ms 0 ms ms 35311 Reset Time vDI11 0 ms 250 ms 0 ms ms 35212 Pickup Time vDI12 0 ms 250 ms 0 ms ms 35312 Reset Time vDI12 0 ms 250 ms 0 ms ms 35213 Pickup Time vDI13 0 ms 250 ms 0 ms ms 35313 Reset Time vDI13 0 ms 250 ms 0 ms ms 35214 Pickup Time vDI14 0 ms 250 ms 0 ms ms 35314 Reset Time vDI14 0 ms 250 ms 0 ms ms 35215 Pickup Time vDI15 0 ms 250 ms 0 ms ms 35315 Reset Time vDI15 0 ms 250 ms 0 ms ms

51411 Pre-Fault Time 0 ms 4000 ms 100 ms msDisturbance Record 51412 Post-Fault Time 0 ms 500 ms 150 ms msAdditionals 51730 Language Device German X English

Appendix 11


Table 14 Communication+Substation Control


upper lower Alternatives Delivery Selec-

tion Communication 51530 Baudrate Serv. 232 9600 Bd 19200 Bd 38400 Bd 57600 Bd X 115200 Bd do not use 51531 Parity Serv. 232 8,N,1 X 8,E,1 51530 Baudrate IEC 103 9600 Bd 19200 Bd X 38400 Bd 57600 Bd 115200 Bd do not use 51533 Parity IEC 103 8,N,1 8,E,1 X 51501 Device Address 1 254 1 Substation 51630 Remote Setting enabled Control disabled X 51631 Cmd Blockage TRIP enabled disabled X 51632 Cmd AR On/Off enabled disabled X 51633 Cmd TP On/Off enabled disabled X 51634 Cmd Prot. On/Off enabled disabled X 51635 Cmd Reset LED/LCD enabled disabled X 51636 Cmd Char. Set Switch enabled disabled X 51637 Information Blocking connected not connected X 51638 CB Close from SCADA 2 yes no X 51639 Cmd Reset

Recl.Lockout enabled

disabled (X) 51640 Cmd Reset tIE>int enabled disabled (X) 2 This signal can only be activated by the CB with the smallest node number (e.g. Q0 01.-01) in the control sys-tem setting

SPRECO

N-E-Pxx-D

Dx6 U


337

Sprecher A

utomation D

eutschland Gm

bH

Appendix 1

1

Table 15 Input configuration

PS-DI PROT-DI virtual Inputs vDI Function module Signal function and / or 1 2 3 4 5 6 7 8 9 10 1 2 3 4 5 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

operate time /ms:* *) setting at device under ...\General\Optocoupler

or ...\General\Virtual Inputs reset time /ms:*

Equipment Adaptation\ CB Adaptation 460 CB closed manually 461 CB Position On 462 CB Position Off 499 Blockage TripCircSv 463 TripCircuitSuperv. 1 464 TripCircuitSuperv. 2 Transf. Adaptation 360 FuseVoltageTransf. 361 Fuse VT U4 Characteristic Set 261 Characteristic Set 1 262 Characteristic Set 2 263 Characteristic Set 3 264 Characteristic Set 4 System Adaptation\ System Adaptation 561 Left Handed (L132) 562 Right Handed (L123) Protection Modules\ Measurand Check 18199 Block. Check IPath 18299 Block. Check UPath 18399 Block. Check UNE Direction Decision 1999 Blockage SCD 2999 Blockage ESCD Dist (U-) I-Start 5899 Block. (U-) I-Start Z<-Start 5999 Blockage Z< Loop Determination 4999 Blockage IE>EFC 4997 Blockage UNE>EFC

SPRECO

N-E-Pxx-D

Dx6 U


338

Sprecher A

utomation D

eutschland Gm

bH

Appendix 1

1


Distance Module 5199 Blockage Z1,t1 5299 Blockage Z1x,t1x 5260 Signal Z1x,t1x 5399 Blockage Z2,t2 5499 Blockage Z3,t3 5599 Blockage Z4,t4 5699 Blockage t5 5799 Blockage t6 Earthfault Detection 7099 Block. Earth.Det. 7061 EarthFlt. forw.ext. 7062 EarthFlt. rev. ext Reclose Lockout 4599 Block.ReclLockout 4560 Set RecloseLockout 4561 Reset Recl.Lockout IL> (Emerg.)OTP 1199 Blockage IL> 1299 Blockage IL>> 1399 Blockage IL>>> 1499 Blockage IL>>>> IE> (Emerg.)OTP 2199 Blockage IE> 2299 Blockage IE>> 2399 Blockage IE>>> 2499 Blockage IE>>>> 2899 Blockage IE>int 2861 Reset tIE>int Switch-On Protection 8099 Blockage SOTF Negative Sequence I 3199 Blockage Ineg> 3299 Blockage Ineg>> Inrush Restraint 6899 Blockage IR Auto-Reclose (AR) 9961 AR ON-Pushbutton 9962 AR OFF-Pushbutton 9999 AR extern Blockage 9963 CB ready 9960 AR External Start

SPRECO

N-E-Pxx-D

Dx6 U


339

Sprecher A

utomation D

eutschland Gm

bH

Appendix 1

1


Teleprotection 19063 TP ON-Pushbutton 19064 TP OFF-Pushbutton 19099 Blockage TP 19062 H2:Subst.BlockSignal 19060 TP Signal Input 19065 TP Connect.disturbed Voltage Protection 14199 Blockage U> 14299 Blockage U>> 15199 Blockage U< 15299 Blockage U<< 14399 Blockage UNE> 14499 Blockage UNE>> Frequency Protect. 16199 Blockage f1>< 16299 Blockage f2>< 16399 Blockage f3>< 16499 Blockage f4>< Power Protection 17199 Blockage P> 17299 Blockage P>> 17399 Blockage Q> 17499 Blockage Q>> Overload Protection 4197 Block.therm. TRIP 4161 Record Therm.Level CB TRIP 9299 Blockage sign. TRIP 9260 External TRIP 1 9261 External TRIP 2 CBFailure Protection 9399 Blockage CBF 9360 Signal CBF extern. Fault Location 9499 Blockage FL Synchrocheck 9799 Blockage SyncCheck 9760 Bypass SyncCheck 9761 US2 3~ Dead 9762 US2 3~ Live Current Annunciation 11199 Blockage IL>an 11299 Blockage IL>> an

SPRECO

N-E-Pxx-D

Dx6 U


340

Sprecher A

utomation D

eutschland Gm

bH

Appendix 1

1


12199 Blockage IE> an Pulse Shaping 19161 Signal 1 19162 Reset Signal1 19199 Block.I/O-Coupl.1 19261 Signal 2 19262 Reset Signal2 19299 Block.I/O-Coupl.2 Temperature Protec-tion 4499 Block. Temp.Monit.

General\ Disturbance Record 51460 Disturb.Data Record. Additionals 51860 Test Mode 51760 Reset LED/LCD Com.+SubstCtrl.\ Substation Control 51660 InformationBlockg. 51661 Aux. Input 1 51662 Aux. Input 2 51663 Aux. Input 3 51664 Aux. Input 4

Appendix 11


In the above Table, the input signals (optocouplers and virtual inputs) can be used in negated form. To identify negated use, ”N“ and – in case of non-negated use – “X” can be entered. The logic operation (AND, OR) is effective subsequently if several inputs are used.

Table 16 Input signals explained Blockages block the corresponding functions for the duration of the active signal level

CB closed manually obligatory signal for “Switch onto Fault protection” and “AR” (Auto Recloser) (during an AR cycle an ON is not considered as closed manually)

CB Position On position signal On of the power switcher, important signal CB Position Off position signal Off of the power switcher, important signal TripCircuitSuperv. 1 input 1 of the trip circuit supervision TripCircuitSuperv. 2 2nd input of the trip circuit supervision Fuse Voltage Transf. U4 fuse of the voltage transformer, active level leads to U path error Left Handed (L132) active signal results in a switch to an anti-clockwise rotating field Right Handed (L123) active signal results in a switch to a clockwise rotating field

Characteristic Set 1...4 Activation of the corresponding characteristic set for the duration of the active signal level. If there are none ore more than one input with active level available the last valid one will stay active. Only accessable if enabled in Equipment Adaptation.

5260 Signal Z1x,t1x activation of the overreach stage Z1x, t1x EarthFlt. forw. if signal active transfer (e.g. from ERER) as earth fault forward EarthFlt. rev. if signal active transfer as earth fault reverse

Set RecloseLockout If signal active the reclose lockout will be resetted. Reset only possible using input “Reset Recl.Lockout”.

Reset Recl.Lockout If signal active the reclose lockout will be resetted, set by input signal and tempera-ture detector. Overload protection reclose lockout is not affected.

Reset tIE>int if signal active reset of the sum time of the IE>int stage AR ON-Pushbutton connection of a button for switching on the protection module “AR“ AR OFF-Pushbutton connection o a button for switching off of the protection module “AR“ AR extern Blockage prevents an automatic reclosing by “AR“ CB ready CB ready for AR cycle Off/On/Of, obligatory signal for “AR”. AR External Start starts an one-time AR TP ON-Pushbutton connection of a button for switching on the protection module “TP“ (teleprotection) TP OFF-Pushbutton connection of a button for switching off of the protection module “TP“ H2:Subst.BlockSignal input signal of the station blocking bus of the H2 logic TP Signal Input receiving input of the selected signal transmission type TP Connect.disturbed input signal from teleprotection equipment in case of disturbances/malfunction Record Therm.Level if signal active recording of winding temperature and overload protection levels Blockage TRIP input signal requesting a TRIP-command Signal CBF extern. input signal of CB failure protection: acts depending on conditions Bypass SyncCheck allows ON-command without using synchronizing function 9761 US2 3~ Dead the single phase controlled US2 in the device is triple phase dead (off-circuit) 9762 US2 3~ Live the single phase controlled US2 in the device is triple phase live Signal 1/2 input signal for pulse shaper stage Reset Signal 1/2 input signal for pulse shaper stage Disturb.Data Record. disturbance data logging by external signal, acting without delay Test Mode defining the events as test events Reset LED/LCD reset of LED/LCD by external signal InformationBlockg. active or Substation Control interface

Aux. Input 1..4

Identically named entries provided for substation control communication in compati-ble areas acc. to IEC60870-5-103. Output commands can be configured onto these inputs (apart from assignment of digital inputs) using virtual digital inputs (vDI). This enables any output command to be signalled as “input x” to the substation control.

Appendix 11


Table 17 Temperature sensors of module PT100 (Option)

Function other Function Mini-mum

Aver-age

Maximum TI 1 TI 2 TI 3 TI 4 TI 5 TI 6 TI 7 TI 8

665 Temperature 1 (X) 666 Temperature 2 (X) 667 Temperature 3 (X) 668 Temperature 4 (X) 669 Temperature 5 (X)

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


343

Sprecher A

utomation D

eutschland Gm

bH

Table 18 Output configuration of relays

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8

Min. operation time/ms: * *) Setting at device under Logic (and/or): * ..\General\Relays

Equipment Adaptation \ CB Adaptation 460 CB closed manually 461 CB Position On 462 CB Position Off 490 TripCircSupv FctOn 499 Blockage TripCircSv 480 Malfunct TripCircuit Transf. Adaptation 360 FuseVoltageTransf.

361 Fuse VT U4

Characteristic Set 271 Char. Set 1 act. 272 Char. Set 2 act. 273 Char. Set 3 act. 274 Char. Set 4 act. System Adaptation \ System Adaptation 571 Left Handed (L132)

572 Right Handed (L123)

Protection Modules \ Measurand Check 18163 3phase I < Imin 18190 Superv.IPath FctOn 18199 Block. Check IPath 18180 I Path disturbed 18274 3phase U < Umin 18290 Superv.UPath FctOn 18299 Block. Check UPath 18281 WarnPhaseSequ. V 18390 Superv.UNE FctOn 18399 Block. Check UNE 18370 UNE>Check 18280 U Path disturbed

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


344

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 18282 I> Backup Operation Direction Decision 1990 Sh.C.Direct FctOn 1999 Blockage SCD 1971 Short Circ.forward 1972 Short Circ.reverse 1974 3ph. U<Umem min 2990 EarthSCDirectFctOn 2999 Blockage ESCD 2970 IE>,UNE>UNEmin ESCD 2971 Earth-SC forward 2972 Earth-SC reverse Dist (U-) I-Start 5890 (U-) I Start FctOn 5899 Block. (U-) I-Start 5870 (U-) I gen. Start 5871 (U-) I Start L1 5872 (U-) I Start L2 5873 (U-) I Start L3 Z<-Start 5990 Z< Start FctOn 5999 Blockage Z< 5970 Z< general start 5971 Z< Start 1-E 5972 Z< Start 2-E 5973 Z< Start 3-E 5974 Z< Start 1-2 5975 Z< Start 2-3 5976 Z< Start 3-1 Loop Determination 4990 IE>EFC FctOn 4999 Blockage IE>EFC 4970 IE>EFC Start 4991 UNE>EFC FctOn 4997 Blockage UNE>EFC 4971 UNE>EFC Start 4980 EF Crit. satisf. 4981 loop selection 1E

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


345

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 4982 loop selection 2E 4983 loop selection 3E 4984 loop selection 12 4985 loop selection 23 4986 loop selection 31 Distance Module 5090 Distance FctOn 5190 Z1,t1 FctOn 5199 Blockage Z1,t1 5170 Start Zone Z1 5180 Decision Zone Z1,t1 5181 Zone t1 expired 5290 Z1x,t1x FctOn 5299 Blockage Z1x,t1x 5260 Signal Z1x,t1x 5270 Start Zone Z1x 5280 Decision Zone Z1x,t1x 5281 Zone t1x expired 5390 Z2,t2 FctOn 5399 Blockage Z2,t2 5370 Start Zone Z2 5380 Decision Zone Z2,t2 5381 Zone t2 expired 5490 Z3,t3 FctOn 5499 Blockage Z3,t3 5470 Start Zone Z3 5480 Decision Zone Z3,t3 5481 Zone t3 expired 5590 Z4,t4 FctOn 5599 Blockage Z4,t4 5570 Start Zone Z4 5580 Decision Zone Z4,t4 5581 Zone t4 expired 5690 t5 FctOn 5699 Blockage t5

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


346

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 5680 DecisionDir.BackupTime 5681 Zone t5 expired 5790 t6 FctOn 5799 Blockage t6 5780 Decision Time Limit t6 5781 Zone t6 expired Earthfault Detection 7090 EFDetect. FctOn 7099 Block. Earth.Det. 7073 UNE>EF 7070 Earthfault 7081 Earthfault L1 7082 Earthfault L2 7083 Earthfault L3 7080 t TRIP EF expired 7061 EarthFlt. forw.ext. 7062 EarthFlt. rev. ext 7071 EarthFlt. forw. 7072 EarthFlt. rev. Reclose Lockout 4590 Recl.Lockout FctOn 4599 Block. ReclLockout 4560 Set RecloseLockout 4561 Reset Recl.Lockout 4570 Reclose Lockout IL> (Emerg.) OTP 1190 IL> Start FctOn 1199 Blockage IL> 1171 I1> Start 1172 I2> Start 1173 I3> Start 1180 tIL> expired 1290 IL>> Start FctOn 1299 Blockage IL>> 1271 I1>> Start 1272 I2>> Start 1273 I3>> Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


347

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 1280 tIL>> expired 1390 IL>>> Start FctOn 1399 Blockage IL>>> 1371 I1>>>Start 1372 I2>>> Start 1373 I3>>> Start 1380 tIL>>> expired 1490 IL>>>> Start FctOn 1499 Blockage IL>>>> 1471 I1>>>> Start 1472 I2>>>> Start 1473 I3>>>> Start 1480 tIL>>>> expired IE> (Emerg.) OTP 2190 IE> Start FctOn 2199 Blockage IE> 2170 IE> Start 2180 tIE> expired 2290 IE>> Start FctOn 2299 Blockage IE>> 2270 IE>> Start 2280 tIE>> expired 2390 IE>>> Start FctOn 2399 Blockage IE>>> 2370 IE>>> Start 2380 tIE>>> expired 2490 IE>>>> Start FctOn 2499 Blockage IE>>>> 2470 IE>>>> Start 2480 tIE>>>> expired 2890 IE>int Start FctOn 2899 Blockage IE>int 2870 IE>int Start 2880 tIE>int expired 2879 IE>int Cycle

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


348

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 2861 Reset tIE>int Switch-On Protection 8090 SOTF FctOn 8099 Blockage SOTF 8490 Dist. SOTF FctOn 8480 SOTF Distance 8079 top SOTF runs 8190 IL>SOTF FctOn 8171 IL1>SOTF Start 8172 IL2> SOTF Start 8173 IL3> SOTF Start 8180 tIL>SOTF expired 8290 IE> SOTF FctOn 8270 IE> SOTF Start 8280 tIE>SOTF expired 8390 Ineg>SOTF FctOn 8370 Ineg> SOTF Start 8380 tIneg>SOTF expired 8070 SOTF general Start Negative Sequence I 3190 Ineg> Start FctOn 3199 Blockage Ineg> 3170 Ineg> Start 3180 tIneg> expired 3290 Ineg>>Start FctOn 3299 Blockage Ineg>> 3270 Ineg>> Start 3280 tIneg>> expired 3275 Ineg gen. Start Inrush Restraint 6890 Inrushrest. FctOn 6899 Blockage IR 6870 Inrushrest. gen. 6871 Inrushrest. L1 6872 Inrushrest. L2 6873 Inrushrest. L3

