Arcteq Generator Commander Instruction Manual
  1. Manuals
  2. Brands
  3. Arcteq Manuals
  4. Protection Device
  5. Generator Commander
  6. Instruction manual

Arcteq Generator Commander Instruction Manual

Hide thumbs
1
2
Table Of Contents
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128
129
130
131
132
133
134
135
136
137
138
139
140
141
142
143
144
145
146
147
148
149
150
151
152
153
154
155
156
157
158
159
160
161
162
163
164
165
166
167
168
169
170
171
172
173
174
175
176
177
178
179
180
181
182
183
184
185
186
187
188
189
190
191
192
193
194
195
196
197
198
199
200
201
202
203
204
205
206
207
208
209
210
211
212
213
214
215
216
217
218
219
220
221
222
223
224
225
226
227
228
229
230
231
232
233
234
235
236
237
238
239
240
241
242
243
244
245
246
247
248
249
250
251
252
253
254
255
256
257
258
259
260
261
262
263
264
265
266
267
268
269
270
271
272
273
274
275
276
277
278
279
280
281
282
283
284
285
286
287
288
289
290
291
292
293
294
295
296
297
298
299
300
301
302
303
304
305
306
307
308
309
310
311
312
313
314
315
316
317
318
319
320
321
322
323
324
325
326
327
328
329
330
331
332
333
334
335
336
337
338
339
340
341
342
343
344
345
346
347
348
349
350
351
352
353
354
355
356
357
358
359
360
361
362
363
364
365
366
367
368
369
370
371
372
373
374
375
376
377
378
379
380
381
382
383
384
385
386
387
388
389
390
391
392
393
394
395
396
397
398
399
400
401
402
403
404
405
406
407
408
409
410
411
412
413
414
415
416
417
418
419
420
421
422
423
424
425
426
427
428
429
430
431
432
433
434
435
436
437
438
439
440
441
442
443
444
445
446
447
448
449
450
451
452
453
454
455
456
457
458
459
460
461
462
463
464
465
466
467
468
469
470
471
472
473
474
475
476
477
478
479
480
481
482
483
484
485
486
487
488
489
490
491
492
493
494
495
496
497
498
499
500
501
502
503
504
505
506
507
508
509
510
511
512
513
514
515
516
517
518
519
520
521
522
523
524
525
526
527
528
529
530
531
532
533
534
535
536
537
538
539
540
541
542
543
544
545
546
547
548
549
550
551
552
553
554
555
556
557
558
559
560
561
Table of Contents

Advertisement

Quick Links

Download this manual
Generator
Commander
Instruction manual

Advertisement

Table of Contents
loading
Need help?

Need help?

Do you have a question about the Generator Commander and is the answer not in the manual?

Questions and answers

Related Manuals for Arcteq Generator Commander

Summary of Contents for Arcteq Generator Commander

  • Page 1 Generator Commander Instruction manual...

  • Page 3: Table Of Contents

    5.4.28 Resistance temperature detectors (RTD) ............... 290 5.4.29 Arc fault protection (IArc>/I0Arc>; 50Arc/50NArc) ..........297 5.4.30 Voltage memory ....................305 5.5 Control functions ....................... 309 5.5.1 Common signals...................... 309 5.5.2 Setting group selection .................... 310 5.5.3 Object control and monitoring.................. 318 © Arcteq Relays Ltd IM00001...
  • Page 4 6.2.2.5 Active control status ................... 454 6.2.3 Remote and local control ..................456 6.2.4 Excitation internal parameters.................. 459 6.2.5 Events recorded by the Generator commander............463 6.2.6 Other control functions .................... 470 6.2.6.1 Reference values ..................470 6.2.6.2 Start and stop functions................470 6.2.6.3 Test mode....................
  • Page 5 10.1.3.4 Milliampere module (mA out & mA in) ............528 10.1.3.5 RTD input module..................529 10.1.3.6 RS-232 & serial fiber communication module..........529 10.1.3.7 Double LC 100 Mbps Ethernet communication module ......529 10.1.3.8 Double ST 100 Mbps Ethernet communication module ......530 © Arcteq Relays Ltd IM00001...
  • Page 6 10.3 Tests and environmental ....................554 11 Or 11 Ordering inf dering informa ormation tion ............................................557 12 Contact and r 12 Contact and re e f f er erence inf ence informa ormation tion....................................559 © Arcteq Relays Ltd IM00001...
  • Page 7 Nothing contained in this document shall increase the liability or extend the warranty obligations of the manufacturer Arcteq Relays Ltd. The manufacturer expressly disclaims any and all liability for any damages and/or losses caused due to a failure to comply with the instructions contained herein or caused by persons who do not fulfil the aforementioned requirements.
  • Page 8 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Copyright Copyright © Arcteq Relays Ltd. 2022. All rights reserved. © Arcteq Relays Ltd IM00001...

  • Page 9: Document Inf

    - Order codes revised. - Added double ST 100 Mbps Ethernet communication module and Double RJ45 10/100 Mbps Ethernet communication module descriptions Revision 2.02 Date 7.7.2020 Changes - A number of image descriptions improved. Revision 2.03 Date 27.8.2020 © Arcteq Relays Ltd IM00001...
  • Page 10 - Added sample rate to voltage and current measurement tech data. - Fixed overvoltage, undervoltage, neutral overvoltage and sequence voltage stage misspelled IDMT curve formula. - "Functions of the Generator Commander" and "Excitation functions" images updated. - Note added to power protection tech data. Revision 2.04...
  • Page 11 - Added user description parameter descriptions for digital inputs, digital outputs, logical inputs, logical outputs and GOOSE inputs. - Arc point sensor HSO1 and HSO2 position fixed. - Added spare part codes and compatibilities to option cards. Revision 2.07 Date 7.7.2022 © Arcteq Relays Ltd IM00001...

  • Page 12: Version 1 Revision Notes

    Changes Added HMI display technical data 1.3 Version 1 revision notes Table. 1.3 - 3. Version 1 revision notes Revision 1.00 Date 16.3.2017 Changes The first revision for Generator Commander manual Revision 1.01 Date 5.1.2018 © Arcteq Relays Ltd IM00001...
  • Page 13 Power factor protection description added Over/Under/Reverse protection descriptions removed. Replaced with power protection function description. Order code revised Revision 1.02 Date 14.8.2018 Added mA output option card description and ordercode Changes Added HMI display technical data © Arcteq Relays Ltd IM00001...

  • Page 14: Abbr Bbre E Via Viations Tions

    FFT – Fast Fourier transform FTP – File Transfer Protocol GI – General interrogation HMI – Human-machine interface HR – Holding register HV – High voltage HW – Hardware IDMT– Inverse definite minimum time IED – Intelligent electronic device © Arcteq Relays Ltd IM00001...
  • Page 15 SG – Setting group SOTF – Switch-on-to-fault SW – Software THD – Total harmonic distortion TRMS – True root mean square VT – Voltage transformer VTM – Voltage transformer module VTS – Voltage transformer supervision © Arcteq Relays Ltd IM00001...

  • Page 16: General

    Version: 2.07 3 General The Generator Commander is a new innovation that combines generator protection and control into a single unit. Compared to traditional systems with several separate units and software, the Generator Commander takes less space and saves considerable hours of engineering time. Its operation is smooth as there is only one interface to the system.

  • Page 17: Ied User Interface Erface

    (hardware or software) error that affects the operation of the unit. The activation of the yellow "Start" LED and the red "Trip" LED are based on the setting the user has put in place in the software. © Arcteq Relays Ltd IM00001...

  • Page 18: Configuring User Levels And Their Passwords

    The different user levels and their star indicators are as follows (also, see the image below for the HMI view): • Super user (***) • Configurator (**) • Operator (*) • User ( - ) © Arcteq Relays Ltd IM00001...
  • Page 19 In AQ-250 frame units unlocking and locking a user level generates a time-stamped event to the event log. NOTE! Any user level with a password automatically locks itself after half an hour (30 minutes) of inactivity. © Arcteq Relays Ltd IM00001...

  • Page 20: Functions Unctions

    ROCOF (1) df/dt>/< (1…8) Rate-of-change of frequency I2> Negative sequence overcurrent/ I2>> CUB (4) 46/46R/46L phase current reversal/ I2>>> current unbalance protection I2>>>> U1/U2>/< U1/U2>>/<< VUB (4) 47/27P/59PN Sequence voltage protection U1/U2>>>/<<< U1/U2>>>>/<<<< © Arcteq Relays Ltd IM00001...
  • Page 21 ∆φ ΔV/Δa/Δf Synchrocheck GSYN ΔV/Δa/Δf Synchronizer (optional) Table. 5.1 - 6. Monitoring functions of AQ-G257. Name ANSI Description CTS (2) Current transformer supervision Voltage transformer supervision Disturbance recorder Total harmonic distortion Circuit breaker wear monitor © Arcteq Relays Ltd IM00001...

  • Page 22: Measurements

    NOM: The nominal primary current of the protected transformer. The nominal current on the HV side differs from that on the LV side according to the transformer voltage ratio. The nominal current is calculated based on the transformer's MVA and the nominal voltage on each winding. © Arcteq Relays Ltd IM00001...
  • Page 23 CT ratings and the transformer nominal current. Note that S1 is always connected to an odd connector regardless of the CT direction. The CT direction is selected in the settings of the transformer differential protection function. © Arcteq Relays Ltd IM00001...
  • Page 24 TrafoModule → Idx> [87T,87N] → Settings ). This way the direction of the measured currents are checked correctly from the relay's perspective. The following table presents the initial data of the connection as well as the ratings. © Arcteq Relays Ltd IM00001...
  • Page 25 As seen in the image above, relay calculates both the HV side nominal current (669.2 A) and the LV side nominal current (5 888.97 A). The nominal current calculations are done according to the following formulas: The HV and LV side nominal current can also be calculated in per unit values as follows: © Arcteq Relays Ltd IM00001...
  • Page 26 CT ratings and the transformer nominal current. Note that S1 is always connected to an odd connector regardless of the CT direction. The CT direction is selected in the settings of the transformer differential protection function. © Arcteq Relays Ltd IM00001...
  • Page 27 [87T,87N] → Settings ). The difference with the first application is that here the CTs point towards the protected object instead of pointing through it. The following table presents the initial data of the connection as well as the ratings. © Arcteq Relays Ltd IM00001...
  • Page 28 CTs are checked. In Application 2 it is necessary to inject higher amplitudes to the CTs via the secondary injection tool in order to reach the nominal currents. See the example calculation below: © Arcteq Relays Ltd IM00001...
  • Page 29 P/S Table. 5.2.1 - 11. Settings of the Residual I02 CT scaling. Name Unit Range Step Default Description I02 CT 1…25000 0.00001 100 The rated primary current of the current transformer. primary © Arcteq Relays Ltd IM00001...
  • Page 30 Sec") Table. 5.2.1 - 15. Phase current angle measurements. Name Unit Range Step Description Phase angle ILx The phase angle measurement from each of the three phase current ("Pha.angle 0.000…360.000 0.001 inputs. ILx") © Arcteq Relays Ltd IM00001...
  • Page 31 Name Unit Range Step Description Residual current angle The residual current angle measurement from the I01 or 0.000…360.000 0.001 I02 current input. ("Res.curr.angle I0x") Calculated I0 angle 0.000…360.000 0.001 The calculated residual current angle measurement. © Arcteq Relays Ltd IM00001...
  • Page 32 The calculated positive sequence current angle. ("Positive sequence curr.angle") Negative sequence current angle 0.000…360.0 0.001 The calculated negative sequence current angle. ("Negative sequence curr.angle") Zero sequence current angle 0.000…360.0 0.001 The calculated zero sequence current angle. ("Zero sequence curr.angle") © Arcteq Relays Ltd IM00001...

  • Page 33: Voltage Measurement And Scaling

    RI: The primary voltage, i.e. the voltage in the primary circuit which is connected to the primary side of the voltage transformer. SEC: SEC: The secondary voltage, i.e. the voltage which the voltage transformer transforms according to the ratio. This voltage is measured by the protection relay. © Arcteq Relays Ltd IM00001...
  • Page 34 - U4 VT secondary: 100 V - the zero sequence voltage is connected similarly to line-to-neutral voltages (+U0). - in case wiring is incorrect, all polarities can be individually switched by 180 degrees in the relay. © Arcteq Relays Ltd IM00001...
  • Page 35 Protection → Voltage → [protection stage menu] → Settings ). Fault loops are either line-to-line or line-to-neutral according to the "Measured magnitude" setting. As a default, the activation of any one voltage trips the voltage protection stage. Figure. 5.2.2 - 12. Selecting the operating mode. © Arcteq Relays Ltd IM00001...
  • Page 36 In the image below is an example of 2LL+U0+SS, that is, two line-to-line measurements with the zero sequence voltage and voltage from side 2 for Synchrocheck. Since U0 is available, line-to-neutral voltages can be calculated. © Arcteq Relays Ltd IM00001...
  • Page 37 The VT scaling has been set to 20 000 : 100 V. The U4 channel measures the zero sequence voltage which has the same ratio (20 000 : 100 V). © Arcteq Relays Ltd IM00001...
  • Page 38 Table. 5.2.2 - 26. Settings of the VT scaling. Name Range Step Default Description Voltage 0: 3LN+U4 The relay's voltage wiring method. The voltages are scaled according measurement 1: 3LL+U4 3LN+U4 the set voltage measurement mode. mode 2: 2LL+U3+U4 © Arcteq Relays Ltd IM00001...
  • Page 39 VT scaling A relay feedback value; the scaling factor for the primary voltage's factor p.u. Pri per-unit value. VT scaling A relay feedback value; the scaling factor for the secondary voltage's factor p.u. Sec per-unit value. © Arcteq Relays Ltd IM00001...
  • Page 40 The phase angle measurement from each of the four voltage inputs. Table. 5.2.2 - 30. Per-unit sequence voltage measurements. Name Unit Range Step Description Positive sequence The measurement (in p.u.) from the calculated positive sequence voltage × U 0.00…500.0 0.01 voltage. ("Pos.seq.Volt.p.u.") © Arcteq Relays Ltd IM00001...
  • Page 41 Range Step Description System voltage magnitude The primary RMS line-to-line UL12 voltage (measured or calculated). You UL12 0.00…1000000.00 0.01 can also select the row where the unit for this is kV. ("System volt UL12 mag") © Arcteq Relays Ltd IM00001...
  • Page 42 0.00…1000000.00 0.01 displayed only when the "2LL+U3+U4" mode is selected and both U3 and ("System U4 are in use. You can also select the row where the unit for this is kV. volt U4 mag") © Arcteq Relays Ltd IM00001...
  • Page 43 ("Harm Abs.or 1: Absolute absolute values. Perc.") 0: Per unit Defines how the harmonics are displayed: in p.u. values, as primary Harmonics display 1: Primary V voltage values, or as secondary voltage values. 2: Secondary V © Arcteq Relays Ltd IM00001...