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


349

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 Auto-Reclose (AR) 9990 AR FctOn 9999 AR extern Blockage 9979 tblockAR CBC runs 9963 CB ready 9960 AR External Start 9971 AR ready 9972 AR not ready 9970 AR-Cycle 9973 AR IntruptTrip.Sig 9974 CBTRIPSignal later 9980 CLOSE by AR Teleprotection 19090 Teleprot. FctOn 19099 Blockage TP 19062 H2:Subst.BlockSignal 19074 StationBus disturb. 19071 TP Send Signal 19060 TP Signal Input 19072 TP Signal received 19073 TP Connect.disturbed Voltage Protection 14190 U> FctOn 14199 Blockage U> 14171 U1E> Start 14172 U2E> Start 14173 U3E> Start 14174 U12> Start 14175 U23> Start 14176 U31> Start 14180 tU> expired 14290 U>> FctOn 14299 Blockage U>> 14271 U1E>> Start 14272 U2E>> Start 14273 U3E>> Start 14274 U12>> Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


350

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 14275 U23>> Start 14276 U31>> Start 14280 tU>> expired 15190 U< FctOn 15199 Blockage U< 15171 U1E< Start 15172 U2E< Start 15173 U3E< Start 15174 U12< Start 15175 U23< Start 15176 U31< Start 15180 tU< expired 15290 U<< FctOn 15299 Blockage U<< 15271 U1E<< Start 15272 U2E<< Start 15273 U3E<< Start 15274 U12<< Start 15275 U23<< Start 15276 U31<< Start 15280 tU<< expired 14390 UNE> FctOn 14399 Blockage UNE> 14370 UNE> Start 14380 tUNE> expired 14490 UNE>> FctOn 14499 Blockage UNE>> 14470 UNE>> Start 14480 tUNE>> expired

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


351

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 Frequency Protection 16190 f1>< FctOn 16199 Blockage f1>< 16170 f1>< Start 16180 tf1>< expired 16290 f2>< FctOn 16299 Blockage f2>< 16270 f2>< Start 16280 tf2>< expired 16390 f3>< FctOn 16399 Blockage f3>< 16370 f3>< Start 16380 tf3>< expired 16490 f4>< FctOn 16499 Blockage f4>< 16470 f4>< Start 16480 tf4>< expired Power Protection 17190 P> FctOn 17199 Blockage P> 17170 P> Start 17180 tP> expired 17290 P>> FctOn 17299 Blockage P>> 17270 P>> Start 17280 tP>> expired 17390 Q> FctOn 17399 Blockage Q> 17370 Q> Start 17380 tQ> expired 17490 Q>> FctOn 17499 Blockage Q>> 17470 Q>> Start 17480 tQ>> expired

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


352

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 Overload Protection 4190 O.load Prot FctOn 4175 IL > ILmax therm. 4197 Block.therm. TRIP 4178 Recl.Lock Overload 4171 Therm. Level 1 4172 Therm. Level 2 4180 Therm.Level >=100% 4161 Record Therm.Level General Start 9170 General Start 9171 Start L1 9172 Start L2 9173 Start L3 9174 Start E 9176 DT/IDMT Start CB TRIP 9299 Blockage sign. TRIP 9278 Blockage TRIP 9260 External TRIP 1 9261 External TRIP 2 9270 TRIP not final 9280 TRIP final CBFailure Protection 9390 CBF FctOn 9399 Blockage CBF 9371 Internal CBFailure 9360 Signal CBF extern. 9372 tCBF extern. expired Fault Location 9490 Fault Loc. FctOn 9499 Blockage FL 9470 Fault Loc. < 100%

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


353

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 Synchrocheck 9790 Synchrocheck FctOn 9799 Blockage SyncCheck 9760 Bypass SyncCheck 9770 SynchrocheckActive 9771 Sync Measure Req. 9772 Sync Malfunction 9773 Udiff > Udiff max 9774 fdiff > fdiff max 9775 phidiff>phidiffmax 9776 US1 <> Usync 9777 US2 <> Usync 9783 Udiff < Udiff max 9784 fdiff < fdiff max 9785 phidiff<phidiffmax 9786 < US1 Usync > 9787 < US2 Usync > 9778 Synchronism 9779 tsync expired 9780 tsyncmax expired 9761 US2 3~ Dead 9762 US2 3~ Live 9791 US1 Dead / US2 Dead 9792 US1 Live / US2 Dead 9793 US1 Dead / US2 Live 9794 Bypass active 9795 tdeadlive expired 9796 Sync: CB CLOSE Synchrocheck AR 9890 Syncheck AR FctOn

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


354

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 Current Annunciation 11190 IL>an FctOn 11199 Blockage IL>an 11171 IL1 > IL>an 11172 IL2 > IL> an 11173 IL3 > IL> an 11180 tIL> an expired 11290 IL>>an FctOn 11299 Blockage IL>> an 11271 IL1 > IL>> an 11272 IL2 > IL>> an 11273 IL3 > IL>> an 11280 tIL>>an expired 12190 IE>an FctOn 12199 Blockage IE> an 12170 IE > IE>an 12180 tIE>an expired Pulse Shaping 19190 Signal1 Fct On 19170 Signal 1 19199 Block.I/O-Coupl.1 19180 IO Coupl. signal 1 19290 Signal2 FctOn 19270 Signal 2 19299 Block.I/O-Coupl.2 19280 IO Coupl. signal 2 Temperature Protection 4490 Temp.Monit. FctOn 4499 Block. Temp.Monit. 4471 Warning Temp.1 4473 Temperature 1 > 4474 Warn.Level1 Temp.2 4475 Warn.Level2 Temp.2 4476 Temperature 2 > 4477 Warn.Level Temp.3 4478 Temperature 3 > 4479 Warn.LevelTemp.4

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


355

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 4480 Temperature 4 > 4481 Warn.LevelTemp.5 4482 Temperature 5 > General \ Alarm/Malfunction 51270 Alarm 51273 Warning Pt100 TI 51280 Malfunction 51281 Malfunct. TripRel. 51271 No Warning/Malfunc. Device On/Off 51171 Protection ready 51172 Protection dead Optocoupler 33401 PS-DI1 33402 PS-DI2 33403 PS-DI3 33404 PS-DI4 33405 PS-DI5 33406 PS-DI6 33407 PS-DI7 33408 PS-DI8 33409 PS-DI9 33410 PS-DI10 33411 PROT-DI1 33412 PROT-DI2 33413 PROT-DI3 33414 PROT-DI4 33415 PROT-DI5

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


356

Sprecher A

utomation D

eutschland Gm

bH

PS-CO PS-AO PROT-DO Function module Output command 1 2 3 4 1 2 1 2 3 4 5 6 7 8 Virtual Inputs 35401 vDI1 35402 vDI2 35403 vDI3 35404 vDI4 35405 vDI5 35406 vDI6 35407 vDI7 35408 vDI8 35409 vDI9 35410 vDI10 35411 vDI11 35412 vDI12 35413 vDI13 35414 vDI14 35415 vDI15 Additionals 51860 Test Mode 51770 Local Operation Com.+SubstCtrl.\ Substation Control 51660 InformationBlockg. 51661 Aux. Input 1 51662 Aux. Input 2 51663 Aux. Input 3 51664 Aux. Input 4 setting as delivered

In the above table, the output commands can be used in negated form. To identify negated use, ”N“ and – in case of non-negated use – “X” can be entered. The logic operation (AND, OR) assigned to the relay in question is effective subsequently if several output commands are used.

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


357

Sprecher A

utomation D

eutschland Gm

bH

Table 19 Output configuration of LED Function module Output command Latch-

ing 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

CB Adaptation 460 CB closed manually 461 CB Position On 462 CB Position Off 490 TripCircSupv FctOn 499 Blockage TripCircSv 480 Malfunct TripCircuit Transf. Adaptation 360 FuseVoltageTransf. 361 Fuse VT U4 Characteristic Set 271 Char. Set 1 act. 272 Char. Set 2 act. 273 Char. Set 3 act. 274 Char. Set 4 act. System Adaptation \ System Adaptation 571 Left Handed (L132) 572 Right Handed (L123) Protection Modules \ Measurand Check 18163 3phase I < Imin 18190 Superv.IPath FctOn 18199 Block. Check IPath 18180 I Path disturbed 18274 3phase U < Umin 18290 Superv.UPath FctOn 18299 Block. Check UPath 18281 WarnPhaseSequ. V 18390 Superv.UNE FctOn 18399 Block. Check UNE 18370 UNE>Check 18280 U Path disturbed 18282 I> Backup Operation Direction Decision 1990 Sh.C.Direct FctOn 1999 Blockage SCD 1971 Short Circ.forward

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


358

Sprecher A

utomation D

eutschland Gm

bH

Function module Output command Latch-ing 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

1972 Short Circ.reverse 1974 3ph. U<Umem min 2990 EarthSCDirectFctOn 2999 Blockage ESCD 2970 IE>,UNE>UNEmin ESCD 2971 Earth-SC forward 2972 Earth-SC reverse Dist (U-) I Start 5890 (U-) I Start FctOn 5899 Block. (U-) I-Start 5870 (U-) I gen. Start 5871 (U-) I Start L1 5872 (U-) I Start L2 5873 (U-) I Start L3 Z< Start 5990 Z< Start FctOn 5999 Blockage Z< 5970 Z< general start 5971 Z< Start 1-E 5972 Z< Start 2-E 5973 Z< Start 3-E 5974 Z< Start 1-2 5975 Z< Start 2-3 5976 Z< Start 3-1 Loop Determination 4990 IE>EFC FctOn 4999 Blockage IE>EFC 4970 IE>EFC Start 4991 UNE>EFC FctOn 4997 Blockage UNE>EFC 4971 UNE>EFC Start 4980 EF Crit. satisf. 4981 loop selection 1E 4982 loop selection 2E 4983 loop selection 3E 4984 loop selection 12 4985 loop selection 23 4986 loop selection 31

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


359

Sprecher A

utomation D

eutschland Gm

bH


Distance Module 5090 Distance FctOn 5190 Z1,t1 FctOn 5199 Blockage Z1,t1 5170 Start Zone Z1 5180 Decision Zone Z1,t1 5181 Zone t1 expired 5290 Z1x,t1x FctOn 5299 Blockage Z1x,t1x 5260 Signal Z1x,t1x 5270 Start Zone Z1x 5280 Decision Zone Z1x,t1x 5281 Zone t1x expired 5390 Z2,t2 FctOn 5399 Blockage Z2,t2 5370 Start Zone Z2 5380 Decision Zone Z2,t2 5381 Zone t2 expired 5490 Z3,t3 FctOn 5499 Blockage Z3,t3 5470 Start Zone Z3 5480 Decision Zone Z3,t3 5481 Zone t3 expired 5590 Z4,t4 FctOn 5599 Blockage Z4,t4 5570 Start Zone Z4 5580 Decision Zone Z4,t4 5581 Zone t4 expired 5690 t5 FctOn 5699 Blockage t5 5680 DecisionDir.BackupTime 5681 Zone t5 expired 5790 t6 FctOn

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


360

Sprecher A

utomation D

eutschland Gm

bH


5799 Blockage t6 5780 Decision Time Limit t6 5781 Zone t6 expired Earthfault Detection 7090 EFDetect. FctOn 7099 Block. Earth.Det. 7073 UNE>EF 7070 Earthfault 7081 Earthfault L1 7082 Earthfault L2 7083 Earthfault L3 7080 t TRIP EF expired 7061 EarthFlt. forw.ext. 7062 EarthFlt. rev. ext 7071 EarthFlt. forw. 7072 EarthFlt. rev. Reclose Lockout 4590 Recl.Lockout FctOn 4599 Block. ReclLockout 4560 Set RecloseLockout 4561 Reset Recl.Lockout 4570 Reclose Lockout IL> (Emerg.) OTP 1190 IL> Start FctOn 1199 Blockage IL> 1171 I1> Start 1172 I2> Start 1173 I3> Start 1180 tIL> expired 1290 IL>> Start FctOn 1299 Blockade IL>> 1271 I1>> Start 1272 I2>> Start 1273 I3>> Start 1280 tIL>> expired 1390 IL>>> Start FctOn 1399 Blockage IL>>>

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


361

Sprecher A

utomation D

eutschland Gm

bH


1371 I1>>> Start 1372 I2>>> Start 1373 I3>>> Start 1380 tIL>>> expired 1490 IL>>>> Start FctOn 1499 Blockage IL>>>> 1471 I1>>>> Start 1472 I2>>>> Start 1473 I3>>>> Start 1480 tIL>>>> expired IE> (Emerg.) OTP 2190 IE> Start FctOn 2199 Blockage IE> 2170 IE> Start 2180 tIE> expired 2290 IE>> Start FctOn 2299 Blockage IE>> 2270 IE>> Start 2280 tIE>> expired 2390 IE>>> Start FctOn 2399 Blockage IE>>> 2370 IE>>> Start 2380 tIE>>> expired 2490 IE>>>> Start FctOn 2499 Blockage IE>>>> 2470 IE>>>> Start 2480 tIE>>>> expired 2890 IE>int Start FctOn 2899 Blockage IE>int 2870 IE>int Start 2880 tIE>int expired 2879 IE>int Cycle 2861 Reset tIE>int

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


362

Sprecher A

utomation D

eutschland Gm

bH


Switch-On Protection 8090 SOTF FctOn 8099 Blockage SOTF 8490 Dist. SOTF FctOn 8480 SOTF Distance 8079 top SOTF runs 8190 IL>SOTF FctOn 8171 IL1> SOTF Start 8172 IL2> SOTF Start 8173 IL3> SOTF Start 8180 tIL> SOTF expired 8290 IE> SOTF FctOn 8270 IE> SOTF Start 8280 tIE>SOTF expired 8390 Ineg>SOTF FctOn 8370 Ineg>SOTF Start 8380 tIneg>SOTF expired 8070 SOTF general Start Negative Sequence I 3190 Ineg> Start FctOn 3199 Blockage Ineg> 3170 Ineg> Start 3180 tIneg> expired 3290 Ineg>>Start FctOn 3299 Blockage Ineg>> 3270 Ineg>> Start 3280 tIneg>> expired 3275 Ineg gen. Start Inrush Restraint 6890 Inrushrest. FctOn 6899 Blockage IR 6870 Inrushrest. gen. 6871 Inrushrest. L1 6872 Inrushrest. L2 6873 Inrushrest. L3

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


363

Sprecher A

utomation D

eutschland Gm

bH


Auto-Reclose (AR) 9990 AR FctOn 9999 AR extern Blockage 9979 tblockAR CBC runs 9963 CB ready 9960 AR External Start 9971 AR ready 9972 AR not ready 9970 AR-Cycle 9973 AR IntruptTrip.Sig 9974 CBTRIPSignal later 9980 CLOSE by AR Teleprotection 19090 Teleprot. FctOn 19099 Blockage TP 19062 H2:Subst.BlockSignal 19074 StationBus disturb. 19071 TP Send Signal 19060 TP Signal Input 19072 TP Signal received 19073 TP Connect.disturbed Voltage Protection 14190 U> FctOn 14199 Blockage U> 14171 U1E> Start 14172 U2E> Start 14173 U3E> Start 14174 U12> Start 14175 U23> Start 14176 U31> Start 14180 tU> expired 14290 U>> FctOn 14299 Blockage U>> 14271 U1E>> Start 14272 U2E>> Start 14273 U3E>> Start 14274 U12>> Start 14275 U23>> Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


364

Sprecher A

utomation D

eutschland Gm

bH


14276 U31>> Start 14280 tU>> expired 15190 U< FctOn 15199 Blockage U< 15171 U1E< Start 15172 U2E< Start 15173 U3E< Start 15174 U12< Start 15175 U23< Start 15176 U31< Start 15180 tU< expired 15290 U<< FctOn 15299 Blockage U<< 15271 U1E<< Start 15272 U2E<< Start 15273 U3E<< Start 15274 U12<< Start 15275 U23<< Start 15276 U31<< Start 15280 tU<< expired 14390 UNE> FctOn 14399 Blockage UNE> 14370 UNE> Start 14380 tUNE> expired 14490 UNE>> FctOn 14499 Blockage UNE>> 14470 UNE>> Start 14480 tUNE>> expired Frequency Protect. 16190 f1>< FctOn 16199 Blockage f1>< 16170 f1>< Start 16180 tf1>< expired 16290 f2>< FctOn 16299 Blockage f2>< 16270 f2>< Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


365

Sprecher A

utomation D

eutschland Gm

bH


16280 tf2>< expired 16390 f3>< FctOn 16399 Blockage f3>< 16370 f3>< Start 16380 tf3>< expired 16490 f4>< FctOn 16499 Blockade f4>< 16470 f4>< Start 16480 tf4>< expired Power Protection 17190 P> FctOn 17199 Blockage P> 17170 P> Start 17180 tP> expired 17290 P>> FctOn 17299 Blockage P>> 17270 P>> Start 17280 tP>> expired 17390 Q> FctOn 17399 Blockage Q> 17370 Q> Start 17380 tQ> expired 17490 Q>> FctOn 17499 Blockage Q>> 17470 Q>> Start 17480 tQ>> expired Overload Protection 4190 O.load Prot FctOn 4175 IL > ILmax therm. 4197 Block.therm. TRIP 4178 Recl.Lock Overload 4171 Therm. Level 1 4172 Therm. Level 2 4180 Therm.Level >=100% 4161 Record Therm.Level

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


366

Sprecher A

utomation D

eutschland Gm

bH


General Start 9170 General Start 9171 Start L1 9172 Start L2 9173 Start L3 9174 Start E 9176 DT/IDMT Start CB TRIP 9299 Blockage sign. TRIP 9278 Blockage TRIP 9260 External TRIP 1 9261 External TRIP 2 9270 TRIP not final 9280 TRIP final CBFailure Protection 9390 CBF FctOn 9399 Blockage CBF 9371 Internal CBFailure 9360 Signal CBF extern. 9372 tCBF extern. expired Fault Location 9490 Fault Loc. FctOn 9499 Blockage FL 9470 Fault Loc. < 100% Synchrocheck 9790 Synchrocheck FctOn 9799 Blockage SyncCheck 9760 Bypass SyncCheck 9770 SynchrocheckActive 9771 Sync Measure Req. 9772 Sync Malfunction 9773 Udiff > Udiff max 9774 fdiff > fdiff max 9775 phidiff>phidiffmax 9776 US1 <> Usync 9777 US2 <> Usync 9783 Udiff < Udiff max 9784 fdiff < fdiff max 9785 phidiff<phidiffmax 9786 < US1 Usync >

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


367

Sprecher A

utomation D

eutschland Gm

bH


9787 < US2 Usync > 9778 Synchronism 9779 tsync expired 9780 tsyncmax expired 9761 US2 3~ Dead 9762 US2 3~ Live 9791 US1 Dead / US2 Dead 9792 US1 Live / US2 Dead 9793 US1 Dead / US2 Live 9794 Bypass active 9795 tdeadlive expired 9796 Sync: CB CLOSE Synchrocheck AR 9890 Syncheck AR FctOn Current Annunciation 11190 IL>an FctOn 11199 Blockage IL>an 11171 IL1 > IL> an 11172 IL2 > IL> an 11173 IL3 > IL> an 11180 tIL> an expired 11290 IL>>an FctOn 11299 Blockage IL>> an 11271 IL1 > IL>> an 11272 IL2 > IL>> an 11273 IL3 > IL>> an 11280 tIL>>an expired 12190 IE>an FctOn 12199 Blockage IE> an 12170 IE > IE>an 12180 tIE>an expired Pulse Shaping 19190 Signal1 Fct On 19170 Signal 1 19199 Block.I/O-Coupl.1 19180 IO Coupl. signal 1 19290 Signal2 FctOn 19270 Signal 2

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


368

Sprecher A

utomation D

eutschland Gm

bH


19299 Block.I/O-Coupl.2 19280 IO Coupl. signal 2 Temperature 4490 Temp.Monit. FctOn Protection 4499 Block. Temp.Monit. 4471 Warning Temp.1 4473 Temperature 1 > 4474 Warn.Level1 Temp.2 4475 Warn.Level2 Temp.2 4476 Temperature 2 > 4477 Warn.Level Temp.3 4478 Temperature 3 > 4479 Warn.Level Temp.4 4480 Temperature 4 > 4481 Warn.Level Temp.5 4482 Temperature 5 > General \ Alarm/Malfunction 51270 Alarm 51273 Warning Pt100 TI 51280 Malfunction 51281 Malfunct. TripRel. 51271 No Warning/Malfunc. Device On/Off 51171 Protection ready 51172 Protection dead Optocoupler 33401 PS-DI1 33402 PS-DI2 33403 PS-DI3 33404 PS-DI4 33405 PS-DI5 33406 PS-DI6 33407 PS-DI7 33408 PS-DI8 33409 PS-DI9 33410 PS-DI10 33411 PROT-DI1

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


369

Sprecher A

utomation D

eutschland Gm

bH


33412 PROT-DI2 33413 PROT-DI3 33414 PROT-DI4 33415 PROT-DI5 Virtual Inputs 35401 vDI1 35402 vDI2 35403 vDI3 35404 vDI4 35405 vDI5 35406 vDI6 35407 vDI7 35408 vDI8 35409 vDI9 35410 vDI10 35411 vDI11 35412 vDI12 35413 vDI13 35414 vDI14 35415 vDI15 Additionals 51860 Test Mode 51770 Local Operation Com.+SubstCtrl. \ Substation Control 51660 InformationBlockg. 51661 Aux. Input 1 51662 Aux. Input 2 51663 Aux. Input 3 51664 Aux. Input 4 setting with delivery: steady light / in column “latching “ for latching

setting with delivery: flashing

Available are latching and updating as well as steady light (e.g. insert “x”) or flashing (“B“)

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


370

Sprecher A

utomation D

eutschland Gm

bH

Table 20 Output configuration of virtual digital inputs

Function module Output command vDI 1

vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

*) at device under Setting Set\ Cmd.->Inputs (vDI) \ Logic Logic (and/or): *

Equipment Adaptation \ CB Adaptation 460 CB closed manually 461 CB Position On 462 CB Position Off 490 TripCircSupv FctOn 499 Blockage TripCircSv 480 Malfunct TripCircuit Transf. Adaptation 360 FuseVoltageTransf. 361 Fuse VT U4 Characteristic Set 271 Char. Set 1 act. 272 Char. Set 2 act. 273 Char. Set 3 act. 274 Char. Set 4 act. System Adaptation\ System Adaptation 571 Left Handed (L132) 572 Right Handed (L123) Protection Modules \ Measurand Check 18163 3phase I < Imin 18190 Superv.IPath FctOn 18199 Block. Check IPath 18180 I Path disturbed 18274 3phase U < Umin 18290 Superv.UPath FctOn 18299 Block. Check UPath 18281 WarnPhaseSequ. V 18390 Superv.UNE FctOn 18399 Block. Check UNE 18370 UNE>Check 18280 U Path disturbed 18282 I> Backup Operation

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


371

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

Direction Decision 1990 Sh.C.Direct FctOn 1999 Blockage SCD 1971 Short Circ.forward 1972 Short Circ.reverse 1974 3ph. U<Umem min 2990 EarthSCDirectFctOn 2999 Blockage ESCD 2970 IE>,UNE>UNEmin ESCD 2971 Earth-SC forward 2972 Earth-SC reverse Dist (U-) I Start 5890 (U-) I Start FctOn 5899 Block. (U-) I-Start 5870 (U-) I gen. Start 5871 (U-) I Start L1 5872 (U-) I Start L2 5873 (U-) I Start L3 Z< Start 5990 Z< Start FctOn 5999 Blockage Z< 5970 Z< general start 5971 Z< Start 1-E 5972 Z< Start 2-E 5973 Z< Start 3-E 5974 Z< Start 1-2 5975 Z< Start 2-3 5976 Z< Start 3-1

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


372

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

Loop Determination 4990 IE>EFC FctOn 4999 Blockage IE>EFC 4970 IE>EFC Start 4991 UNE>EFC FctOn 4997 Blockage UNE>EFC 4971 UNE>EFC Start 4980 EF Crit. satisf. 4981 loop selection 1E 4982 loop selection 2E 4983 loop selection 3E 4984 loop selection 12 4985 loop selection 23 4986 loop selection 31 Distance Module 5090 Distance FctOn 5190 Z1,t1 FctOn 5199 Blockage Z1,t1 5170 Start Zone Z1 5180 Decision Zone Z1,t1 5181 Zone t1 expired 5290 Z1x,t1x FctOn 5299 Blockage Z1x,t1x 5260 Signal Z1x,t1x 5270 Start Zone Z1x 5280 Decision Zone Z1x,t1x 5281 Zone t1x expired 5390 Z2,t2 FctOn 5399 Blockage Z2,t2 5370 Start Zone Z2 5380 Decision Zone Z2,t2 5381 Zone t2 expired 5490 Z3,t3 FctOn 5499 Blockage Z3,t3 5470 Start Zone Z3

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


373

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

5480 Decision Zone Z3,t3 5481 Zone t3 expired 5590 Z4,t4 FctOn 5599 Blockage Z4,t4 5570 Start Zone Z4 5580 Decision Zone Z4,t4 5581 Zone t4 expired 5690 t5 FctOn 5699 Blockage t5 5680 DecisionDir.BackupTime 5681 Zone t5 expired 5790 t6 FctOn 5799 Blockage t6 5780 Decision Time Limit t6 5781 Zone t6 expired Earthfault Detection 7090 EFDetect. FctOn 7099 Block. Earth.Det. 7073 UNE>EF 7070 Earthfault 7081 Earthfault L1 7082 Earthfault L2 7083 Earthfault L3 7080 t TRIP EF expired 7061 EarthFlt. forw.ext. 7062 EarthFlt. rev. ext 7071 EarthFlt. forw. 7072 EarthFlt. rev. Reclose Lockout 4590 Recl.Lockout FctOn 4599 Block. ReclLockout 4560 Set RecloseLockout 4561 Reset Recl.Lockout 4570 Reclose Lockout

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


374

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

IL> (Emerg.) OTP 1190 IL> Start FctOn 1199 Blockage IL> 1171 I1> Start 1172 I2> Start 1173 I3> Start 1180 tIL> expired 1290 IL>> Start FctOn 1299 Blockage IL>> 1271 I1>> Start 1272 I2>> Start 1273 I3>> Start 1280 tIL>> expired 1390 IL>>> Start FctOn 1399 Blockage IL>>> 1371 I1>>> Start 1372 I2>>> Start 1373 I3>>> Start 1380 tIL>>> expired 1490 IL>>>> Start FctOn 1499 Blockage IL>>>> 1471 I1>>>> Start 1472 I2>>>> Start 1473 I3>>>> Start 1480 tIL>>>> expired IE> (Emerg.) OTP 2190 IE> Start FctOn 2199 Blockage IE> 2170 IE> Start 2180 tIE> expired 2290 IE>> Start FctOn 2299 Blockage IE>> 2270 IE>> Start 2280 tIE>> expired 2390 IE>>> Start FctOn 2399 Blockage IE>>>

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


375

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

2370 IE>>> Start 2380 tIE>>> expired 2490 IE>>>> Start FctOn 2499 Blockage IE>>>> 2470 IE>>>> Start 2480 tIE>>>> expired 2890 IE>int Start FctOn 2899 Blockage IE>int 2870 IE>int Start 2880 tIE>int expired 2879 IE>int Cycle 2861 Reset tIE>int Switch-On Protection 8090 SOTF FctOn 8099 Blockage SOTF 8490 Dist. SOTF FctOn 8480 SOTF Distance 8079 top SOTF runs 8190 IL>SOTF FctOn 8171 IL1> SOTF Start 8172 IL2> SOTF Start 8173 IL3> SOTF Start 8180 tIL> SOTF expired 8290 IE> SOTF FctOn 8270 IE> SOTF Start 8280 tIE>SOTF expired 8390 Ineg>SOTF FctOn 8370 Ineg>SOTF Start 8380 tIneg>SOTF expired 8070 SOTF general Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


376

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

Negative Sequence I 3190 Ineg> Start FctOn 3199 Blockage Ineg> 3170 Ineg> Start 3180 tIneg> expired 3290 Ineg>>Start FctOn 3299 Blockage Ineg>> 3270 Ineg>> Start 3280 tIneg>> expired 3275 Ineg gen. Start Inrush Restraint 6890 Inrushrest. FctOn 6899 Blockage IR 6870 Inrushrest. gen. 6871 Inrushrest. L1 6872 Inrushrest. L2 6873 Inrushrest. L3 Auto-Reclose (AR) 9990 AR FctOn 9999 AR extern Blockage 9979 tblockAR CBC runs 9963 CB ready 9960 AR External Start 9971 AR ready 9972 AR not ready 9970 AR-Cycle 9973 AR IntruptTrip.Sig 9974 CBTRIPSignal later 9980 CLOSE by AR Teleprotection 19090 Teleprot. FctOn 19099 Blockage TP 19062 H2:Subst.BlockSignal 19074 StationBus disturb. 19071 TP Send Signal 19060 TP Signal Input 19072 TP Signal received 19073 TP Connect.disturbed

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


377

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

Voltage Protection 14190 U> FctOn 14199 Blockage U> 14171 U1E> Start 14172 U2E> Start 14173 U3E> Start 14174 U12> Start 14175 U23> Start 14176 U31> Start 14180 tU> expired 14290 U>> FctOn 14299 Blockage U>> 14271 U1E>> Start 14272 U2E>> Start 14273 U3E>> Start 14274 U12>> Start 14275 U23>> Start 14276 U31>> Start 14280 tU>> expired 15190 U< FctOn 15199 Blockage U< 15171 U1E< Start 15172 U2E< Start 15173 U3E< Start 15174 U12< Start 15175 U23< Start 15176 U31< Start 15180 tU< expired 15290 U<< FctOn 15299 Blockage U<< 15271 U1E<< Start 15272 U2E<< Start 15273 U3E<< Start 15274 U12<< Start 15275 U23<< Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


378

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

15276 U31<< Start 15280 tU<< expired 14390 UNE> FctOn 14399 Blockage UNE> 14370 UNE> Start 14380 tUNE> expired 14490 UNE>> FctOn 14499 Blockage UNE>> 14470 UNE>> Start 14480 tUNE>> expired Frequency Protect. 16190 f1>< FctOn 16199 Blockage f1>< 16170 f1>< Start 16180 tf1>< expired 16290 f2>< FctOn 16299 Blockage f2>< 16270 f2>< Start 16280 tf2>< expired 16390 f3>< FctOn 16399 Blockage f3>< 16370 f3>< Start 16380 tf3>< expired 16490 f4>< FctOn 16499 Blockage f4>< 16470 f4>< Start 16480 tf4>< expired

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


379

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

Power Protection 17190 P> FctOn 17199 Blockage P> 17170 P> Start 17180 tP> expired 17290 P>> FctOn 17299 Blockage P>> 17270 P>> Start 17280 tP>> expired 17390 Q> FctOn 17399 Blockage Q> 17370 Q> Start 17380 tQ> expired 17490 Q>> FctOn 17499 Blockage Q>> 17470 Q>> Start 17480 tQ>> expired Overload Protection 4190 O.load Prot FctOn 4175 IL > ILmax therm. 4197 Block.therm. TRIP 4178 Recl.Lock Overload 4171 Therm. Level 1 4172 Therm. Level 2 4180 Therm.Level >=100% 4161 Record Therm.Level General Start 9170 General Start 9171 Start L1 9172 Start L2 9173 Start L3 9174 Start E 9176 DT/IDMT Start

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


380

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

CB TRIP 9299 Blockage sign. TRIP 9278 Blockage TRIP 9260 External TRIP 1 9261 External TRIP 2 9270 TRIP not final 9280 TRIP final CBFailure Protection 9390 CBF FctOn 9399 Blockage CBF 9371 Internal CBFailure 9360 Signal CBF extern. 9372 tCBF extern. expired Fault Location 9490 Fault Loc. FctOn 9499 Blockage FL 9470 Fault Loc. < 100% Synchrocheck 9790 Synchrocheck FctOn 9799 Blockage SyncCheck 9760 Bypass SyncCheck 9770 SynchrocheckActive 9771 Sync Measure Req. 9772 Sync Malfunction 9773 Udiff > Udiff max 9774 fdiff > fdiff max 9775 phidiff>phidiffmax 9776 US1 <> Usync 9777 US2 <> Usync 9783 Udiff < Udiff max 9784 fdiff < fdiff max 9785 phidiff<phidiffmax 9786 < US1 Usync > 9787 < US2 Usync > 9778 Synchronism 9779 tsync expired 9780 tsyncmax expired 9761 US2 3~ Dead

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


381

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

9762 US2 3~ Live 9791 US1 Dead / US2 Dead 9792 US1 Live / US2 Dead 9793 US1 Dead / US2 Live 9794 Bypass active 9795 tdeadlive expired 9796 Sync: CB CLOSE Synchrocheck AR 9890 Syncheck AR FctOn Current Annunciation 11190 IL>an FctOn 11199 Blockage IL>an 11171 IL1 > IL> an 11172 IL2 > IL> an 11173 IL3 > IL> an 11180 tIL> an expired 11290 IL>>an FctOn 11299 Blockage IL>> an 11271 IL1 > IL>> an 11272 IL2 > IL>> an 11273 IL3 > IL>> an 11280 tIL>>an expired 12190 IE>an FctOn 12199 Blockage IE> an 12170 IE > IE>an 12180 tIE>an expired Pulse Shaping 19190 Signal1 Fct On 19170 Signal 1 19199 Block.I/O-Coupl.1 19180 IO Coupl. signal 1 19290 Signal2 FctOn 19270 Signal 2 19299 Block.I/O-Coupl.2 19280 IO Coupl. signal 2

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


382

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

Temperature 4490 Temp.Monit. FctOn Protection 4499 Block. Temp.Monit. 4471 Warning Temp.1 4473 Temperature 1 > 4474 Warn.Level1 Temp.2 4475 Warn.Level2 Temp.2 4476 Temperature 2 > 4477 Warn.Level Temp.3 4478 Temperature 3 > 4479 Warn.Level Temp.4 4480 Temperature 4 > 4481 Warn.Level Temp.5 4482 Temperature 5 > General \ Alarm/Malfunction 51270 Alarm 51273 Warning Pt100 TI 51280 Malfunction 51281 Malfunct. TripRel. 51271 No Warning/Malfunc. Device On/Off 51171 Protection ready 51172 Protection dead Optocoupler 33401 PS-DI1 33402 PS-DI2 33403 PS-DI3 33404 PS-DI4 33405 PS-DI5 33406 PS-DI6 33407 PS-DI7 33408 PS-DI8 33409 PS-DI9 33410 PS-DI10 33411 PROT-DI1 33412 PROT-DI2 33413 PROT-DI3

Appendix 1

1

SPRECO

N-E-Pxx-D

Dx6 U


383

Sprecher A

utomation D

eutschland Gm

bH


vDI 2

vDI 3

vDI 4

vDI 5

vDI 6

vDI 7

vDI 8

vDI 9

vDI 10

vDI 11

vDI 12

vDI 13

vDI 14

vDI 15

33414 PROT-DI4 33415 PROT-DI5 Virtual Inputs 35401 vDI1 35402 vDI2 35403 vDI3 35404 vDI4 35405 vDI5 35406 vDI6 35407 vDI7 35408 vDI8 35409 vDI9 35410 vDI10 35411 vDI11 35412 vDI12 35413 vDI13 35414 vDI14 35415 vDI15 Additionals 51860 Test Mode 51770 Local Operation Com.+SubstCtrl. \ Substation Control 51660 InformationBlockg. 51661 Aux. Input 1 51662 Aux. Input 2 51663 Aux. Input 3 51664 Aux. Input 4