  • Page 44: Power And Energy Calculation

    The following equations apply for power calculations with the line-to-neutral mode and the line- to-line voltage mode (with U0 connected and measured): Figure. 5.2.3 - 17. Three-phase power (S) calculation. Figure. 5.2.3 - 18. Three-phase active power (P) calculation. © Arcteq Relays Ltd IM00001...
  • Page 45 (φ) (tangent phi), which is calculated according the following formula: Power factor calculation is done similarly to the Cosine phi calculation but the polarity is defined by the reactive power direction. Therefore, the power factor is calculated with the following formula: © Arcteq Relays Ltd IM00001...
  • Page 46 0: Undefined 1: Q1 Fwd Cap AV VA Quadrant 2: Q2 Rev Ind AV Indicates what the power VA quadrant is at that moment. Undefined 3: Q3 Rev Cap VA 4: Q4 Fwd Ind VA © Arcteq Relays Ltd IM00001...
  • Page 47 Indicates the total number of pulses sent. sent Table. 5.2.3 - 39. DC 1…4 Pulse out settings Name Range Step Default Description None selected DC 1…4 Pulse out OUT1…OUTx The selection of the controlled physical outputs. © Arcteq Relays Ltd IM00001...
  • Page 48 904.00…999 999 995 0.01 The total amount of imported active energy. MWh) 904.00 -999 999 995 Active Energy (P) Export/Import 904.00…999 999 995 0.01 The sum of imported and exported active energy. balance (kWh or MWh) 904.00 © Arcteq Relays Ltd IM00001...
  • Page 49 The apparent energy of the phase while active energy is Apparent Energy (S) while Export (P) Lx 0.01 -1x10 …1x10 exported. The apparent energy of the phase while active energy is Apparent Energy (S) while Import (P) Lx 0.01 -1x10 …1x10 imported. © Arcteq Relays Ltd IM00001...
  • Page 50 L2 Cos 0.77 L3 Cos L3 Cos 0.99 3PH Cos H Cos 0.87 Voltages (line-to-line): Currents: = 100.00 V, 30.00° = 2.5 A, 0.00° = 100.00 V, -90.00° = 2.5 A, -120.00° = 2.5 A, 120.00° © Arcteq Relays Ltd IM00001...

  • Page 51: Frequency Tracking And Scaling

    Measurement sampling can be set to the frequency tracking mode or to the fixed user- defined frequency sampling mode. The benefit of frequency tracking is that the measurements are within a pre-defined accuracy range even when the fundamental frequency of the power system changes. © Arcteq Relays Ltd IM00001...
  • Page 52 FFT calculation always has a whole power cycle in the buffer. The measurement accuracy is further improved by Arcteq's patented calibration algorithms that calibrate the analog channels against eight (8) system frequency points for both magnitude and angle.
  • Page 53 "Start behavior" is set to "First nominal or tracked". Tracked f Displays the rough value of the tracked frequency in Channel 0.000…75.000Hz 0.001Hz - channel A Tracked f Displays the rough value of the tracked frequency in Channel 0.000…75.000Hz 0.001Hz - channel B © Arcteq Relays Ltd IM00001...

  • Page 54: General Menu

    If an external clock time synchronization source is available, the type is Time defined with this parameter. In the internal mode there is no external 0: Internal synchronization source 2: External Timesync source. IRIG-B requires a serial fiber communication option Serial card. 3: IRIG-B © Arcteq Relays Ltd IM00001...
  • Page 55 0: Disabled Enables the measurement recorder tool, further configured in Tools → Measurement recorder 0: Disabled 1: Enabled Misc → Measurement recorder. 0: - Reconfigure mimic 0: - Reloads the mimic to the unit. Reconfigure © Arcteq Relays Ltd IM00001...

  • Page 56: Protection Functions

    5.4.1 General properties of a protection function The following flowchart describes the basic structure of any protection function. The basic structure is composed of analog measurement values being compared to the pick-up values and operating time characteristics. © Arcteq Relays Ltd IM00001...
  • Page 57 Generat t or Commander or Commander Instruction manual Version: 2.07 The protection function is run in a completely digital environment with a protection CPU microprocessor which also processes the analog signals transformed into the digital form. © Arcteq Relays Ltd IM00001...
  • Page 58 Figure. 5.4.1 - 21. Pick up and reset. The pick-up activation of the function is not directly equal to the START signal generation of the function. The START signal is allowed if a blocking condition is not active. © Arcteq Relays Ltd IM00001...
  • Page 59 • Definite time operation (DT): activates the trip signal after a user-defined time delay regardless of the measured current as long as the current is above or below the X value and thus the pick-up element is active (independent time characteristics). © Arcteq Relays Ltd IM00001...
  • Page 60 Selects whether the delay curve series for an IDMT operation follows either IEC or IEEE/ANSI standard defined characteristics. Delay curve 0: IEC 0: IEC series 1: IEEE This setting is active and visible when the "Delay type" parameter is set to "IDMT". © Arcteq Relays Ltd IM00001...
  • Page 61 "Param". Defines the Constant C for IEEE characteristics. This setting is active and visible when the "Delay type" parameter is 0.0000…250.0000 0.0001 0.0200 set to "IDMT" and the "Delay characteristic" parameter is set to "Param". © Arcteq Relays Ltd IM00001...
  • Page 62 = Operating delay (s) t = Operating delay (s) k = Time dial setting k = Time dial setting = Measured maximum current = Measured maximum current = Pick-up setting = Pick-up setting © Arcteq Relays Ltd IM00001...
  • Page 63 1: Yes reset. release time The behavior of the stages with different release time configurations are presented in the figures below. Figure. 5.4.1 - 25. No delayed pick-up release. © Arcteq Relays Ltd IM00001...
  • Page 64 Commander Instruction manual Version: 2.07 Figure. 5.4.1 - 26. Delayed pick-up release, delay counter is reset at signal drop-off. Figure. 5.4.1 - 27. Delayed pick-up release, delay counter value is held during the release time. © Arcteq Relays Ltd IM00001...