Appendix 11


Table 21 Output commands explained

Function module Output command Explanation Equipment Adaptation \ CB-Adaptation 460 CB closed manually pass-through of identically named input signal 461 CB Position On pass-through of identically named input signal 462 CB Position Off pass-through of identically named input signal 490 TripCircSupv FctOn active if function is enabled 499 Blockage TripCircSv pass-through of identically named input signal 480 Malfunct TripCircuit annunciation of disturbed trip circuit Transf. Adaptation 360 FuseVoltageTransf. pass-through of identically named input signal 361 Fuse VT U4 pass-through of identically named input signal Characteristic Set 271 Char. Set 1 act. signalling of the active characteristic set 1 272 Char. Set 2 act. signalling of the active characteristic set 2 273 Char. Set 3 act. signalling of the active characteristic set 3 274 Char. Set 4 act. signalling of the active characteristic set 4 System Adaptation \ System Adaptation 571 Left Handed (L132) signalling of an anti-clockwise rotating field 572 Right Handed (L123) signalling of a clockwise rotating field Protection Modules \ Measurand Check 18163 3phase I < Imin all currents below 18108 Imin=Line dead 18190 Superv.IPath FctOn active if function is enabled 18199 Block. Check IPath pass-through of identically named input signal 18180 I Path disturbed also included in group alarm 51270 Alarm 18274 3phase U < Umin all voltages lower than 18208 Umin 18290 Superv.UPath FctOn active if function is enabled 18299 Block. Check UPath pass-through of identically named input signal 18281 WarnPhaseSequ. V signalling of a wrong rotating voltage field (included in 18280) 18390 Superv.UNE FctOn active if function enabled 18399 Block. Check UNE pass-through of identically named input signal 18370 UNE>Check signal overrange of pickup value 18301 UNE>Check 18280 U Path disturbed also included in group alarm 51270 Alarm 18282 I> Backup Operation emergency OTP active Direction Decision 1990 Sh.C.Direct FctOn active if function is enabled 1999 Blockage SCD pass-through of identically named input signal 1971 Short Circ.forward short circuit direction forward active 1972 Short Circ.reverse short circuit direction reverse active

1974 3ph. U<Umem min underflow of the operate value of voltage memory 1908 Umem if ULL <

2990 EarthSCDirectFctOn active if function enabled 2999 Blockage ESCD pass-through of identically named input signal

2970 IE>,UNE>UNEmin ESCD signalling of starting of the earth-fault direction (IE> alone+UNE>)

2971 Earth-SC forward earth short circuit fault direction forward active 2972 Earth-SC reverse earth short circuit fault direction reverse active Dist (U-) I Start 5890 (U-) I Start FctOn active if function is enabled 5899 Block. (U-) I-Start pass-through of identically named input signal 5870 (U-) I gen. Start distance protection start by (U-) I start 5871 (U-) I Start L1 5872 (U-) I Start L2 5873 (U-) I Start L3

phase-selective signal of a voltage independent or voltage de-pendent current starting

Z< Start 5990 Z< Start FctOn active if function is enabled 5999 Blockage Z< pass-through of identically named input signal 5970 Z< general start distance protection start by polygonal Z< start 5971 Z< Start 1-E 5972 Z< Start 2-E 5973 Z< Start 3-E 5974 Z< Start 1-2 5975 Z< Start 2-3 5976 Z< Start 3-1

loop-selective signal of underimpedance starting by polygonal Z< start

Appendix 11


Function module Output command Explanation Loop Determination 4990 IE>EFC FctOn active if function is enabled 4999 Blockage IE>EFC pass-through of identically named input signal 4970 IE>EFC Start exceeding of the stabilised setting value 4901 IE>EFC 4991 UNE>EFC FctOn active if function is enabled 4997 Blockage UNE>EFC pass-through of identically named input signal 4971 UNE>EFC Start exceeding of the setting value 4905 UNE>EFC 4980 EF Crit. satisf. earth fault criterion is currently met 4981 loop selection 1E 4982 loop selection 2E 4983 loop selection 3E 4984 loop selection 12 4985 loop selection 23 4986 loop selection 31

signalling of the selected loop

Distance Module 5090 Distance FctOn active if function is enabled 5190 Z1,t1 FctOn active if function is enabled 5199 Blockage Z1,t1 pass-through of identically named input signal 5170 Start Zone Z1 start by impedance in Zone Z1 (start timer with zone) 5180 Decision Zone Z1,t1 determined impedance lies in Zone Z1 and time t1 is up*) 5181 Zone t1 expired timer 5111 t1 expired 5290 Z1x,t1x FctOn active if function is enabled 5299 Blockage Z1x,t1x pass-through of identically named input signal 5260 Signal Z1x,t1x pass-through of identically named input signal 5270 Start Zone Z1x start by impedance in Zone Z1 (start timer with zone) 5280 Decision Zone Z1x,t1x determined impedance lies in Zone Z1 and time t1 is up *) 5281 Zone t1x expired timer 5211 t1x expired 5390 Z2,t2 FctOn active if function is enabled 5399 Blockage Z2,t2 pass-through of identically named input signal 5370 Start Zone Z2 start by impedance in Zone Z2 (start timer with zone) 5380 Decision Zone Z2,t2 determined impedance lies in Zone Z2 and time t2 is up *) 5381 Zone t2 expired timer 5311 t2 expired 5490 Z3,t3 FctOn active if function is enabled 5499 Blockage Z3,t3 pass-through of identically named input signal 5470 Start Zone Z3 start by impedance in Zone Z3 (start timer with zone) 5480 Decision Zone Z3,t3 determined impedance lies in Zone Z3 and time t3 is up *) 5481 Zone t3 expired timer 5411 t3 expired 5590 Z4,t4 FctOn active if function is enabled 5599 Blockage Z4,t4 pass-through of identically named input signal 5570 Start Zone Z4 start by impedance in Zone Z4 (start timer with zone) 5580 Decision Zone Z4,t4 determined impedance lies in Zone Z4 and time t4 is up *) 5581 Zone t4 expired timer 5511 t4 expired 5690 t5 FctOn active if function is enabled 5699 Blockage t5 pass-through of identically named input signal 5680 DecisionDir.BackupTime TRIP request, direction identical with the defined one *) 5681 Zone t5 expired timer 5611 t5 expired 5790 t6 FctOn active if function is enabled 5799 Blockage t6 pass-through of identically named input signal 5780 Decision Time Limit t6 TRIP request after timer t6 (-103 signal) has expired *) 5781 Zone t6 expired timer 5711 t6 expired Earthfault Detection 7090 EFDetect. FctOn active if function is enabled 7099 Block. Earth.Det. pass-through of identically named input signal 7073 UNE>EF signalling of the exceeding of the setting value 7002 UNE>EF

7070 Earthfault group signal of an active earth fault (after 7014 tUNE>EF Time f. UNE> exceeded)

7081 Earthfault L1 7082 Earthfault L2 7083 Earthfault L3

phase-selective signal of an active earth fault

7080 t TRIP EF expired TRIP decision by earth-fault detection module *) 7061 EarthFlt. forw.ext. external signal of forward earth fault direction 7062 EarthFlt. rev. ext external signal of reverse earth fault direction 7071 EarthFlt. forw. earth fault direction forward is active 7072 EarthFlt. rev. earth fault direction reverse is active Reclose Lockout 4590 Recl.Lockout FctOn active if function is enabled

Appendix 11


Function module Output command Explanation 4599 Block. ReclLockout pass-through of identically named input signal 4560 Set RecloseLockout pass-through of identically named input signal 4561 Reset Recl.Lockout pass-through of identically named input signal

4570 Reclose Lockout reclose lockout for configuration on a relay as a series circuit in the ON circle of the circuit breaker therefore preventing a switch in

IL> (Emerg.) OTP 1190 IL> Start FctOn active if function is enabled 1199 Blockage IL> pass-through of identically named input signal 1171 I1> Start 1172 I2> Start 1173 I3> Start

phase-selective signal of the exceeding of the pickup value 1101 IL> Definite Time or 1102 IL> Inverse Time

1180 tIL> expired signal that the timer has expired *) 1290 IL>> Start FctOn active if function is enabled 1299 Blockage IL>> pass-through of identically named input signal 1271 I1>> Start 1272 I2>> Start 1273 I3>> Start

phase-selective signal of the exceeding of the pickup value 1201 IL>>

1280 tIL>> expired signal that the timer has expired *) 1390 IL>>> Start FctOn active if function is enabled 1399 Blockage IL>>> pass-through of identically named input signal 1371 I1>>> Start 1372 I2>>> Start 1373 I3>>> Start

phase-selective signal of the exceeding of the pickup value 1301 IL>>>

1380 tIL>>> expired signal that the timer has expired *) 1490 IL>>>> Start FctOn active if function is enabled 1499 Blockage IL>>>> pass-through of identically named input signal 1471 I1>>>> Start 1472 I2>>>> Start 1473 I3>>>> Start

phase-selective signal of the exceeding of the pickup value 1401 IL>>>>

1480 tIL>>>> expired signal that the timer has expired *) IE> (Emerg.) OTP 2190 IE> Start FctOn active if function is enabled 2199 Blockage IE> pass-through of identically named input signal

2170 IE> Start signal of the exceeding of the pickup value 2101 IE> Definite Time resp. 2105 IE> Definit.Time sens or 2102 IE> Inverse Time resp. 2106 IE> Inv. Time sens.

2180 tIE> expired signal of a TRIP demand after the timer has expired *) 2290 IE>> Start FctOn active if function is enabled 2299 Blockage IE>> pass-through of identically named input signal 2270 IE>> Start signal of the exceeding of the pickup value 2201 IE>> 2280 tIE>> expired signal of a TRIP demand after the timer has expired *) 2390 IE>>> Start FctOn active if function is enabled 2399 Blockage IE>>> pass-through of identically named input signal 2370 IE>>> Start signal of the exceeding of the pickup value 2301 IE>>> 2380 tIE>>> expired signal of a TRIP demand after the timer has expired *) 2490 IE>>>> Start FctOn active if function is enabled 2499 Blockage IE>>>> pass-through of identically named input signal 2470 IE>>>> Start signal of the exceeding of the pickup value 2401 IE>>>> 2480 tIE>>>> expired signal of a TRIP demand after the timer has expired *) 2890 IE>int Start FctOn active if function is enabled 2899 Blockage IE>int pass-through of identically named input signal

2870 IE>int Start exceeding of the pickup value “2801 IE>int“ or “2805 IE>int sen-sitive“

2880 tIE>int expired timer “2811 tIE>int Time“ expired, TRIP demanded (TRIP may have been avoided by blocking of the TRIP)

2879 IE>int Cycle starts with reaching the count “2808 IE>int EntryCounter “ and stops with TRIP command or expiration of “2817 tIE>intSumReset Time“

2861 Reset tIE>int handing over of the input signal of the same name for resetting the sum time

Switch-On 8090 SOTF FctOn active if function is enabled Protection 8099 Blockage SOTF pass-through of identically named input signal

8490 Dist. SOTF FctOn active if function switch-on-to-fault protection using distance zone is enabled

8480 SOTF Distance TRIP decision by SOTF after classification into selected zone

8079 top SOTF runs the action time of the switch-on protection after manual close is enabled

Appendix 11


Function module Output command Explanation 8190 IL>SOTF FctOn active if function is enabled 8171 IL1> SOTF Start 8172 IL2> SOTF Start 8173 IL3> SOTF Start

phase-selective signal of the exceeding of the pickup value 8101 IL>SOTF

8180 tIL> SOTF expired signal that the timer has expired *) 8290 IE> SOTF FctOn active if function is enabled 8270 IE>SOTF Start signal of the exceeding of the pickup value 8201 IE>SOTF 8280 tIE>SOTF expired signal that the timer has expired *) 8390 Ineg>SOTF FctOn active if function is enabled 8370 Ineg>SOTF Start signal of the exceeding of the pickup value 8380 tIneg>SOTF expired signal that the timer has expired *) 8070 SOTF general Start summary of single start signals SOTF Negative Sequence I 3190 Ineg> Start FctOn active if function is enabled 3199 Blockage Ineg> pass-through of identically named input signal

3170 Ineg> Start signal of the exceeding of the pickup value 3101 Ineg> Definite Time or 3102 Ineg> Inverse Time

3180 tIneg> expired signal that the timer has expired *) 3290 Ineg>>Start FctOn active if function is enabled 3299 Blockage Ineg>> pass-through of identically named input signal 3270 Ineg>> Start signal of the exceeding of the pickup value 3201 Ineg>> 3280 tIneg>> expired signal that the timer has expired *) 3275 Ineg gen. Start summary of single start signals Ineg Inrush Restraint 6890 Inrushrest. FctOn active if function is enabled 6899 Blockage IR pass-through of identically named input signal

6870 Inrushrest. gen. signalling that current starting element(s) blocked by inrush process

6871 Inrushrest. L1 6872 Inrushrest. L2 6873 Inrushrest. L3

current inrush detection (I2f/I1f>) in specified phase

Auto-Reclose (AR) 9990 AR FctOn active if function is enabled 9999 AR extern Blockage pass-through of identically named input signal 9979 tblockAR CBC runs AR is blocked during manual close active 9963 CB ready pass-through of identically named input signal 9960 AR External Start pass-through of identically named input signal 9971 AR ready readiness for AR exists 9972 AR not ready readiness for AR does not exist

9970 AR-Cycle begins with the AR starting conditions fulfilled, ends with reclaim or blocking time

9973 AR IntruptTrip.Sig suppression of CB tripping alarm (NC contact!) 9974 CBTRIPSignal later subsequent generation of breaker tripping signal (pulse) 9980 CLOSE by AR CLOSE command by AR Teleprotection 19090 Teleprot. FctOn active if function is enabled 19099 Blockage TP pass-through of identically named input signal 19062 H2:Subst.BlockSignal pass-through of identically named input signal

19074 StationBus disturb. H2 logic’s station bus is disturbed; the active level is on for more than 15 s at the input 19062 H2:Station blockage sign

19071 TP Send Signal transmit signal to connected protection device 19060 TP Signal Input pass-through of identically named input signal 19072 TP Signal received input signal interpreted as receive signal via protection module 19073 TP Connect.disturbed signalling transfer distance to remote station disturbed Voltage Protection 14190 U> FctOn active if function is enabled 14199 Blockage U> pass-through of identically named input signal 14171 U1E> Start 14172 U2E> Start 14173 U3E> Start 14174 U12> Start 14175 U23> Start 14176 U31> Start

phase-selective signal of the exceeding of the pickup value 14101 U>

14180 tU> expired signalling command of U> stage *) 14290 U>> FctOn active if function is enabled 14299 Blockage U>> pass-through of identically named input signal 14271 U1E>> Start 14272 U2E>> Start 14273 U3E>> Start 14274 U12>> Start

phase-selective signal of the exceeding of the pickup value 14201 U>

Appendix 11


Function module Output command Explanation 14275 U23>> Start 14276 U31>> Start 14280 tU>> expired signalling command of U>> stage *) 15190 U< FctOn active if function is enabled 15199 Blockage U< pass-through of identically named input signal 15171 U1E< Start 15172 U2E< Start 15173 U3E< Start 15174 U12< Start 15175 U23< Start 15176 U31< Start

phase-selective signal of the exceeding of the pickup value 15101 U<

15180 tU< expired signalling command of U< stage *) 15290 U<< FctOn active if function is enabled 15299 Blockage U<< pass-through of identically named input signal 15271 U1E<< Start 15272 U2E<< Start 15273 U3E<< Start 15274 U12<< Start 15275 U23<< Start 15276 U31<< Start

phase-selective signal of the exceeding of the pickup value 15201 U<<

15280 tU<< expired signalling command of U<< stage *) 14390 UNE> FctOn active if function is enabled 14399 Blockage UNE> pass-through of identically named input signal 14370 UNE> Start signal of the exceeding of the pickup value 14301 UNE> 14380 tUNE> expired signalling command of UNE> stage *) 14490 UNE>> FctOn active if function is enabled 14499 Blockage UNE>> pass-through of identically named input signal 14470 UNE>> Start signal of the exceeding of the pickup value 14401 UNE>> 14480 tUNE>> expired signalling command of UNE>> stage *) Frequency Protect. 16190 f1>< FctOn active if function is enabled 16199 Blockage f1>< pass-through of identically named input signal

16170 f1>< Start signal of the exceeding of the pickup value 16101 f1><, if it is greater than 530 System Frequency resp. underflow if it is smaller

16180 tf1>< expired signalling command of f1>< stage *) 16290 f2>< FctOn active if function is enabled 16299 Blockage f2>< pass-through of identically named input signal






16480 tf4>< expired signalling command of f4>< stage *)

Appendix 11


Function module Output command Explanation Power Protection 17190 P> FctOn active if function is enabled 17199 Blockage P> pass-through of identically named input signal 17170 P> Start outrun of setting value 17101 P> 17180 tP> expired timer 17111 tP> expired 17290 P>> FctOn active if function is enabled 17299 Blockage P>> pass-through of identically named input signal 17270 P>> Start outrun of setting value 17201 P>> 17280 tP>> expired timer 17211 tP>> expired 17390 Q> FctOn active if function is enabled 17399 Blockage Q> pass-through of identically named input signal 17370 Q> Start outrun of setting value 17301 Q> 17380 tQ> expired timer 17311 tQ> expired 17490 Q>> FctOn active if function is enabled 17499 Blockage Q>> pass-through of identically named input signal 17470 Q>> Start outrun of setting value 17401 Q>> 17480 tQ>> expired timer 17411 tQ>> expired Overload Protection 4190 O.load Prot FctOn active if function is enabled 4175 IL > ILmax therm. current is higher than 4111 OLoadProt. up to ILmax 4197 Block.therm. TRIP pass-through of identically named input signal

4178 Recl.Lock Overload Signalling from reclose lockout set by the overload protection. Is included in group command 4570 Reclose Lockout.

4171 Therm. Level 1 thermal warning level 1 4172 Therm. Level 2 thermal warning level 2 4180 Therm.Level >=100% signalling level of thermal map ≥ 100% 4161 Record Therm.Level pass-through of identically named input signal General Start

9170 General Start General start (group signal of starts) which can lead to TRIP. All starts are contained which may lead to TRIP, i.e. also the volt-age starts. If signalling only has been selected for one stage, this command is not activated.

9171 Start L1 group signal of all current starts of phase 1 9172 Start L2 group signal of all current starts of phase 2 9173 Start L3 group signal of all current starts of phase 3 9174 Start E group of all earth current starts 9176 DT/IDMT Start group signal of overcurrent-time protection start CB TRIP 9299 Blockage sign. TRIP pass-through of identically named input signal 9278 Blockage TRIP sum of all TRIP blockages (also via substation control) 9260 External TRIP 1 9261 External TRIP 2

pass-through of the identically named input; the TRIP command is included in the final TRIP

9270 TRIP not final TRIP command by AR; CLOSE to follow. Command must be configured together with final TRIP onto the TRIP relay.

9280 TRIP final General trip of the protection device; it contains all TRIP com-mands of the protection modules, not, however, the non-definite TRIP o AR!

CBFailure Protection 9390 CBF FctOn active if function is enabled 9399 Blockage CBF pass-through of identically named input signal

9371 Internal CBFailure Internal switching failure; must be configured for switching off higher priority supplies!

9360 Signal CBF extern. pass-through of identically named input signal

9372 tCBF extern. expired

Input signal “9360 Signal CBF extern. “ passed through after ex-piry of the time tLSVextern and in case of I > IminCBF (or false switch position). If TRIP command of a resource located at the same switch is monitored, the command must be configured to relays together with it “9371 Internal CBFailure“ in view of tripping higher-priority supplies.

Fault Location 9490 Fault Loc. FctOn active if function is enabled 9499 Blockage FL pass-through of identically named input signal 9470 Fault Loc. < 100% fault location within 100 % setting Synchrocheck 9790 Synchrocheck FctOn active if function is enabled 9799 Blockage SyncCheck pass-through of identically named input signal 9760 Bypass SyncCheck pass-through of identically named input signal 9770 SynchrocheckActive synchronisation process active 9771 Sync Measure Req. synchronisation request of control system is running 9772 Sync Malfunction 9773 Udiff > Udiff max state: voltage difference too big 9774 fdiff > fdiff max state: frequency difference too big 9775 phidiff>phidiffmax state: phase difference too big

Appendix 11


Function module Output command Explanation 9776 US1 <> Usync synchronizing voltage US1 out of allowed range 9777 US2 <> Usync synchronizing voltage US2 out of allowed range 9783 Udiff < Udiff max voltage difference inside allowed range 9784 fdiff < fdiff max frequency difference inside allowed range 9785 phidiff<phidiffmax phase difference inside allowed range 9786 < US1 Usync > synchronizing voltage US1 inside allowed range 9787 < US2 Usync > synchronizing voltage US2 inside allowed range 9778 Synchronism 9779 tsync expired timer 9711 tsync expired 9780 tsyncmax expired timer 9712 tsyncmax expired 9761 US2 3~ Dead pass-through of identically named input signal 9762 US2 3~ Live pass-through of identically named input signal 9791 US1 Dead / US2 Dead both voltages are dead (not sufficiently available) 9792 US1 Live / US2 Dead US2 voltage dead (not sufficiently available) 9793 US1 Dead / US2 Live US1 voltage dead (not sufficiently available) 9794 Bypass active state: connection allowed without synchronization 9795 tdeadlive expired timer 9713 tdeadlive expired 9796 Sync: CB CLOSE ON command Synchrocheck AR 9890 Syncheck AR FctOn active if function is enabled Current 11190 IL>an FctOn active if function is enabled Annunciation 11199 Blockage IL>an pass-through of identically named input signal 11171 IL1 > IL> an 11172 IL2 > IL> an 11173 IL3 > IL> an

phase-selective signalling of pickup value being exceeded 11101 IL>an

11180 tIL> an expired signalling command of IL>an stage 11290 IL>>an FctOn active if function is enabled 11299 Blockage IL>> an pass-through of identically named input signal 11271 IL1 > IL>> an 11272 IL2 > IL>> an 11273 IL3 > IL>> an

phase-selective signalling of pickup value being exceeded 11201 IL>>an

11280 tIL>>an expired signalling command of IL>>an stage 12190 IE>an FctOn active if function is enabled 12199 Blockage IE> an pass-through of identically named input signal

12170 IE > IE>an signalling of pickup value 12101 IE>an or 12105 IE> an sensitive being exceeded

12180 tIE>an expired annunciation command of IE>meld stage Pulse Shaping 19190 Signal1 Fct On active if function is enabled 19170 Signal 1 pass-through of identically named non-processed input signal 1 19199 Block.I/O-Coupl.1 pass-through of identically named input signal 19180 IO Coupl. signal 1 input/output coupling of the processed signal 1 19290 Signal2 FctOn active if function is enabled 19270 Signal 2 pass-through of identically named non-processed input signal 2 19299 Block.I/O-Coupl.2 pass-through of identically named input signal 19280 IO Coupl. signal 2 input/output coupling of the processed signal 2 Temperature 4490 Temp.Monit. FctOn active if function is enabled Protection 4499 Block. Temp.Monit. pass-through of identically named input signal 4471 Warning Temp.1 signalling 4401 warning level of temperature 1 exceeded 4473 Temperature 1 > signalling 4402 temperature limit of temperature 1 exceeded 4474 Warn.Level1 Temp.2 signalling 4403 Warn.Level 1 of temperature 2 exceeded 4475 Warn.Level2 Temp.2 signalling 4404 Warn.Level 2 of temperature 2 exceeded 4476 Temperature 2 > signalling 4405 temperature limit of temperature 2 exceeded 4477 Warn.Level Temp.3 signalling 4406 warning level of temperature 3 exceeded 4478 Temperature 3 > signalling 4407 temperature limit of temperature 3 exceeded 4479 Warn.Level Temp.4 signalling 4408 warning level of temperature 4 exceeded 4480 Temperature 4 > signalling 4409 temperature limit of temperature 4 exceeded 4481 Warn.Level Temp.5 signalling 4410 warning level of temperature 5 exceeded 4482 Temperature 5 > signalling 4411 temperature limit of temperature 5 exceeded

Appendix 11


Function module Output command Explanation General \

Alarm/Malfunction 51270 Alarm Group alarm for all causes of alarms. In case of present alarms, the protection remains operative within certain restrictions.

51273 Warning Pt100 TI signalling of temperature module (PT100)

51280 Malfunction malfunction of protection relay (at the same time, “protection available” disappears)

51281 Malfunct. TripRel. the switching relay’s coil supervision has detected a fault

51271 No Warning/Malfunc. The protection part operates troublefree and does not require maintenance. Contrary to the “available” mode, alarms must not be present either.

Device On/Off

51171 Protection ready

In troublefree operation, protection is the safest and most im-portant command of self-monitoring. If the command is not ac-tive, the protection is inactive! This command is not adequate for signalling the availability of the complete device (protection and substation control modules). The signalling of the availability of both protection and substation control needs to be realized in the control part.

51172 Protection dead protection is not available; tripping either manually or via moni-toring is included

Optocoupler 33401 PS-DI1 pass-through of physical input signal 33402 PS-DI2 pass-through of physical input signal 33403 PS-DI3 pass-through of physical input signal 33404 PS-DI4 pass-through of physical input signal 33405 PS-DI5 pass-through of physical input signal 33406 PS-DI6 pass-through of physical input signal 33407 PS-DI7 pass-through of physical input signal 33408 PS-DI8 pass-through of physical input signal 33409 PS-DI9 pass-through of physical input signal 33410 PS-DI10 pass-through of physical input signal 33411 PROT-DI1 pass-through of physical input signal 33412 PROT-DI2 pass-through of physical input signal 33413 PROT-DI3 pass-through of physical input signal 33414 PROT-DI4 pass-through of physical input signal 33415 PROT-DI5 pass-through of physical input signal Virtual Inputs 35401 vDI1 35402 vDI2 to 35415 vDI15

output of the virtual input configured via output command

Additionals 51860 Test Mode 51770 Local Operation Com.+SubstCtrl. \

Substation Control 51660 InformationBlockg. output of messages and measured values to substation control is blocked

51661 Aux. Input 1 51662 Aux. Input 2 51663 Aux. Input 3 51664 Aux. Input 4

pass-through of identically named input signal

*) TRIP can still be prevented by blocking the TRIP.

Appendix 12


Appendix 12: Message list

Name Description Device Type Protection Protection specific device type Function Protection specific function group Message Text Protocol text for display resp. printer output MTyp AS Alarm signal WM Warning message PS Process signal COM Command DW Double word (relative time with fault number) MV Metered value FP32 Floating point value FUN Function type according to IEC 60870-103: Assignment of the data point to a

device function. INF Information number according to IEC 60870-103: Meaning of a data point in a

function. TYP Type identification according to IEC 60870-103: Determines the structure of a

data point. GI General interrogation CG Comes / Goes

Appendix 12


Device Type SPRECON-E IEC 60870-5-103 DD6 DDE6 DDEY6 Function Message Text MTyp FUN INF TYP SubIdx GI CG

x x x Dist. compatible Protection operating AS 128 18 1 0 Y CG x x x Dist. compatible Set Protection operating COM 128 18 20 0 N x x x Dist. compatible General Start AS 128 84 2 0 Y CG x x x Dist. compatible General Start DW 128 84 2 1 Y x x x Dist. compatible General Trip AS 128 68 2 0 N C x x x Dist. compatible General Trip DW 128 68 2 1 N x x x DD6 general General Trip blocked AS 1 82 1 0 Y CG x x x DD6 general Block General Trip COM 1 82 20 0 N

x x x DD6 general Trip by 1st external Trip Re-quest AS 1 80 2 0 N C

x x x DD6 general Trip by 1st external Trip Re-quest DW 1 80 2 1 N

x x x DD6 general Trip by 2nd external Trip Re-quest AS 1 81 2 0 N C

x x x DD6 general Trip by 2nd external Trip Re-quest DW 1 81 2 1 N

x x x DD6 general Disturbance-Rec. Start by ext. Request PS 1 182 1 0 N C

x x x DD6 general Disturbance-Rec. Start PS 1 253 2 0 N C x x x DD6 general Disturbance-Rec. Start DW 1 253 2 1 N x x x DD6 general Disturbance-Rec. Stop PS 1 254 2 0 N C x x x DD6 general Disturbance-Rec. Stop DW 1 254 2 1 N x x x DD6 general Phase Seq. Lefthand PS 1 91 1 0 Y CG x x x DD6 general Phase Seq. Righthand PS 1 92 1 0 Y CG x x x Dist. compatible Aux. Input 1 PS 128 27 1 0 Y CG x x x Dist. compatible Aux. Input 2 PS 128 28 1 0 Y CG x x x Dist. compatible Aux. Input 3 PS 128 29 1 0 Y CG x x x Dist. compatible Aux. Input 4 PS 128 30 1 0 Y CG x x x Dist. compatible Local Param. Active PS 128 22 1 0 Y CG x x x DD6 general Device-Ident changed PS 1 6 1 0 N C x x x DD6 general Device-Parameter changed PS 1 50 1 0 N C x x x Dist. compatible Characteristic 1 PS 128 23 1 0 Y CG x x x Dist. compatible Characteristic 1 COM 128 23 20 0 N x x x Dist. compatible Characteristic 2 PS 128 24 1 0 Y CG x x x Dist. compatible Characteristic 2 COM 128 24 20 0 N x x x Dist. compatible Characteristic 3 PS 128 25 1 0 Y CG x x x Dist. compatible Characteristic 3 COM 128 25 20 0 N x x x Dist. compatible Characteristic 4 PS 128 26 1 0 Y CG x x x Dist. compatible Characteristic 4 COM 128 26 20 0 N x x x Dist. compatible LED/LCD cleared PS 128 19 1 0 N C x x x Dist. compatible Clear LED/LCD COM 128 19 20 0 N

x x x DD6 general Event-Rec. / Disturbance-Rec. cleared PS 1 2 1 0 N C

x x x DD6 general Clear Event-Rec. / Distur-bance-Rec. COM 1 2 20 0 N

Appendix 12



x x x DD6 general Faultno./Gridfaultno. Cleared PS 1 180 1 0 N C x x x DD6 general Reset to Standard PS 1 181 1 0 N C x x x Dist. compatible Test Mode PS 128 21 1 0 Y CG x x x DD6 general Testmenu Relays PS 1 73 1 0 N CG x x x DD6 general Testmenu Earthfaultl PS 1 74 1 0 N CG x x x DD6 general Trip by CB open test AS 1 72 1 0 N C x x x Dist. compatible Monitoring Direction blocked PS 128 20 1 0 Y CG

x x x DD6 general Statistics cleared PS 1 3 1 0 N C x x x DD6 general Reset Statistics COM 1 3 20 0 N

x x x DD6 general Total amount of Trip Current I1 FP32 1 113 4 0 Y

x x x DD6 general Total amount of Trip Current I1 DW 1 113 4 1 N





x x x DD6 general CB Close Counter MV32 1 116 32 0 N x x x DD6 general CB Open Counter MV32 1 117 32 0 N x x x Dist. compatible Group Warning AS 128 46 1 0 Y CG x x x Dist. compatible Measurand Check I AS 128 32 1 0 Y CG x x x Dist. compatible Measurand Check U AS 128 33 1 0 Y CG x x x Dist. compatible MCB Failure AS 128 38 1 0 Y CG x x x Dist. compatible Phase Sequence Check AS 128 35 1 0 Y CG x DD6 general VT4 Fuse Failure AS 1 140 1 0 Y CG

x x x DD6 general Warning: Pt100 Temperature Meas. AS 1 149 1 0 Y CG

x x x DD6 general Warning: Resource Conflict AS 1 152 1 0 N CG x x x DD6 general Warning: EEPROM empty AS 1 151 1 0 N C x x x DD6 general Warning: Bufferoverflow AS 1 153 1 0 N C

x x x DD6 general Trip Circuit Supervision en-abled AS 1 30 1 0 Y CG

x x x DD6 general Trip Circuit Supervision blocked AS 1 31 1 0 Y CG

x x x Dist. compatible Trip Circuit Supervision AS 128 36 1 0 Y CG x x x Dist. compatible I> Backup Operation AS 128 37 1 0 Y CG x x x Dist. compatible TRIP by Backup Protection AS 128 72 2 0 N C x x x Dist. compatible TRIP by Backup Protection AS 128 72 2 1 N x x x Dist. compatible Group Failure AS 128 47 1 0 Y CG

x x x DD6 general Malfunction: Switching Relays-Fault AS 1 36 1 0 Y CG

x x x DD6 general Malfunction: Trap-Fault AS 1 65 1 0 N C x x x DD6 general Malfunction: Uref-Fault AS 1 67 1 0 N C x x x DD6 general Malfunction: Param.Rd/Wr-Fault AS 1 71 1 0 N C x x x DD6 general Malfunction: Firmware not com- AS 1 155 1 0 N C

Appendix 12



patible

x x x DD6 general Malfunction: Handshake Fault AS 1 157 1 0 N C x x x DD6 general Malfunction: Supply Voltage AS 1 158 1 0 N C x x x DD6 general Malfunction: Wrong Prot.Module AS 1 159 1 0 N CG x x x DD6 general Auxiliary Power Supply AS 1 160 1 0 N CG

x x x DD6 general Malfunction: Prot.Module not parameterized AS 1 170 1 0 N C

x x x DD6 general Malfunction: Prot.Module not calibrated AS 1 171 1 0 N C

x x x DD6 general Malfunction: Checksum Error AS 1 172 1 0 N C x x x DD6 general Malfunction: Data Access Fault AS 1 173 1 0 N C

x x x DD6 general Malfunction: Data Access Time-out AS 1 174 1 0 N C

x x x DD6 general Malfunction: Reset by Watchdog AS 1 175 1 0 N C x x x Current annunciation IL>ann enabled PS 50 11 1 0 Y CG x x x Current annunciation IL>ann blocked AS 50 12 1 0 Y CG x x x Current annunciation I1>ann AS 50 13 1 0 Y CG x x x Current annunciation I2>ann AS 50 14 1 0 Y CG x x x Current annunciation I3>ann AS 50 15 1 0 Y CG x x x Current annunciation IL>ann Time expired GM 50 16 1 0 N C x x x Current annunciation IL>>ann enabled PS 50 21 1 0 Y CG x x x Current annunciation IL>>ann blocked AS 50 22 1 0 Y CG x x x Current annunciation I1>>ann AS 50 23 1 0 Y CG x x x Current annunciation I2>>ann AS 50 24 1 0 Y CG x x x Current annunciation I3>>ann AS 50 25 1 0 Y CG x x x Current annunciation IL>>ann Time expired AS 50 26 1 0 N C

x x x Current annunciation IN>ann enabled PS 50 51 1 0 Y CG x x x Current annunciation IN>ann blocked AS 50 52 1 0 Y CG x x x Current annunciation IN>ann AS 50 53 1 0 Y CG x x x Current annunciation IN>ann Time expired AS 50 54 1 0 N C x x x Earthfault Detection Earthfault Detection enabled PS 51 11 1 0 Y CG x x x Earthfault Detection Earthfault Detection blocked AS 51 12 1 0 Y CG x x x Earthfault Detection Earthfault UNE> AS 51 53 1 0 Y CG x x x Earthfault Detection Earthfault AS 51 57 1 0 Y CG x x x Dist. compatible Earthfault L1 AS 128 48 1 0 Y CG x x x Dist. compatible Earthfault L2 AS 128 49 1 0 Y CG x x x Dist. compatible Earthfault L3 AS 128 50 1 0 Y CG x x Dist. compatible Earthfault forward/Line AS 128 51 1 0 Y CG x x Dist. compatible Earthfault reverse/Bus AS 128 52 1 0 Y CG x x Earthfault Detection Earthfault extern forward AS 51 16 1 0 Y CG x x Earthfault Detection Earthfault extern reverse AS 51 17 1 0 Y CG x x Earthfault Detection Trip by Earthfault AS 51 30 2 0 N C