  • Page 65: Non-Directional Overcurrent Protection (I>; 50/51)

    The blocking signal and the setting group selection control the operating characteristics of the function during normal operation, i.e. the user or user-defined logic can change function parameters while the function is running. © Arcteq Relays Ltd IM00001...
  • Page 66 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the non-directional overcurrent function. Figure. 5.4.2 - 29. Simplified function block diagram of the I> function. © Arcteq Relays Ltd IM00001...
  • Page 67 1: RMS Defines which available measured magnitude is used by the function. 3: Peak- to-peak 1: Side 1 1: Side Measurement side Defines which current measurement module is used by the function. 2: Side 2 © Arcteq Relays Ltd IM00001...
  • Page 68 When the function has detected a fault and counts down time towards a trip, remaining 0.000...1800.000s 0.005s this displays how much time is left before tripping occurs. to trip meas 0.00...1250.00 0.01 The ratio between the highest measured phase current and the pick-up value. at the moment © Arcteq Relays Ltd IM00001...
  • Page 69 This function supports definite time delay (DT) and inverse definite minimum time delay (IDMT). For detailed information on these delay types please refer to the chapter "General properties of a protection function" and its section "Operating time characteristics for trip and reset". © Arcteq Relays Ltd IM00001...
  • Page 70 NOC1 Phase B Start ON NOC1 Phase B Start OFF NOC1 Phase C Start ON NOC1 Phase C Start OFF NOC1 Phase A Trip ON NOC1 Phase A Trip OFF NOC1 Phase B Trip ON © Arcteq Relays Ltd IM00001...
  • Page 71 NOC3 Phase C Start ON NOC3 Phase C Start OFF NOC3 Phase A Trip ON NOC3 Phase A Trip OFF NOC3 Phase B Trip ON NOC3 Phase B Trip OFF NOC3 Phase C Trip ON © Arcteq Relays Ltd IM00001...

  • Page 72: Non-Directional Earth Fault Protection (I0>; 50N/51N)

    The non-directional earth fault function uses a total of eight (8) separate setting groups which can be selected from one common source. © Arcteq Relays Ltd IM00001...
  • Page 73 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the non-directional earth fault function. Figure. 5.4.3 - 31. Simplified function block diagram of the I0> fucntion. © Arcteq Relays Ltd IM00001...
  • Page 74 Measurement 1: Side Defines which current measurement module is used by the function. side 2: Side 1: I01 2: I02 Input selection 1: I01 Defines which measured residual current is used by the function. I0Calc © Arcteq Relays Ltd IM00001...
  • Page 75 When the function has detected a fault and counts down time towards a trip, this remaining 0.000...1800.000 s displays how much time is left before tripping occurs. to trip meas at the 0.00...1250.00 0.01 The ratio between the measured current and the pick-up value. moment © Arcteq Relays Ltd IM00001...
  • Page 76 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.4.3 - 63. Event messages. Event block name Event names NEF1 Start ON NEF1 Start OFF NEF1 Trip ON NEF1 Trip OFF NEF1 Block ON NEF1 Block OFF © Arcteq Relays Ltd IM00001...

  • Page 77: Directional Overcurrent Protection (Idir>; 67)

    The directional overcurrent function uses a total of eight (8) separate setting groups which can be selected from one common source. © Arcteq Relays Ltd IM00001...
  • Page 78 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the directional overcurrent function. Figure. 5.4.4 - 32. Simplified function block diagram of the Idir> function. © Arcteq Relays Ltd IM00001...
  • Page 79 Set mode of DOC block. Blocked Idir> LN 3: Test 1: On This parameter is visible only when Allow setting of individual LN mode is enabled in mode 4: Test/ General menu. Blocked 5: Off © Arcteq Relays Ltd IM00001...
  • Page 80 Pick-up setting 0.10…40.00×I 0.01×I 1.20×I The pick-up activation of the function is not directly equal to the START signal generation of the function. The START signal is allowed if the blocking condition is not active. © Arcteq Relays Ltd IM00001...
  • Page 81 In a short- circuit the angle comes from impedance calculation. Figure. 5.4.4 - 34. Operation sector area when the sector center has been set to -45 degrees. © Arcteq Relays Ltd IM00001...
  • Page 82 When the function has detected a fault and counts down time towards a trip, remaining -1800.000...1800.00s 0.005s this displays how much time is left before tripping occurs. to trip meas The ratio between the highest measured phase current and the pick-up 0.00...1250.00I 0.01I at the value. moment © Arcteq Relays Ltd IM00001...
  • Page 83 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.4.4 - 70. Event messages. Event block name Event names DOC1 Start ON DOC1 Start OFF DOC1 Trip ON DOC1 Trip OFF DOC1 Block ON © Arcteq Relays Ltd IM00001...
  • Page 84 Measuring live angle OFF DOC3 Using voltmem ON DOC3 Using voltmem OFF DOC4 Start ON DOC4 Start OFF DOC4 Trip ON DOC4 Trip OFF DOC4 Block ON DOC4 Block OFF DOC4 No voltage, Blocking ON © Arcteq Relays Ltd IM00001...

  • Page 85: Directional Earth Fault Protection (I0Dir>; 67N/32N)

    (DT) or for inverse definite minimum time (IDMT); the IDMT operation supports both IEC and ANSI standard time delays as well as custom parameters. The operational logic consists of the following: • input magnitude selection • input magnitude processing • threshold comparator © Arcteq Relays Ltd IM00001...
  • Page 86 Both I and U must be above the squelch limit to be able to detect the angle. The squelch limit for the I current is 0.01 x I and for the U voltage 0.01 x U © Arcteq Relays Ltd IM00001...
  • Page 87 1: Side Defines which current measurement module is used by the function. side 2: Side 2 1: I01 Input 2: I02 1: I01 Defines which measured residual current is used by the function. selection 3: I0Calc © Arcteq Relays Ltd IM00001...
  • Page 88 I0 angle blinder (Petersen coil earthed) -90.0…0.0° 0.1° -90° The pick-up activation of the function is not directly equal to the START signal generation of the function. The START signal is allowed if the blocking condition is not active. © Arcteq Relays Ltd IM00001...
  • Page 89 Each outgoing feeder produces capacitance according to the zero sequence capacitive reactance of the line (ohms per kilometer). It is normal that in cable networks fault currents are higher than in overhead lines. © Arcteq Relays Ltd IM00001...
  • Page 90 In emergency situations a line with an earth fault can be used for a specific time. Figure. 5.4.5 - 38. Angle tracking of I0dir> function (Petersen coil earthed network model). © Arcteq Relays Ltd IM00001...
  • Page 91 This resistance includes the amplitude of the fault current. In undercompensated or overcompensated situations the resistive component does not change during the fault; therefore, selective tripping is ensured even when the network is slightly undercompensated or overcompensated. © Arcteq Relays Ltd IM00001...
  • Page 92 Directly earthed or small impedance network schemes are normal in transmission, distribution and industry. The phase angle setting of the tripping area is adjustable as is the base direction of the area (angle offset). © Arcteq Relays Ltd IM00001...
  • Page 93 CT errors. For all these reasons, Arcteq has developed an improved alternative to these traditional directional earth fault protections.
  • Page 94 No extra parameterization is required compared to the traditional method. The multi- criteria algorithm can be tested with COMTRADE files supplied by Arcteq. The function requires a connection of three-phase currents, residual current and residual voltage to operate correctly.
  • Page 95 If the START function has been activated before the blocking signal, it resets and the release time characteristics are processed similarly to when the pick- up signal is reset. © Arcteq Relays Ltd IM00001...
  • Page 96 I0Sinfi Start OFF DEF1 I0Cosfi Trip ON DEF1 I0Cosfi Trip OFF DEF1 I0Sinfi Trip ON DEF1 I0Sinfi Trip OFF DEF2 Start ON DEF2 Start OFF DEF2 Trip ON DEF2 Trip OFF DEF2 Block ON DEF2 Block OFF © Arcteq Relays Ltd IM00001...
  • Page 97 DEF4 Block OFF DEF4 I0Cosfi Start ON DEF4 I0Cosfi Start OFF DEF4 I0Sinfi Start ON DEF4 I0Sinfi Start OFF DEF4 I0Cosfi Trip ON DEF4 I0Cosfi Trip OFF DEF4 I0Sinfi Trip ON DEF4 I0Sinfi Trip OFF © Arcteq Relays Ltd IM00001...

  • Page 98: Negative Sequence Overcurrent/ Phase Current Reversal/ Current Unbalance Protection (I2>; 46/46R/46L)

    (DT) or inverse definite minimum time (IDMT). The IDMT operation supports both IEC and ANSI standard time delays as well as custom parameters. The operational logic consists of the following: • input magnitude selelction • input magnitude processing © Arcteq Relays Ltd IM00001...
  • Page 99 Time base Positive sequence current magnitude 5 ms Negative sequence current magnitude 5 ms Zero sequence current magnitude 5 ms I1 ANG Positive sequence current angle 5 ms I2 ANG Negative sequence current angle 5 ms © Arcteq Relays Ltd IM00001...
  • Page 100 The relay's Info page displays useful, real-time information on the state of the protection function. It is accessed either through the relay's HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. © Arcteq Relays Ltd IM00001...
  • Page 101 Both IEC and IEEE/ANSI standard characteristics as well as user settable parameters are available for the IDMT operation. Unique to the current unbalance protection is the availability of the “Curve2” delay which follows the formula below: © Arcteq Relays Ltd IM00001...
  • Page 102 OFF for messages in the main event buffer. The function offers four (4) independent stages; the events are segregated for each stage operation. The triggering event of the function (START, TRIP or BLOCKED) is recorded with a time stamp and with process data values. © Arcteq Relays Ltd IM00001...
  • Page 103 Date and time Event Used SG current current current currents remaining Setting dd.mm.yyyy Event Start/Trip Start/Trip Start -200ms I1, I2, IZ mag. 0 ms...1800s group 1...8 hh:mm:ss.mss name -20ms current current current and ang. active © Arcteq Relays Ltd IM00001...

  • Page 104: Harmonic Overcurrent Protection (Ih>; 50H/51H/68H)

    START and TRIP events simultaneously with an equivalent time stamp. The time stamp resolution is 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the non-directional harmonic overcurrent function. © Arcteq Relays Ltd IM00001...
  • Page 105 The magnitudes (RMS) of phase L1 (A) current components: - Fundamental harmonic harmonic harmonic harmonic harmonic IL1FFT 5 ms harmonic harmonic - 11 harmonic - 13 harmonic - 15 harmonic - 17 harmonic - 19 harmonic. © Arcteq Relays Ltd IM00001...
  • Page 106 The magnitudes (RMS) of residual I0 current components: - Fundamental harmonic harmonic harmonic harmonic harmonic I01FFT 5 ms harmonic harmonic - 11 harmonic - 13 harmonic - 15 harmonic - 17 harmonic - 19 harmonic. © Arcteq Relays Ltd IM00001...
  • Page 107 5: Off 1: Side 1 Ih> Defines which current measurement module is used by the function. Visible if the unit measurement 1: Side 1 2: Side 2 has more than one current measurement module. side © Arcteq Relays Ltd IM00001...
  • Page 108 5.00…200.00% 0.01% 20.00% (percentage monitoring) The pick-up activation of the function is not directly equal to the START signal generation of the function. The START signal is allowed if the blocking condition is not active. © Arcteq Relays Ltd IM00001...
  • Page 109 This function supports definite time delay (DT) and inverse definite minimum time delay (IDMT). For detailed information on these delay types please refer to the chapter "General properties of a protection function" and its section "Operating time characteristics for trip and reset". © Arcteq Relays Ltd IM00001...
  • Page 110 The function registers its operation into the last twelve (12) time-stamped registers. The register of the function records the ON event process data for START, TRIP or BLOCKED. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 111: Circuit Breaker Failure Protection (Cbfp; 50Bf/52Bf)