Appendix 12



x x Earthfault Detection Trip by Earthfault DW 51 30 2 1 N

x x Earthfault Detection Trip by Earthfault Direction forward/Line AS 51 40 2 0 N C

x x Earthfault Detection Trip by Earthfault Direction forward/line DW 51 40 2 1 N

x x Earthfault Detection Trip by Earthfault Detection reverse/Bus AS 51 50 2 0 N C

x x Earthfault Detection Trip by Earthfault Detection reverse/Bus DW 51 50 2 1 N

x x Earthfault Detection tTrip Earthfault expired AS 51 60 2 0 N C x x Earthfault Detection tTrip Earthfault expired DW 51 60 2 1 N x x x Dist. compatible Start L1 AS 128 64 2 0 Y CG x x x Dist. compatible Start L1 DW 128 64 2 1 Y x x x Dist. compatible Start L2 AS 128 65 2 0 Y CG x x x Dist. compatible Start L2 DW 128 65 2 1 Y x x x Dist. compatible Start L3 AS 128 66 2 0 Y CG x x x Dist. compatible Start L3 DW 128 66 2 1 Y x x x Dist. compatible Start N AS 128 67 2 0 Y CG x x x Dist. compatible Start N DW 128 67 2 1 Y

x x x Time overcurrent protection Trip Current I1 FP32 60 3 4 0 N

x x x Time overcurrent protection Trip Current I1 DW 60 3 4 1 N





x x Time overcurrent protection Trip Current IN measured FP32 60 6 4 0 N

x x x Time overcurrent protection Trip Current IN measured DW 60 6 4 1 N

x x Time overcurrent protection

Trip Current IN measured sen-sitive FP32 60 7 4 0 N

x x x Time overcurrent protection

Trip Current IN measured sen-sitive DW 60 7 4 1 N

x x x Time overcurrent protection Trip Current IN calculated FP32 60 8 4 0 N

x x x Time overcurrent protection Trip Current IN calculated DW 60 8 4 1 N

x x x Distance protection Distance stages enabled PS 130 10 1 0 Y CG x x x Distance protection Zone Z1 enabled PS 130 11 1 0 Y CG x x x Distance protection Zone Z1 blocked AS 130 12 1 0 Y CG x x x Distance protection Zone Z1 Start AS 130 13 2 0 Y CG x x x Distance protection Zone Z1 Start DW 130 13 2 1 Y x x x Dist. compatible State Zone Z1 AS 128 78 2 0 N C x x x Dist. compatible State Zone Z1 DW 128 78 2 1 N x x x Distance protection Zone Z1 Time expired AS 130 19 2 0 N C

Appendix 12



x x x Distance protection Zone Z1 Time expired DW 130 19 2 1 N x x x Distance protection Trip by Z1 AS 130 20 2 0 N C x x x Distance protection Trip by Z1 DW 130 20 2 1 N x x x Distance protection Zone Z1x enabled PS 130 31 1 0 Y CG x x x Distance protection Zone Z1x blocked AS 130 32 1 0 Y CG x x x Distance protection Zone Z1x Start AS 130 33 2 0 Y CG x x x Distance protection Zone Z1x Start DW 130 33 2 1 Y x x x Distance protection State Zone Z1x AS 130 34 2 0 N C x x x Distance protection State Zone Z1x DW 130 34 2 1 N x x x Distance protection OverreachSignal 1x PS 130 38 1 0 Y CG x x x Distance protection Zone Z1x Time expired AS 130 39 2 0 N C x x x Distance protection Zone Z1x Time expired DW 130 39 2 1 N x x x Distance protection Trip by Z1x AS 130 40 2 0 N C x x x Distance protection Trip by Z1x DW 130 40 2 1 N x x x Distance protection Zone Z2 enabled PS 130 51 1 0 Y CG x x x Distance protection Zone Z2 blocked AS 130 52 1 0 Y CG x x x Distance protection Zone Z2 Start AS 130 53 2 0 Y CG x x x Distance protection Zone Z2 Start DW 130 53 2 1 Y x x x Dist. compatible State Zone Z2 AS 128 79 2 0 N C x x x Dist. compatible State Zone Z2 DW 128 79 2 1 N x x x Distance protection Zone Z2 Time expired AS 130 59 2 0 N C x x x Distance protection Zone Z2 Time expired DW 130 59 2 1 N x x x Distance protection Trip by Z2 AS 130 60 2 0 N C x x x Distance protection Trip by Z2 DW 130 60 2 1 N x x x Distance protection Zone Z3 enabled PS 130 71 1 0 Y CG x x x Distance protection Zone Z3 blocked AS 130 72 1 0 Y CG x x x Distance protection Zone Z3 Start AS 130 73 2 0 Y CG x x x Distance protection Zone Z3 Start DW 130 73 2 1 Y x x x Dist. compatible State Zone Z3 AS 128 80 2 0 N C x x x Dist. compatible State Zone Z3 DW 128 80 2 1 N x x x Distance protection Zone Z3 Time expired AS 130 79 2 0 N C x x x Distance protection Zone Z3 Time expired DW 130 79 2 1 N x x x Distance protection Trip by Z3 AS 130 80 2 0 N C x x x Distance protection Trip by Z3 DW 130 80 2 1 N x x x Distance protection Zone Z4 enabled PS 130 91 1 0 Y CG x x x Distance protection Zone Z4 blocked AS 130 92 1 0 Y CG x x x Distance protection Zone Z4 Start AS 130 93 2 0 Y CG x x x Distance protection Zone Z4 Start DW 130 93 2 1 Y x x x Dist. compatible State Zone Z4 AS 128 81 2 0 N C x x x Dist. compatible State Zone Z4 DW 128 81 2 1 N x x x Distance protection Zone Z4 Time expired AS 130 99 2 0 N C x x x Distance protection Zone Z4 Time expired DW 130 99 2 1 N x x x Distance protection Trip by Z4 AS 130 100 2 0 N C

Appendix 12



x x x Distance protection Trip by Z4 DW 130 100 2 1 N

x x x Distance protection Zone t5 enabled PS 130 111 1 0 Y CG x x x Distance protection Zone t5 blocked AS 130 112 1 0 Y CG x x x Dist. compatible State Zone t5 AS 128 82 2 0 N C x x x Dist. compatible State Zone t5 DW 128 82 2 1 N x x x Distance protection Zone t5 Time expired AS 130 119 2 0 N C x x x Distance protection Zone t5 time expired DW 130 119 2 1 N x x x Distance protection Trip by t5 AS 130 120 2 0 N C x x x Distance protection Trip by t5 DW 130 120 2 1 N

x x x Distance protection Zone t6 enabled PS 130 131 1 0 Y CG x x x Distance protection Zone t6 blocked AS 130 132 1 0 Y CG x x x Dist. compatible State Zone t6 AS 128 83 2 0 N C x x x Dist. compatible State Zone t6 DW 128 83 2 1 N x x x Distance protection Zone t6 Time expired AS 130 139 2 0 N C x x x Distance protection Zone t6 Time expired DW 130 139 2 1 N x x x Distance protection Trip by t6 AS 130 140 2 0 N C x x x Distance protection Trip by t6 DW 130 140 2 1 N x x x Distance protection EarthFaultCriteria IE> enabled PS 130 201 1 0 Y CG

x x x Distance protection EarthFaultCriteria UNE> en-abled AS 130 202 1 0 Y CG

x x x Distance protection EarthFaultCriteria IE> blocked AS 130 203 1 0 Y CG

x x x Distance protection EarthFaultCriteria UNE> blocked AS 130 204 1 0 Y CG

x x x Distance protection EarthFaultCriteria IE> Start AS 130 206 1 0 Y CG x x x Distance protection EarhtFaultCriteria UNE> Start AS 130 207 1 0 Y CG x x x Distance protection EarthFaultCriteria satisfied AS 130 208 1 0 Y CG x x x Dist (U-) I Start (U-) I Start enabled PS 62 11 1 0 Y CG x x x Dist (U-) I Start (U-) I Start blocked AS 62 12 1 0 Y CG x x x Dist (U-) I Start (U-) I Start L1 AS 62 13 2 0 Y CG x x x Dist (U-) I Start (U-) I Start L1 DW 62 13 2 1 Y x x x Dist (U-) I Start (U-) I Start L2 AS 62 14 2 0 Y CG x x x Dist (U-) I Start (U-) I Start L2 DW 62 14 2 1 Y x x x Dist (U-) I Start (U-) I Start L3 AS 62 15 2 0 Y CG x x x Dist (U-) I Start (U-) I Start L3 DW 62 15 2 1 Y x x x Dist (U-) I Start (U-) I Start general AS 62 18 2 0 Y CG x x x Dist (U-) I Start (U-) I Star general DW 62 18 2 1 Y

x x x Z< Start Z< Start enabled PS 63 11 1 0 Y CG x x x Z< Start Z< Start blocked AS 63 12 1 0 Y CG x x x Z< Start Z< Start L1E AS 63 13 2 0 Y CG x x x Z< Start Z< Start L1E DW 63 13 2 1 Y x x x Z< Start Z< Start L2E AS 63 14 2 0 Y CG x x x Z< Start Z< Start L2E DW 63 14 2 1 Y

Appendix 12



x x x Z< Start Z< Start L3E AS 63 15 2 0 Y CG x x x Z< Start Z< Start L3E DW 63 15 2 1 Y x x x Z< Start Z< Start L12 AS 63 16 2 0 Y CG x x x Z< Start Z< Start L12 DW 63 16 2 1 Y x x x Z< Start Z< Start L23 AS 63 17 2 0 Y CG x x x Z< Start Z< Start L23 DW 63 17 2 1 Y x x x Z< Start Z< Start L31 AS 63 18 2 0 Y CG x x x Z< Start Z< Start L31 DW 63 18 2 1 Y x x x Z< Start Z< Start general AS 63 19 2 0 Y CG x x x Z< Start Z< Start general DW 63 19 2 1 Y

x x x Time overcurrent protection IL> enabled PS 60 11 1 0 Y CG

x x x Time overcurrent protection IL> blocked AS 60 101 1 0 Y CG

x x x Time overcurrent protection I1> Start AS 60 43 1 0 Y CG



x x x Time overcurrent protection I Start general AS 60 96 2 0 Y CG

x x x Time overcurrent protection I Start general DW 60 96 2 1 Y

x x x Time overcurrent protection IL> time expired AS 60 57 1 0 N C

x x x Dist. compatible Trip by IL> AS 128 90 2 0 N C x x x Dist. compatible Trip by IL> DW 128 90 2 1 N

x x x Time overcurrent protection IL>> enabled PS 60 12 1 0 Y CG

x x x Time overcurrent protection IL>> blocked AS 60 102 1 0 Y CG

x x x Time overcurrent protection I1>> Start AS 60 39 1 0 Y CG



x x x Time overcurrent protection IL>> Time expired AS 60 55 1 0 N C

x x x Dist. compatible Trip by IL>> AS 128 91 2 0 N C x x x Dist. compatible Trip by IL>> DW 128 91 2 1 N

x x x Time overcurrent protection IL>>> enabled PS 60 13 1 0 Y CG

x x x Time overcurrent protection IL>>> blocked AS 60 103 1 0 Y CG

x x x Time overcurrent protection I1>>> Start AS 60 35 1 0 Y CG

Appendix 12




x x x Time overcurrent protection IL>>> Time expired AS 60 53 1 0 N C

x x x Time overcurrent protection Trip by IL>>> AS 60 80 2 0 N C

x x x Time overcurrent protection Trip by IL>>> DW 60 80 2 1 N

x x x Time overcurrent protection IL>>>> enabled PS 60 14 1 0 Y CG

x x x Time overcurrent protection IL>>>> blocked AS 60 104 1 0 Y CG

x x x Time overcurrent protection I1>>>> Start AS 60 31 1 0 Y CG



x x x Time overcurrent protection IL>>>> Time expired AS 60 51 1 0 N C

x x x Time overcurrent protection Trip by IL>>>> AS 60 81 2 0 N C

x x x Time overcurrent protection Trip by IL>>>> DW 60 81 2 1 N

x x x Time overcurrent protection IN> enabled PS 60 15 1 0 Y CG

x x x Time overcurrent protection IN> blocked AS 60 105 1 0 Y CG

x x x Time overcurrent protection IN> Start AS 60 46 1 0 Y CG

x x x Time overcurrent protection IN> Time expired AS 60 58 1 0 N C

x x x Dist. compatible Trip by IN> AS 128 92 2 0 N C x x x Dist. compatible Trip by IN> DW 128 92 2 1 N

x x x Time overcurrent protection IN>> enabled PS 60 16 1 0 Y CG

x x x Time overcurrent protection IN>> blocked AS 60 106 1 0 Y CG

x x x Time overcurrent protection IN>> Start AS 60 42 1 0 Y CG

x x x Time overcurrent protection IN>> Time expired AS 60 56 1 0 N C

x x x Dist. compatible Trip by IN>> AS 128 93 2 0 N C x x x Dist. compatible Trip by IN>> DW 128 93 2 1 N

x x x Time overcurrent protection IN>>> enabled PS 60 17 1 0 Y CG

x x x Time overcurrent protection IN>>> blocked AS 60 107 1 0 Y CG

x x x Time overcurrent protection IN>>> Start AS 60 38 1 0 Y CG

x x x Time overcurrent IN>>> Time expired AS 60 54 1 0 Y C

Appendix 12



protection

x x x Time overcurrent protection Trip by IN>>> AS 60 86 2 0 N C

x x x Time overcurrent protection Trip by IN>>> DW 60 86 2 1 N

x x x Time overcurrent protection IN>>>> enabled PS 60 18 1 0 Y CG

x x x Time overcurrent protection IN>>>> blocked AS 60 108 1 0 Y CG

x x x Time overcurrent protection IN>>>> Start AS 60 34 1 0 Y CG

x x x Time overcurrent protection IN>>>> Time expired AS 60 52 1 0 N C

x x x Time overcurrent protection Trip by IN>>>> AS 60 87 2 0 N C

x x x Time overcurrent protection Trip by IN>>>> DW 60 87 2 1 N

x x x Time overcurrent protection IN>int enabled PS 60 19 1 0 Y CG

x x x Time overcurrent protection IN>int blocked AS 60 109 1 0 Y CG

x x x Time overcurrent protection IN>int Start AS 60 47 1 0 Y CG

x x x Time overcurrent protection IN>int Time expired AS 60 59 1 0 N C

x x x Time overcurrent protection Trip by IN>int AS 60 88 2 0 N C

x x x Time overcurrent protection Trip by IN>int DW 60 88 2 1 N

x x x Time overcurrent protection IN>int Cycle active PS 60 60 1 0 Y CG

x x x Time overcurrent protection IN>int Reset PS 60 61 1 0 N C

x x x Time overcurrent protection Reset tIN>int PS 60 63 1 0 N C

x x x Time overcurrent protection Reset tIN>int COM 60 63 20 0 N

x x x Time overcurrent protection Inrush Restraint enabled PS 60 131 1 0 Y CG

x x x Time overcurrent protection Inrush Restraint blocked AS 60 132 1 0 Y CG

x x x Time overcurrent protection Inrush Restraint L1 AS 60 133 1 0 Y CG



x x x Time overcurrent protection Inrush Restraint AS 60 136 1 0 Y CG

x x x Direction Decision Phase Direction enabled PS 61 11 1 0 Y CG x x x Direction Decision Phase Direction blocked AS 61 12 1 0 Y CG

Appendix 12



x x x Direction Decision Phase Direction forward/Line AS 61 13 2 0 Y CG x x x Direction Decision Phase Direction forward/Line DW 61 13 2 1 Y x x x Direction Decision Phase Direction reverse/Bus AS 61 14 2 0 Y CG x x x Direction Decision Phase Direction reverse/Bus DW 61 14 2 1 Y x x x Direction Decision Phase Direction by Umem AS 61 15 2 0 N C x x x Direction Decision Phase Direction by Umem DW 61 15 2 1 N

x x x Direction Decision Phase Direction preferred for-ward AS 61 16 2 0 N C

x x x Direction Decision Phase Direction preferred for-ward DW 61 16 2 1 N

x x x Direction Decision 3phase U < Umem min PS 61 18 1 0 Y CG x x x Direction Decision Phase Direction restored AS 61 21 2 0 N C x x x Direction Decision Phase Direction restored DW 61 21 2 1 N x x x Direction Decision Groundfault Direction enabled PS 61 31 1 0 Y CG x x x Direction Decision Groundfault Direction blocked AS 61 32 1 0 Y CG

x x x Direction Decision Groundfault Direction for-ward/Line AS 61 33 2 0 Y CG

x x x Direction Decision Groundfault Direction for-ward/Line DW 61 33 2 1 Y

x x x Direction Decision Groundfault Direction re-verse/Bus AS 61 34 2 0 Y CG

x x x Direction Decision Groundfault Direction re-verse/Bus DW 61 34 2 1 Y

x x x Direction Decision Groundfault Direction detect-able AS 61 35 2 0 Y CG

x x x Direction Decision Groundfault Direction detect-able DW 61 35 2 1 Y

x x x Dist. compatible Fault forward/Line AS 128 74 2 0 N C x x x Dist. compatible Fault forward/Line DW 128 74 2 1 N x x x Dist. compatible Fault reverse/Bus AS 128 75 2 0 N C x x x Dist. compatible Fault reverse/Bus DW 128 75 2 1 N

x x x Negative sequence current Ineg>(>) Start general GM 70 67 2 0 Y CG

x x x Negative sequence current Ineg>(>) Start general DW 70 67 2 1 Y

x x x Negative sequence current Trip Current Ineg FP32 70 3 4 0 N

x x x Negative sequence current Trip Current Ineg DW 70 3 4 1 N

x x x Negative sequence current Ineg> enabled PS 70 61 1 0 Y CG

x x x Negative sequence current Ineg> blocked AS 70 62 1 0 Y CG

x x x Negative sequence current Ineg> Start AS 70 63 2 0 Y CG

x x x Negative sequence current Ineg> Start DW 70 63 2 1 Y

x x x Negative sequence current Ineg> Time expired AS 70 69 2 0 N C

x x x Negative sequence current Ineg> Time expired DW 70 69 2 1 N

Appendix 12



x x x Negative sequence current Trip by Ineg> AS 70 70 2 0 N C

x x x Negative sequence current Trip by Ineg> DW 70 70 2 1 N

x x x Negative sequence current Ineg>> enabled PS 70 81 1 0 Y CG

x x x Negative sequence current Ineg>> blocked AS 70 82 1 0 Y CG

x x x Negative sequence current Ineg>> Start AS 70 83 2 0 Y CG

x x x Negative sequence current Ineg>> Start DW 70 83 2 1 Y

x x x Negative sequence current Ineg>> Time expired AS 70 89 2 0 N C

x x x Negative sequence current Ineg>> Time expired DW 70 89 2 1 N

x x x Negative sequence current Trip by Ineg>> AS 70 90 2 0 N C

x x x Negative sequence current Trip by Ineg>> DW 70 90 2 1 N

x x x Frequency protection Trip Frequency FP32 71 3 4 0 N x x x Frequency protection Trip Frequency DW 71 3 4 1 N x x x Frequency protection f1>< enabled PS 71 21 1 0 Y CG x x x Frequency protection f1>< blocked AS 71 22 1 0 Y CG x x x Frequency protection f1>< Start AS 71 23 2 0 Y CG x x x Frequency protection f1>< Start DW 71 23 2 1 Y x x x Frequency protection f1>< Time expired AS 71 29 2 0 N C x x x Frequency protection f1>< Time expired DW 71 29 2 1 N x x x Frequency protection Trip by f1>< AS 71 30 2 0 N C x x x Frequency protection Trip by f1>< DW 71 30 2 1 N x x x Frequency protection f2>< enabled PS 71 41 1 0 Y CG x x x Frequency protection f2>< blocked AS 71 42 1 0 Y CG x x x Frequency protection f2>< Start AS 71 43 2 0 Y CG x x x Frequency protection f2>< Start DW 71 43 2 1 Y x x x Frequency protection f2>< Time expired AS 71 49 2 0 N C x x x Frequency protection f2>< Time expired DW 71 49 2 1 N x x x Frequency protection Trip by f2>< AS 71 50 2 0 N C x x x Frequency protection Trip by f2>< DW 71 50 2 1 N x x x Frequency protection f3>< enabled PS 71 61 1 0 Y CG x x x Frequency protection f3>< blocked AS 71 62 1 0 Y CG x x x Frequency protection f3>< Start AS 71 63 2 0 Y CG x x x Frequency protection f3>< Start DW 71 63 2 1 Y x x x Frequency protection f3>< Time expired GM 71 69 2 0 N C x x x Frequency protection f3>< Time expired DW 71 69 2 1 N x x x Frequency protection Trip by f3>< AS 71 70 2 0 N C x x x Frequency protection Trip by f3>< DW 71 70 2 1 N

Appendix 12



x x x Frequency protection f4>< enabled PS 71 81 1 0 Y CG x x x Frequency protection f4>< blocked AS 71 82 1 0 Y CG x x x Frequency protection f4>< Start AS 71 83 2 0 Y CG x x x Frequency protection f4>< Start DW 71 83 2 1 Y x x x Frequency protection f4>< Time expired AS 71 89 2 0 N C x x x Frequency protection f4>< Time expired DW 71 89 2 1 N x x x Frequency protection Trip by f4>< AS 71 90 2 0 N C x x x Frequency protection Trip by f4>< DW 71 90 2 1 N x x x Power protection Trip Power P FP32 73 3 4 0 N x x x Power protection Trip Power P DW 73 3 4 1 N x x x Power protection Trip Power Q FP32 73 4 4 0 N x x x Power protection Trip Power Q DW 73 4 4 1 N x x x Power protection P> enabled PS 73 21 1 0 Y CG x x x Power protection P> blocked AS 73 22 1 0 Y CG x x x Power protection P> Start AS 73 23 2 0 Y CG x x x Power protection P> Start DW 73 23 2 1 Y x x x Power protection P> Time expired AS 73 29 2 0 N C x x x Power protection P> Time expired DW 73 29 2 1 N x x x Power protection Trip by P> AS 73 30 2 0 N C x x x Power protection Trip by P> DW 73 30 2 1 N x x x Power protection P>> enabled PS 73 41 1 0 Y CG x x x Power protection P>> blocked AS 73 42 1 0 Y CG x x x Power protection P>> Start AS 73 43 2 0 Y CG x x x Power protection P>> Start DW 73 43 2 1 Y x x x Power protection P>> Time expired AS 73 49 2 0 N C x x x Power protection P>> Time expired DW 73 49 2 1 N x x x Power protection Trip by P>> AS 73 50 2 0 N C x x x Power protection Trip by P>> DW 73 50 2 1 N x x x Power protection Q> enabled PS 73 61 1 0 Y CG x x x Power protection Q> blocked AS 73 62 1 0 Y CG x x x Power protection Q> Start AS 73 63 2 0 Y CG x x x Power protection Q> Start DW 73 63 2 1 Y x x x Power protection Q> Time expired AS 73 69 2 0 N C x x x Power protection Q> Time expired DW 73 69 2 1 N x x x Power protection Trip by Q> AS 73 70 2 0 N C x x x Power protection Trip by Q> DW 73 70 2 1 N x x x Power protection Q>> enabled PS 73 81 1 0 Y CG x x x Power protection Q>> blocked AS 73 82 1 0 Y CG x x x Power protection Q>> Start AS 73 83 2 0 Y CG x x x Power protection Q>> Start DW 73 83 2 1 Y x x x Power protection Q>> Time expired AS 73 89 2 0 N C x x x Power protection Q>> Time expired DW 73 89 2 1 N

Appendix 12



x x x Power protection Trip by Q>> AS 73 90 2 0 N C x x x Power protection Trip by Q>> DW 73 90 2 1 N x x x Voltage protection Trip Voltage U1E FP32 74 3 4 0 N x x x Voltage protection Trip Voltage U1E DW 74 3 4 1 N x x x Voltage protection Trip Voltage U2E FP32 74 4 4 0 N x x x Voltage protection Trip Voltage U2E DW 74 4 4 1 N x x x Voltage protection Trip Voltage U3E FP32 74 5 4 0 N x x x Voltage protection Trip Voltage U3E DW 74 5 4 1 N x x x Voltage protection Trip Voltage U12 FP32 74 6 4 0 N x x x Voltage protection Trip Voltage U12 DW 74 6 4 1 N x x x Voltage protection Trip Voltage U23 FP32 74 7 4 0 N x x x Voltage protection Trip Voltage U23 DW 74 7 4 1 N x x x Voltage protection Trip Voltage U31 FP32 74 8 4 0 N x x x Voltage protection Trip Voltage U31 DW 74 8 4 1 N x x x Voltage protection Trip Voltage UNE FP32 74 9 4 0 N x x x Voltage protection Trip Voltage UNE DW 74 9 4 1 N x x x Voltage protection U< enabled PS 74 21 1 0 Y CG x x x Voltage protection U< blocked AS 74 22 1 0 Y CG x x x Voltage protection U1E< Start AS 74 23 2 0 Y CG x x x Voltage protection U1E< Start DW 74 23 2 1 Y x x x Voltage protection U2E< Start AS 74 24 2 0 Y CG x x x Voltage protection U2E< Start DW 74 24 2 1 Y x x x Voltage protection U3E< Start AS 74 25 2 0 Y CG x x x Voltage protection U3E< Start DW 74 25 2 1 Y x x x Voltage protection U12< Start AS 74 26 2 0 Y CG x x x Voltage protection U12< Start DW 74 26 2 1 Y x x x Voltage protection U23< Start AS 74 27 2 0 Y CG x x x Voltage protection U23< Start DW 74 27 2 1 Y x x x Voltage protection U31< Start AS 74 28 2 0 Y CG x x x Voltage protection U31< Start DW 74 28 2 1 Y x x x Voltage protection U< Time expired AS 74 29 2 0 N C x x x Voltage protection U< Time expired DW 74 29 2 1 N x x x Voltage protection Trip by U< AS 74 30 2 0 N C x x x Voltage protection Trip by U< DW 74 30 2 1 N x x x Voltage protection U<< enabled PS 74 41 1 0 Y CG x x x Voltage protection U<< blocked AS 74 42 1 0 Y CG x x x Voltage protection U1E<< Start AS 74 43 2 0 Y CG x x x Voltage protection U1E<< Start DW 74 43 2 1 Y x x x Voltage protection U2E<< Start AS 74 44 2 0 Y CG x x x Voltage protection U2E<< Start DW 74 44 2 1 Y x x x Voltage protection U3E<< Start AS 74 45 2 0 Y CG x x x Voltage protection U3E<< Start DW 74 45 2 1 Y x x x Voltage protection U12<< Start AS 74 46 2 0 Y CG x x x Voltage protection U12<< Start DW 74 46 2 1 Y

Appendix 12



x x x Voltage protection U23<< Start AS 74 47 2 0 Y CG x x x Voltage protection U23<< Start DW 74 47 2 1 Y x x x Voltage protection U31<< Start AS 74 48 2 0 Y CG x x x Voltage protection U31<< Start DW 74 48 2 1 Y x x x Voltage protection U<< Time expired AS 74 49 2 0 N C x x x Voltage protection U<< Time expired DW 74 49 2 1 N x x x Voltage protection Trip by U<< AS 74 50 2 0 N C x x x Voltage protection Trip by U<< DW 74 50 2 1 N x x x Voltage protection U> enabled PS 74 61 1 0 Y CG x x x Voltage protection U> blocked AS 74 62 1 0 Y CG x x x Voltage protection U1E> Start AS 74 63 2 0 Y CG x x x Voltage protection U1E> Start DW 74 63 2 1 Y x x x Voltage protection U2E> Start AS 74 64 2 0 Y CG x x x Voltage protection U2E> Start DW 74 64 2 1 Y x x x Voltage protection U3E> Start AS 74 65 2 0 Y CG x x x Voltage protection U3E> Start DW 74 65 2 1 Y x x x Voltage protection U12> Start AS 74 66 2 0 Y CG x x x Voltage protection U12> Start DW 74 66 2 1 Y x x x Voltage protection U23> Start AS 74 67 2 0 Y CG x x x Voltage protection U23> Start DW 74 67 2 1 Y x x x Voltage protection U31> Start AS 74 68 2 0 Y CG x x x Voltage protection U31> Start DW 74 68 2 1 Y x x x Voltage protection U> Time expired AS 74 69 2 0 N C x x x Voltage protection U> Time expired DW 74 69 2 1 N x x x Voltage protection Trip by U> AS 74 70 2 0 N C x x x Voltage protection Trip by U> DW 74 70 2 1 N x x x Voltage protection U>> enabled PS 74 81 1 0 Y CG x x x Voltage protection U>> blocked AS 74 82 1 0 Y CG x x x Voltage protection U1E>> Start AS 74 83 2 0 Y CG x x x Voltage protection U1E>> Start DW 74 83 2 1 Y x x x Voltage protection U2E>> Start AS 74 84 2 0 Y CG x x x Voltage protection U2E>> Start DW 74 84 2 1 Y x x x Voltage protection U3E>> Start AS 74 85 2 0 Y CG x x x Voltage protection U3E>> Start DW 74 85 2 1 Y x x x Voltage protection U12>> Start AS 74 86 2 0 Y CG x x x Voltage protection U12>> Start DW 74 86 2 1 Y x x x Voltage protection U23>> Start AS 74 87 2 0 Y CG x x x Voltage protection U23>> Start DW 74 87 2 1 Y x x x Voltage protection U31>> Start AS 74 88 2 0 Y CG x x x Voltage protection U31>> Start DW 74 88 2 1 Y x x x Voltage protection U>> Time expired AS 74 89 2 0 N C x x x Voltage protection U>> Time expired DW 74 89 2 1 N x x x Voltage protection Trip by U>> AS 74 90 2 0 N C x x x Voltage protection Trip by U>> DW 74 90 2 1 N

Appendix 12



x x x Voltage protection UNE> enabled PS 74 101 1 0 Y CG x x x Voltage protection UNE> blocked AS 74 102 1 0 Y CG x x x Voltage protection UNE> Start AS 74 103 2 0 Y CG x x x Voltage protection UNE> Start DW 74 103 2 1 Y x x x Voltage protection UNE> Time expired AS 74 109 2 0 N C x x x Voltage protection UNE> Time expired DW 74 109 2 1 N x x x Voltage protection Trip by UNE> AS 74 110 2 1 N x x x Voltage protection Trip by UNE> DW 74 110 2 1 N x x x Voltage protection UNE>> enabled PS 74 121 1 0 Y CG x x x Voltage protection UNE>> blocked AS 74 122 1 0 Y CG x x x Voltage protection UNE>> Start AS 74 123 2 0 Y CG x x x Voltage protection UNE>> Start DW 74 123 2 1 Y x x x Voltage protection UNE>> Time expired AS 74 129 2 0 N C x x x Voltage protection UNE>> Time expired DW 74 129 2 1 N x x x Voltage protection Trip by UNE>> AS 74 130 2 0 N C x x x Voltage protection Trip by UNE>> DW 74 130 2 1 N x x x Inputs/Outputs CB closed manually PS 75 50 1 0 N C x x x Inputs/Outputs CB Position closed PS 75 51 1 0 Y CG x x x Inputs/Outputs CB Position opened PS 75 52 1 0 Y CG x Synchrocheck Synchrocheck enabled PS 131 11 1 0 Y CG x Synchrocheck Synchrocheck blocked AS 131 12 1 0 Y CG x Synchrocheck Synchronizing runs PS 131 13 1 0 Y CG x Synchrocheck Udiff > Udiffmax PS 131 14 1 0 Y CG x Synchrocheck fdiff > fdiffmax PS 131 15 1 0 Y CG x Synchrocheck phidiff > phidiffmax PS 131 16 1 0 Y CG x Synchrocheck US1 out of Range PS 131 17 1 0 Y CG x Synchrocheck US2 out of Range PS 131 18 1 0 Y CG x Synchrocheck Sync Measuring runs PS 131 21 1 0 Y CG

x Synchrocheck Synchronizing Conditions passed PS 131 22 1 0 Y CG

x Synchrocheck Synchronizing Time expired PS 131 28 1 0 Y CG x Synchrocheck Check Synchronism Time expired PS 131 29 1 0 N C x Synchrocheck Udiff < Udiffmax PS 131 34 1 0 Y CG x Synchrocheck fdiff < fdiffmax PS 131 35 1 0 Y CG x Synchrocheck phidiff < phidiffmax PS 131 36 1 0 Y CG x Synchrocheck US1 in Range PS 131 37 1 0 Y CG x Synchrocheck US2 in Range PS 131 38 1 0 Y CG x Synchrocheck Status US1 Dead / US2 Dead PS 131 51 1 0 Y CG x Synchrocheck Status US1 Live / US2 Dead PS 131 52 1 0 Y CG x Synchrocheck Status US1 Dead / US2 Live PS 131 53 1 0 Y CG x Synchrocheck US2 dead 3~ external PS 131 56 1 0 Y CG x Synchrocheck US2 live 3~ external PS 131 57 1 0 Y CG x Synchrocheck Bypassing US1/US2 active PS 131 58 1 0 Y CG x Synchrocheck Voltage Checking US1/US2 PS 131 59 1 0 Y CG

Appendix 12



passed

x Synchrocheck Malfunction Synchrocheck AS 131 71 1 0 Y CG x Synchrocheck External Bypassing PS 131 78 1 0 Y CG x Synchrocheck CB Inherent Time expired PS 131 99 1 0 N C x Synchrocheck CB Close Request by Control PS 131 92 1 0 N C x Synchrocheck CB Close Request by Control COM 131 92 20 0 N x Synchrocheck Sync Abort by Control PS 131 94 1 0 N C x Synchrocheck Sync Abort by Control COM 131 94 20 0 N x Synchrocheck CB Close immediate by Control PS 131 95 1 0 N C x Synchrocheck CB Close immediate by Control COM 131 95 20 0 N x Synchrocheck CB closed by Synchrocheck PS 131 93 1 0 N C x Synchrocheck Meas. Request by Control PS 131 91 1 0 N CG x Synchrocheck Meas. Request by Control COM 131 91 20 0 N x Synchrocheck AR Synchrocheck enabled PS 131 101 1 0 Y CG x Synchrocheck CB Close Request by AR PS 131 102 1 0 N C x x x Measurand Check Measurand Check Umin PS 135 26 1 0 Y CG x x x Measurand Check Measurand Check I enabled PS 135 11 1 0 Y CG x x x Measurand Check Measurand Check I blocked AS 135 12 1 0 Y CG x x x Measurand Check Measurand Check I Asymmetry AS 135 13 1 0 N CG x x x Measurand Check Measurand Check I Sum AS 135 14 1 0 N CG x x x Measurand Check Measurand Check IN without UNE AS 135 44 1 0 N CG x x x Measurand Check Measurand Check U enabled PS 135 21 1 0 Y CG x x x Measurand Check Measurand Check U blocked AS 135 22 1 0 Y CG x x x Measurand Check Measurand Check U Asymmetry AS 135 23 1 0 N CG x x x Measurand Check Measurand Check I without U AS 135 25 1 0 N CG x x x Measurand Check U-No-I Asymmetry AS 135 27 1 0 N CG x x x Measurand Check Measurand Check UNE> enabled PS 135 41 1 0 Y CG x x x Measurand Check Measurand Check UNE> blocked AS 135 42 1 0 Y CG x x x Measurand Check Measurand Check UNE> AS 135 43 1 0 Y CG

x x x Measurand Check Measurand Check UNE without IN / EF AS 135 45 1 0 N CG

x x x Dist. compatible AR enabled PS 128 16 1 0 Y CG x x x Dist. compatible Enable AR COM 128 16 20 0 N x x x Dist. compatible AR locked PS 128 130 1 0 Y CG x x x Auto reclosing AR blocked AS 165 12 1 0 Y CG x x x Auto reclosing AR Cycle running PS 165 13 1 0 Y CG x x x Auto reclosing AR Start by ext. Request PS 165 14 1 0 N C x x x Auto reclosing AR by AR test PS 165 15 1 0 N C x x x Auto reclosing tblockAR CBClose runs PS 165 16 1 0 Y CG x x x Auto reclosing AR Blocking Time started PS 165 19 1 0 N C