    1 ms. The function also provides a resettable cumulative counters for RETRIP, CBFP, CBFP START and BLOCKED events. The following figure presents a simplified function block diagram of the circuit breaker failure protection function. © Arcteq Relays Ltd IM00001...
  • Page 112 START or TRIP event. General settings The following general settings define the general behavior of the function. These settings are static i.e. it is not possible to change them by editing the setting group. © Arcteq Relays Ltd IM00001...
  • Page 113 Selects the residual current monitoring source, which can be either from the two 1: I01 0: Not I0Input separate residual measurements (I01 and I02) or from the phase current's 2: I02 in use calculated residual current. 3: I0Calc © Arcteq Relays Ltd IM00001...
  • Page 114 This parameter is visible only when Allow setting of individual LN mode is enabled in behaviour 4: Test/ General menu. Blocked 5: Off 0: Normal 1: Start CBFP condition 2: ReTrip Displays status of the protection function. 3: CBFP On 4: Blocked © Arcteq Relays Ltd IM00001...
  • Page 115 CBFP starts the timer. This setting defines how long the starting condition CBFP 0.000…1800.000s 0.005s 0.200s has to last before the CBFP signal is activated. The following figures present some typical cases of the CBFP function. © Arcteq Relays Ltd IM00001...
  • Page 116 The retrip is wired from its own device output contact in parallel with the circuit breaker's redundant trip coil. The CBFP signal is normally wired from its device output contact to the incomer breaker. Below are a few operational cases regarding the various applications. © Arcteq Relays Ltd IM00001...
  • Page 117 CBFP signal to the incomer breaker. If the primary protection function clears the fault, both counters (RETRIP and CBFP) are reset as soon as the measured current is below the threshold settings. © Arcteq Relays Ltd IM00001...
  • Page 118 (RETRIP and CBFP) are reset as soon as the measured current is below the threshold settings or the tripping signal is reset. This configuration allows the CBFP to be controlled with current-based functions alone, and other function trips can be excluded from the CBFP functionality. © Arcteq Relays Ltd IM00001...
  • Page 119 This configuration allows the CBFP to be controlled with current-based functions alone, with added security from current monitoring. Other function trips can also be included in the CBFP functionality. © Arcteq Relays Ltd IM00001...
  • Page 120 Probably the most common application is when the device's trip output controls the circuit breaker trip coil, while one dedicated CBFP contact controls the CBFP function. Below are a few operational cases regarding the various applications and settings of the CBFP function. © Arcteq Relays Ltd IM00001...
  • Page 121 CBFP signal is sent to the incomer breaker. If the primary protection function clears the fault, the counter for CBFP resets as soon as the measured current is below the threshold settings. © Arcteq Relays Ltd IM00001...
  • Page 122 The time delay counter for CBFP is reset as soon as the measured current is below the threshold settings or the tripping signal is reset. This configuration allows the CBFP to be controlled by current-based functions alone, and other function trips can be excluded from the CBFP functionality. © Arcteq Relays Ltd IM00001...
  • Page 123 This configuration allows the CBFP to be controlled by current-based functions alone, with added security from current monitoring. Other function trips can also be included to the CBFP functionality. © Arcteq Relays Ltd IM00001...
  • Page 124 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Device configuration as a dedicated CBFP unit Figure. 5.4.8 - 54. Wiring diagram when the device is configured as a dedicated CBFP unit. © Arcteq Relays Ltd IM00001...
  • Page 125 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.4.8 - 98. Event messages. Event block name Event names CBF1 Start ON CBF1 Start OFF CBF1 Retrip ON CBF1 Retrip OFF © Arcteq Relays Ltd IM00001...

  • Page 126: Overvoltage Protection (U>; 59)

    The function can operate on instant or time-delayed mode. In time-delayed mode the operation can be selected between definite time (DT) mode and inverse definite minimum time (IDMT). The operational logic consists of the following: • input magnitude selection • input magnitude processing • threshold comparator • block signal check © Arcteq Relays Ltd IM00001...
  • Page 127 Table. 5.4.9 - 100. Measurement input of the U> function. Signal Description Time base RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U © Arcteq Relays Ltd IM00001...
  • Page 128 20 ms averaged history value from -20 ms from START or TRIP event. Figure. 5.4.9 - 57. Selectable measurement magnitudes with 3LN+U4 VT connection. Figure. 5.4.9 - 58. Selectable measurement magnitudes with 3LL+U4 VT connection (P-E voltages not available without residual voltage). © Arcteq Relays Ltd IM00001...
  • Page 129 Table. 5.4.9 - 103. Pick-up settings. Name Description Range Step Default 0: 1 voltage Operation mode Pick-up criteria selection 1: 2 voltages 0: 1 voltage 2: 3 voltages 50.00…150.00%U 0.01%U 105%U Pick-up setting © Arcteq Relays Ltd IM00001...
  • Page 130 The blocking of the function causes an HMI display event and a time-stamped blocking event with information of the startup voltage values and its fault type to be issued. © Arcteq Relays Ltd IM00001...
  • Page 131 0.01s 0.05s setting k Time dial/multiplier setting for IDMT characteristics. This setting is active and visible when IDMT is the selected delay type. IDMT 0.01…25.00s 0.01s 1.00s Multiplier IDMT time multiplier in the U power. © Arcteq Relays Ltd IM00001...
  • Page 132 Table. 5.4.9 - 107. Event messages. Event block name Event names Start ON Start OFF Trip ON Trip OFF Block ON Block OFF Start ON Start OFF Trip ON Trip OFF Block ON Block OFF Start ON © Arcteq Relays Ltd IM00001...

  • Page 133: Undervoltage Protection (U<; 27)

    (DT) mode and inverse definite minimum time (IDMT). The operational logic consists of the following: • input magnitude selection • input magnitude processing • threshold comparator • two block signal checks (undervoltage block or stage external signal) • time delay characteristics © Arcteq Relays Ltd IM00001...
  • Page 134 Table. 5.4.10 - 109. Measurement inputs of the U< function. Signal Description Time base RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U RMS measurement of voltage U © Arcteq Relays Ltd IM00001...
  • Page 135 20 ms averaged history value from -20 ms from START or TRIP event. Figure. 5.4.10 - 61. Selectable measurement magnitudes with 3LN+U4 VT connection. Figure. 5.4.10 - 62. Selectable measurement magnitudes with 3LL+U4 VT connection (P-E voltages not available without residual voltage). © Arcteq Relays Ltd IM00001...
  • Page 136 Name Description Range Step Default 0.00…120.00%U 0.01%U 60%U Pick-up setting U Block Block setting. If set to zero, blocking is not in use. The operation is 0.00…100.00%U 0.01%U 10%U setting explained in the next chapter. © Arcteq Relays Ltd IM00001...
  • Page 137 Time When the function has detected a fault and counts down time towards a remaining -1800.000...1800.000s 0.005s trip, this displays how much time is left before tripping occurs. to trip © Arcteq Relays Ltd IM00001...
  • Page 138 • Inverse definite minimum time (IDMT): gives the TRIP signal after a time which is in relation to the set pick-up voltage U and the measured voltage U (dependent time characteristics). The IDMT function follows this formula: © Arcteq Relays Ltd IM00001...
  • Page 139 2: Yes element is reset. release time The user can reset characteristics through the application. The default setting is a 60 ms delay; the time calculation is held during the release time. © Arcteq Relays Ltd IM00001...
  • Page 140 Block ON Block OFF Undervoltage Block ON Undervoltage Block OFF Start ON Start OFF Trip ON Trip OFF Block ON Block OFF Undervoltage Block ON Undervoltage Block OFF Start ON Start OFF Trip ON Trip OFF © Arcteq Relays Ltd IM00001...

  • Page 141: Neutral Overvoltage Protection (U0>; 59N)

    100/√3 V = 57.74 V. Below is the formula for symmetric component calculation (and therefore to zero sequence voltage calculation). Below are some examples of zero sequence calculation. Figure. 5.4.11 - 65. Normal situation. © Arcteq Relays Ltd IM00001...
  • Page 142 • block signal check • time delay characteristics • output processing. The inputs for the function are the following: • operating mode selections • setting parameters • digital inputs and logic signals • measured and pre-processed voltage magnitudes. © Arcteq Relays Ltd IM00001...
  • Page 143 START or TRIP event. General settings The following general settings define the general behavior of the function. These settings are static i.e. it is not possible to change them by editing the setting group. © Arcteq Relays Ltd IM00001...
  • Page 144 Primary voltage required for tripping. The displayed pick-up voltage level U0> Pick- 0.0...1 000 000.0V 0.1V depends on the chosen U0 measurement input selection, on the pick-up up setting settings and on the voltage transformer settings. © Arcteq Relays Ltd IM00001...
  • Page 145 • Inverse definite minimum time (IDMT): gives the TRIP signal after a time which is in relation to the set pick-up voltage U and the measured voltage U (dependent time characteristics). The IDMT function follows this formula: Where: © Arcteq Relays Ltd IM00001...
  • Page 146 In the release delay option the operating time counter calculates the operating time during the release. When using this option the function does not trip if the input signal is not re-activated while the release time count is on-going. © Arcteq Relays Ltd IM00001...
  • Page 147 The function registers its operation into the last twelve (12) time-stamped registers; this information is available for all provided instances separately. The register of the function records the ON event process data for START, TRIP or BLOCKED. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 148: Sequence Voltage Protection (U1/U2>/<; 47/27P/59Pn)

    Below is the formula for symmetric component calculation (and therefore to positive sequence voltage calculation). In what follows are three examples of positive sequence calculation (positive sequence component vector). Figure. 5.4.12 - 69. Normal situation. © Arcteq Relays Ltd IM00001...
  • Page 149 Below is the formula for symmetric component calculation (and therefore to negative sequence voltage calculation). In what follows are three examples of negative sequence calculation (negative sequence component vector). Figure. 5.4.12 - 72. Normal situation. © Arcteq Relays Ltd IM00001...
  • Page 150 START and TRIP events simultaneously with an equivalent time stamp. The time stamp resolution is 1 ms. The function also a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the sequence voltage function. © Arcteq Relays Ltd IM00001...
  • Page 151 Set mode of VUB block. 2: Blocked U1/2 >/< LN 3: Test 0: On mode This parameter is visible only when Allow setting of individual LN 4: Test/Blocked mode is enabled in General menu. 5: Off © Arcteq Relays Ltd IM00001...
  • Page 152 U< pick-up setting. Please see the image below for a visualization of this function. If the block level is set to zero (0), blocking is not in use. Figure. 5.4.12 - 76. Example of the block setting operation. © Arcteq Relays Ltd IM00001...
  • Page 153 There are three basic operating modes available for the function: • Instant operation: gives the TRIP signal with no additional time delay simultaneously with the START signal. © Arcteq Relays Ltd IM00001...
  • Page 154 2: Yes release 2: Yes element is not activated during this time. When disabled, the operating time time counter is reset directly after the pick-up element reset. © Arcteq Relays Ltd IM00001...
  • Page 155 Trip OFF VUB2 Block ON VUB2 Block OFF VUB3 Start ON VUB3 Start OFF VUB3 Trip ON VUB3 Trip OFF VUB3 Block ON VUB3 Block OFF VUB4 Start ON VUB4 Start OFF VUB4 Trip ON © Arcteq Relays Ltd IM00001...

  • Page 156: Overfrequency And Underfrequency Protection (F>/<; 81O/81U)

    The function can operate on instant or time-delayed mode. The operational logic consists of the following: • input magnitude processing • threshold comparator • block signal check • time delay characteristics • output processing. The inputs for the function are the following: © Arcteq Relays Ltd IM00001...
  • Page 157 The frequency protection function compares the measured frequency to the pick-up setting (given in Hz). The source of the measured frequency depends on the user-defined tracking reference which can be chosen from the Frequency tab of the Measurement menu. © Arcteq Relays Ltd IM00001...
  • Page 158 0: No 0: No f< used in setting group group. 1: Yes f<< used in setting group f<<< used in setting group f<<<< used in setting group fset> fset>> Pick-up setting 10.00…80.00Hz 0.01Hz 51Hz fset>>> fset>>>> © Arcteq Relays Ltd IM00001...
  • Page 159 If the blocking signal is not activated when the pick-up element activates, a START signal is generated and the function proceeds to the time characteristics calculation. © Arcteq Relays Ltd IM00001...
  • Page 160 Start OFF FRQV1 f>>>> Trip ON FRQV1 f>>>> Trip OFF FRQV1 f< Start ON FRQV1 f< Start OFF FRQV1 f< Trip ON FRQV1 f< Trip OFF FRQV1 f<< Start ON FRQV1 f<< Start OFF © Arcteq Relays Ltd IM00001...

  • Page 161: Rate-Of-Change Of Frequency (Df/Dt>/<; 81R)

    One of the most common causes for the frequency to deviate from its nominal value is an unbalance between the generated power and the load demand. If the unbalance is big the frequency changes rapidly. © Arcteq Relays Ltd IM00001...
  • Page 162 The function can operate on instant or time-delayed mode. The operational logic consists of the following: • input magnitude processing • threshold comparator • block signal check • time delay characteristics • output processing. The inputs for the function are the following: © Arcteq Relays Ltd IM00001...
  • Page 163 L-N voltages of the second voltage transformer 5 ms General settings The following general settings define the general behavior of the function. These settings are static i.e. it is not possible to change them by editing the setting group. © Arcteq Relays Ltd IM00001...
  • Page 164 This function supports definite time delay (DT). For detailed information on this delay types please refer to the chapter "General properties of a protection function" and its section "Operating time characteristics for trip and reset". © Arcteq Relays Ltd IM00001...
  • Page 165 START, TRIP and BLOCKED. The user can select which event messages are stored in the main event buffer: ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. © Arcteq Relays Ltd IM00001...
  • Page 166 DFT1 df/dt>/< (8) Trip ON DFT1 df/dt>/< (8) Trip OFF DFT1 df/dt>/< (1) Block ON DFT1 df/dt>/< (1) Block OFF DFT1 df/dt>/< (2) Block ON DFT1 df/dt>/< (2) Block OFF DFT1 df/dt>/< (3) Block ON © Arcteq Relays Ltd IM00001...

  • Page 167: Power Protection (P, Q, S>/<; 32)

    The power protection function is for instant and time-delayed, three-phase overpower or underpower protection (active, reactive, or apparent). The user can select the operating mode with parameter settings. The figure below presents the pick-up areas of the function's different modes, displayed in a PQ diagram. © Arcteq Relays Ltd IM00001...
  • Page 168 START and TRIP events simultaneously with an equivalent time stamp. The time stamp resolution is 1 ms. The function also a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the power protection function. © Arcteq Relays Ltd IM00001...
  • Page 169 Blocked 5: Off Defines which power measurement module is used by the function. PQS>/< 1: POW1 This setting is available if the device has more than one current measurement side 2: POW2 POW1 measurement module. © Arcteq Relays Ltd IM00001...
  • Page 170 "Use Gen nom MVA" or "Use Trafo nom MVA". Pick-up Pick-up setting used at the moment by the function. Value of this -1800.000...1800.000MVA 0.001MVA setting parameter can change if setting group has been changed. © Arcteq Relays Ltd IM00001...
  • Page 171 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.4.15 - 149. Event messages. Event block name Event names PWR1 Start ON © Arcteq Relays Ltd IM00001...