Appendix 12



x x x Auto reclosing Trip by AR AS 165 20 2 0 N C x x x Auto reclosing Trip by AR DW 165 20 2 1 N x x x Auto reclosing AR CB ready PS 165 31 1 0 Y CG x x x Dist. compatible CB closed by AR PS 128 128 1 0 N C x x x Dist. compatible CB closed by delayed AR PS 128 129 1 0 N C x x x Auto reclosing AR Cycle aborted (no Close) AS 165 32 1 0 N C x x x Auto reclosing AR CB Trip Signal PS 165 33 1 0 Y CG x x x Auto reclosing CB Trip Signal subsequent PS 165 34 1 0 N C x x x Auto reclosing AR successful (since Version 1.01a) PS 165 40 1 0 N C

x x x CB failure protection CBF Protection enabled PS 166 11 1 0 Y CG x x x CB failure protection CBF Protection blocked AS 166 12 1 0 Y CG x x x Dist. compatible CBF internal AS 128 85 2 0 Y CG x x x Dist. compatible CBF internal DW 128 85 2 1 Y x x x CB failure protection CBF ext. Request PS 166 14 1 0 Y CG x x x CB failure protection CBF external AS 166 15 2 0 N C x x x CB failure protection CBF external DW 166 15 2 1 N x x x CB failure protection Trip by ext. CBF AS 166 20 2 0 N C x x x CB failure protection Trip by ext. CBF DW 166 20 2 1 N

x x x Overload protection Overload Protection enabled PS 167 11 1 0 Y CG

x x x Overload protection Trip by Overload Protection blocked AS 167 12 1 0 Y CG

x x x Overload protection Overload Warn. Level 1 AS 167 13 1 0 Y CG x x x Overload protection Overload Warn. Level 2 AS 167 14 1 0 Y CG

x x x Overload protection Overload Protection disabled by I>Imax AS 167 15 1 0 Y CG

x x x Overload protection Overload Alarm AS 167 17 1 0 Y CG x x x Overload protection Trip by Overload Protection AS 167 20 2 0 N C x x x Overload protection Trip by Overload Protection DW 167 20 2 1 N x x x Overload protection Reset therm. Level PS 167 21 1 0 N C x x x Overload protection Overload Prot. Lockout PS 167 22 1 0 Y CG x x x Overload protection Therm. Level Recording PS 167 51 1 0 Y CG

x x x Fault location Fault Locator enabled PS 168 11 1 0 Y CG x x x Fault location Fault Locator blocked AS 168 12 1 0 Y CG x x x Dist. compatible Fault Location X/Ohm FP32 128 73 4 0 N x x x Dist. compatible Fault Location X/Ohm DW 128 73 4 1 N x x x Fault location Fault Location % of power line FP32 168 3 4 0 N x x x Fault location Fault Location % of power line DW 168 3 4 1 N x x x Fault location Fault Location km FP32 168 4 4 0 N x x x Fault location Fault Location km DW 168 4 4 1 N x x x Fault location Fault Locating not possible AS 168 21 1 0 N C

x x x Pulse shaping Pulse Shaping 1 enabled PS 169 11 1 0 Y CG

x x x Pulse shaping Pulse Shaping 1 I/O Coupling blocked AS 169 12 1 0 Y CG

x x x Pulse shaping Pulse Shaping 1 Output Signal PS 169 13 1 0 Y CG

Appendix 12



x x x Pulse shaping Pulse Shaping 2 enabled PS 169 31 1 0 Y CG

x x x Pulse shaping Pulse Shaping 2 I/O Coupling blocked AS 169 32 1 0 Y CG

x x x Pulse shaping Pulse Shaping 2 Output Signal PS 169 33 1 0 Y CG

x x x Dist. compatible TP enabled PS 128 17 1 0 Y CG x x x Dist. compatible Enable TP COM 128 17 20 0 N x x x DD6 general TP blocked AS 1 102 1 0 Y CG x x x Dist. compatible TP Signal transmitted AS 128 76 2 0 N C x x x Dist. compatible TP Signal transmitted DW 128 76 2 1 N x x x Dist. compatible TP Signal received AS 128 77 2 0 N C x x x Dist. compatible TP Signal received DW 128 77 2 1 N

x x x DD6 general TP H2 Stationbus blocking Sig-nal PS 1 100 1 0 N C

x x x Dist. compatible TP disturbed AS 128 39 1 0 Y CG x x x DD6 general TP Stationbus disturbed AS 1 101 1 0 Y CG x x x DD6 general Trip by TP AS 1 103 2 0 N C x x x DD6 general Trip by TP DW 1 103 2 1 N

x x x Switch on protection SOTF enabled PS 171 1 10 0 Y CG x x x Switch on protection SOTF blocked AS 171 2 1 0 Y CG x x x Switch on protection SOTF Operating Time running PS 171 10 1 0 Y CG

x x x Switch on protection SOTF Distance enabled PS 171 71 1 0 Y CG x x x Switch on protection Start SOTF general AS 171 7 2 0 Y CG x x x Switch on protection Start SOTF general DW 171 7 2 1 Y CG x x x Switch on protection Start SOT Distance AS 171 73 2 0 N C x x x Switch on protection Start SOTF Distance DW 171 73 2 1 N x x x Switch on protection Trip by SOTF Distance AS 171 80 2 0 N C x x x Switch on protection Trip by SOTF Distance DW 171 80 2 1 N

x x x Switch on protection SOTF IL> enabled PS 171 11 1 0 Y CG x x x Switch on protection SOTF I1> Start AS 171 13 2 0 Y CG x x x Switch on protection SOTF I1> Start DW 171 13 2 1 Y x x x Switch on protection SOTF I2> Start AS 171 14 2 0 Y CG x x x Switch on protection SOTF I2> Start DW 171 14 2 1 Y x x x Switch on protection SOTF I3> Start AS 171 15 2 0 Y CG x x x Switch on protection SOTF I3> Start DW 171 15 2 1 Y x x x Switch on protection SOTF IL> Time expired AS 171 19 2 0 N C x x x Switch on protection SOTF IL> Time expired DW 171 19 2 1 N x x x Switch on protection Trip by SOTF IL> AS 171 20 2 0 N C x x x Switch on protection Trip by SOTF IL> DW 171 20 2 1 N

x x x Switch on protection SOTF IN> enabled PS 171 31 1 0 Y CG x x x Switch on protection SOTF IN> Start AS 171 33 2 0 Y CG x x x Switch on protection SOTF IN> Start DW 171 33 2 1 Y x x x Switch on protection SOTF IN> Time expired AS 171 39 2 0 N C x x x Switch on protection SOTF IN> Time expired DW 171 39 2 1 N

Appendix 12



x x x Switch on protection Trip by SOTF IN> AS 171 40 2 0 N C x x x Switch on protection Trip by SOTF IN> DW 171 40 2 1 N

x x x Switch on protection SOTF Ineg> enabled PS 171 51 1 0 Y CG x x x Switch on protection SOTF Ineg> Start AS 171 53 2 0 Y CG x x x Switch on protection SOTF Ineg> Start DW 171 53 2 1 Y x x x Switch on protection SOTF Ineg> Time expired AS 171 59 2 0 N C x x x Switch on protection SOTF Ineg> Time expired DW 171 59 2 1 N x x x Switch on protection Trip by SOTF Ineg> AS 171 60 2 0 N C x x x Switch on protection Trip by SOTF Ineg> DW 171 60 2 1 N

x x x Temperature protec-tion Temperature Prot. Enabled PS 174 11 1 0 Y CG

x x x Temperature protec-tion Temperature Prot. Blocked AS 174 12 1 0 Y CG

x x x Temperature protec-tion Warn. Level 1 Temp. 2 AS 174 13 1 0 Y CG

x x x Temperature protec-tion Warn. Level 2 Temp. 2 AS 174 14 1 0 Y CG

x x x Temperature protec-tion Alarm Temperature 2 AS 174 15 1 0 Y CG

x x x Temperature protec-tion Trip by Temperature 2 AS 174 20 2 0 N C

x x x Temperature protec-tion Trip by Temperature 2 DW 174 20 2 1 N

x x x Temperature protec-tion Warning Temperature 3 AS 174 33 1 0 Y CG












Appendix 12






x x x Temperature protec-tion Trip by Temperature 5 AS 174 100 2 1 N

x x x Reclose Lockout Lockout enabled AS 174 11 1 0 Y CG x x x Reclose Lockout Lockout blocked AS 174 12 1 0 Y CG x x x Reclose Lockout Lockout active AS 174 13 1 0 Y CG x x x Reclose Lockout Lockout Set-Signal DW 174 15 1 0 Y CG

x x x Reclose Lockout Lockout Reset-Signal GM 175 43 1 0 Y CG x x x Reclose Lockout Reset Lockout COM 175 43 20 0 N

Appendix 13


Appendix 13: Assignment of buttons for the protection system menus

Below, please find a description of the functions important for setting and evaluation of the pro-tector only. Regarding the control part or the substation control part, please refer to the operat-ing manual of the SPRECON®-E control panel.

Button Effect

• Enables toggling between control menu, event list of control system and protection relay screen (settings and events of protection).

• In case of extended button actuation (min. 2 s), a help screen appears • To exit the help screen, press the button once more

+

Access to the settings (button actuation < 2 s) • LCD Timeout • LCD Contrast • LCD Lighting • LED Test

C

Exit from menus (extended activation >2 s): LED –Test without reset of the protective LED

Command button for the TRIP command

Command button for the CLOSE command

F1

Configurable button for customized special functions

F2


F3


E

For acceptance of the adjustment and selection of menu items as well

• Moving within the menus • in the event display: scrolling through the main events in the direction of

the past • in case a value is entered, the figure increases • in case of function switches, toggling between the alternatives

• Moving within the menus • in the event display: scrolling through the main events in the direction of

the present • in case a value is entered, the figure decreases • in case of function switches, toggling between the alternatives

• in event presentation: searching and viewing the individual subevents in the direction of the past

• Moving the cursor to the left to the digit to be adjusted or position within a row

• Exiting intermediate menus

• in event presentation: searching and viewing the individual subevents in the direction of the present

• Moving the cursor to the right to the digit to be adjusted or position within a row

• Entry in a menu of the next lower level Remark:

Reset LED Select menu item "Reset LED" in the protection system main menu

Appendix 14


Appendix 14: Abbreviations and explanations

Abbreviation Description Remark (U-)I Voltage-related current start Distance protection start 3~ three-phase AR auto recloser protection module Block. Blockage c comes used in event memory CB Circuit breaker CBF Circuit-breaker failure protection Protection module CharSet Characteristic set Check Supervision, Monitoring Cmd. Command Det Detection DistStart Distance protection start (U-) I-start, Z< start EF Earth fault EFC Earth fault criterion EOTP Emergency overcurrent-time protection back-up protection in case of a disturbed voltage path ERER Directional earth fault protection relay ESCD Earth Short Circuit Direction Back-up protection function in an earthed system FctOn Enabling Fibre Optic Optical fibre FL Fault location Protection module Fuse V transf. Fuse of voltage transformers g goes used in event memory GS General start starts, which can lead to a TRIP command H2 Auxiliary logic 2 Signal comparison method I/O Input/output I2f/1f> Current ratio 2•f/1•f Pickup value of harmonics content for inrush restraint IEint> Starting intermittent earth currents Protection module IL> and IE> Phase current and earth current start Protection module, starting of phases L1, L2, L3 and earth Imag.part Imaginary part In Rated current Ineg> Negative sequence (I2) start Protection module k Pickup factor IB multiplied by k results in tripping limit of the thermal replica L-E or LE Phase-to-earth L-L or LL Phase-to-phase long Long-time interruption pertaining to AR function Malf. Malfunction MCHK Measurand check Protection module OTP Overcurrent-time protection P> and Q> Active and reactive power start Protection module prim primary PROT Protection module Device module PS Power supply module Device module Rec Recording Reclose Reclosing rev.intlock Reverse interlock SC Short-circuit SCD Short-circuit direction decision Protection module SCMP Signal comparison Integral part of protection module teleprotection SDLRE Short Duration Low Resistance Earthing for finding an earth fault in compensated systems (Peterson coils) sec secondary short Short-time interruption pertaining to AR function SOP/SOTF Switch-on protection Protection module t Timer tau Thermal time constant of the operating equipment, for overload protection and start-up

protection TP Teleprotection system Protection module TRIP TRIP command of protection TripCircSv Trip circuit supervision ULE Phase-to-earth-voltage ULL Phase-to-phase voltage Umem Voltage memory for short-circuit direction decision Un Nominal voltage UNE Displacement voltage Equation 5-6 USxD Voltage USx dead Synchronization voltage USx missing USxL Voltage USx live Synchronization voltage USx present vDI Virtual digital input VT Transformer ValIdentAdr identification address of a setting Z< underimpedance starting polygonal, angle-related underimpedance starting

Appendix 15


Appendix 15: Symbols used in circuit diagrams

Dear Reader,

Much as we regret it, errors cannot be ruled out completely despite carefully proofreading. Should you find such errors when reading or applying the User Manual, we would be pleased to hear from you. We also appreciate suggestions and ideas for improvement. Please send your in-formation to:

Sprecher Automation Deutschland GmbH Internet: http://www.sprecher-automation.com Hauptstr. 13 (from 2009-04-01: Möllendorffstr. 47) Telephone: +49 (30) 55762 – 241 10317 Berlin (from 2009-04-01: 10367 Berlin) Fax: +49 (30) 55762 – 240 Germany (from 2009-04: Telefon: +49 (30) 6449241 –70, Fax: +49 (30) 6449241 –99)

9499 Blockage FL digital input of protector with address and designation

9499 Blockage FL digital output of protector with address and designation

logic AND function / AND with negated output and negated input

logic OR function 9498 Blockage FL

H Function switch with address and designation, H=high level, L or open = low level

TP ready internal enable state of a protection module is formed

TP ready internal enable state

internal state

internal state is formed

AR close external command of substation control

Flip-Flops: RS statically / D transfer with L-H edge

GenTRIP

GenTRIP

t = 15 s

adjustable on-delayed timer with address and designation, at expiry of the timer, the start signal must still be present

4911 t1p

& &

1

& 2101 IE> Def. Time

2104 Reset Ratio

IE>

2107 Biasing Fac-

tor

Protection module with settings and enable input

D

R

S R

IE > “2101 IE> Def. Time“ Test of analogue input for exceeding of the setting value DDx 6

17110 tA

17112 tR adjustable timer, off-delayed (at the start of the timer, the input signal is deleted) / timer fixed time

http://www.sprecher-automation.com/en/products.php?parent=109

Appendix 16


Appendix 16: Error report

For an efficient repair, we would like to ask you to submit the following information. Copy this sheet, complete it and enclose it to the faulty device. You can use this sheet also to inform us about a fault which is not clearly due to faulty device hardware. Important: For shipment, use original packaging material, as far as possible. Damage to the de-

vice due to improper packaging is not covered by the manufacturer’s warranty.

General information Date: From: To: Sprecher Automation GmbH Company: Service Contact person: Franckstr. 51 Address: 4018 Linz / Austria Telephone: Fax: +43 732 6809-442 Fax:

Device information Type SPRECON-E-P9x-DDx 6 Order no.: SPRECON-E-P- 9 - D D 6 Serial number: Hardware version: Software version: Structure version: 5601 Auxiliary voltage applied: V DC V AC

Error description The error report should include: • How does the problem manifest itself (display text, event memory text, LED readout)? • If it is known, in which connection has the problem occurred (operator control at device,

tests, substation control mode, power system faults etc.)

Sprecher Automation GmbH Franckstraße 51

4018 Linz Austria

Tel: +43 732 6908-0 Fax: +43 732 6908-321

Ignaz-Köck-Straße 10

1210 Wien Austria

Tel: +43 732 6908-601 Fax: +43 732 6908-5601

[email protected]

www.sprecher-automation.at

Sprecher Automation Deutschland GmbH Möllendorffstraße 47

10367 Berlin Germany

Tel: +49 30 6449241-70 Fax: +49 30 6449241-99

www.sprecher-automation.de

[email protected]

Sprecher Automation Polska Sp z o.o. ul. Laczna 4

58-100 Swidnica Poland

Tel: +48 74 85135-31 Fax: +48 74 85135-32

[email protected]

www.sprecher-automation.pl

Sprecher Automation spol. s r.o. Kopèianska 14

851-01 Bratislava Slovakia

Tel: +421 2 682055-00 Fax: +421 2 682055-10

[email protected]

www.sprecher-automation.sk

www.sprecher-automation.com

© Sprecher Automation 2009 Sprecher Automation, the Sprecher Automation Logo and any alternative version thereof are trademarks and service marks of Sprecher Automation. Other names mentioned, registered or not, are the property of their respective com-panies. Any liability regarding the correctness and completeness of information and/or specifi-cations in the document is excluded. All rights are reserved to alter specifications, make modifications, or to terminate models without prior notice. The specifications of a model may vary from country to country.

sprecon-e-p94-dd 6, -dde 6, -ddey 6 - hf...sprecon-e-p94-dd 6, -dde 6, -ddey 6 one-box solutions...

Documents