  • Page 172: Power Factor Protection (Pf<; 55)

    The power factor protection function is the ratio of active power to apparent power (cos φ = P/S). In a fully resistive load the power factor is 1.00. In partially inductive loads the power factor is under 1.00. Power factor protection cannot detect a power factor value that is too low. © Arcteq Relays Ltd IM00001...
  • Page 173 • block signal check • time delay characteristics • output processing. The inputs for the function are the following: • operating mode selections • setting parameters • digital inputs and logic signals • measured and pre-processed current magnitudes. © Arcteq Relays Ltd IM00001...
  • Page 174 2: Blocked Set mode of UPF block. 3: Test PF< LN mode 0: On 4: Test/ This parameter is visible only when Allow setting of individual LN mode is enabled in General menu. Blocked 5: Off © Arcteq Relays Ltd IM00001...
  • Page 175 The ratio between the measured power factor and the alarm pick-up at the 0.00...1250.00 0.01 alarm value. moment Expected 0.000...1800.000s 0.005s Displays the expected operating time when a fault occurs. operating time © Arcteq Relays Ltd IM00001...
  • Page 176 Table. 5.4.16 - 155. Event messages. Event block name Event names UPF1 Block ON UPF1 Block OFF UPF1 Start ON UPF1 Start OFF UPF1 Trip ON UPF1 Trip OFF UPF1 Alarm Start ON UPF1 Alarm Start OFF UPF1 Alarm ON © Arcteq Relays Ltd IM00001...

  • Page 177: Machine Thermal Overload Protection (Tm>; 49M)

    "memory" uses; it is an integral function which tells apart this function from a normal overcurrent function and its operating principle for overload protection applications. In heating and cooling situations the thermal image for this function is calculated according to the two equations described below: © Arcteq Relays Ltd IM00001...
  • Page 178 = Correction factor between the times t and t The equation below is that of the effective current of the protected object including the TRMS measurement maximum phase current as well as a possible phase current unbalance condition. © Arcteq Relays Ltd IM00001...
  • Page 179 100 % indefinitely but never exceeds it. With a single time constant model the cooling of the object follows this same behavior, the reverse of the heating when the current feeding is completely zero. © Arcteq Relays Ltd IM00001...
  • Page 180 The formulas below present examples of the calculation of the ambient temperature coefficient (a linear correction factor to the maximum allowed current): © Arcteq Relays Ltd IM00001...
  • Page 181 The settable thermal capacity curve uses linear interpolation for ambient temperature correction with a maximum of ten (10) pairs of temperature–correction factor pairs. The temperature and coefficient pairs are set to the TM> function's settable correction curve. © Arcteq Relays Ltd IM00001...
  • Page 182 (locked rotor, overloading situations) in order to achieve a suitable thermal image for the machine. The following figure presents the various differences to consider when solve the time constants in the motor (as compared to single time constant objects like cables). © Arcteq Relays Ltd IM00001...
  • Page 183 Figure. 5.4.17 - 91. Simplified motor construction and time constants. Any normal induction machine such as electric motors have the following major components: © Arcteq Relays Ltd IM00001...
  • Page 184 (DOL) starting. Table. 5.4.17 - 157. Motor heating during DOL starting. The motor is de-energized and all parts of it are in the ambient temperature. © Arcteq Relays Ltd IM00001...
  • Page 185 Most motors are rotor- limited which results in the rotor heating up to dangerously high temperatures before the stator. © Arcteq Relays Ltd IM00001...
  • Page 186 Now, the heat transfer is stabilized and the heat generated in the motor is transferred to the surrounding air and the temperatures of the internal components are not increasing any longer. © Arcteq Relays Ltd IM00001...
  • Page 187 RTD elements. The rotor temperature is highest on the drive end becuase the cooling is the weakest there (as can be seen in the image below). © Arcteq Relays Ltd IM00001...
  • Page 188 1.15 and the ambient temperature was measured to be 24 degrees Celsius. In this case the motor was started without a load, and the loading was increased directly after starting in order to concentrate the heating effects of stable loading. © Arcteq Relays Ltd IM00001...
  • Page 189 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.17 - 93. Measured motor temperature in heating/cooling test. © Arcteq Relays Ltd IM00001...
  • Page 190 Thermal trip curves Motor thermal curves are useful when studying motor heating in possible overload and start-up situations. These are usually available upon request from manufacturers, and the relay operation can be set according to these. © Arcteq Relays Ltd IM00001...
  • Page 191 If the motor is continuously running with a constant load, the cooling time constant is not that significant and can be estimated to be e.g. two to three times longer than the heating time constant. © Arcteq Relays Ltd IM00001...
  • Page 192 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.17 - 96. Comparing single time constant thermal replica tripping curves to given motor thermal characteristics. © Arcteq Relays Ltd IM00001...
  • Page 193 In the curve simulations the hot condition was defined as 70 % of the thermal capacity. The following figures present the tripping and cooling curves of the thermal replica. © Arcteq Relays Ltd IM00001...
  • Page 194 Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.17 - 98. Thermal tripping curves with single time constant, pre-load 0% (cold). Figure. 5.4.17 - 99. Thermal tripping curves with single time constant, pre-load 90% (hot). © Arcteq Relays Ltd IM00001...
  • Page 195 Figure. 5.4.17 - 100. Thermal tripping curves with dual dynamic time constants and correction factor, pre-load 0% (cold) Figure. 5.4.17 - 101. Thermal tripping curves with dual dynamic time constants and correction factor, pre-load 90% (hot). © Arcteq Relays Ltd IM00001...
  • Page 196 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.17 - 102. Thermal cooling curves, single cooling time constant. Figure. 5.4.17 - 103. Thermal cooling curves, dynamic dual time constant. © Arcteq Relays Ltd IM00001...
  • Page 197 Figure. 5.4.17 - 104. Thermal cooling curves, dynamic triple time constant (motor is running without load in the first part with dedicated time constant). Figure. 5.4.17 - 105. NPS-biased thermal trip curves with k value of 1. © Arcteq Relays Ltd IM00001...
  • Page 198 Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.17 - 106. NPS-biased thermal trip curves with k value of 3. Figure. 5.4.17 - 107. NPS-biased thermal trip curves with k value of 7. © Arcteq Relays Ltd IM00001...
  • Page 199 The time stamp resolution is 1 ms. The function also provides a resettable cumulative counter for the TRIP, ALARM 1, ALARM 2, INHIBIT and BLOCKED events. The following figure presents a simplified function block diagram of the machine thermal overload protection function. © Arcteq Relays Ltd IM00001...
  • Page 200 Activated Temp C or 0: C The selection of whether the temperature values of the thermal image and RTD 0: C F deg 1: F compensation are shown in Celsius or in Fahrenheit. © Arcteq Relays Ltd IM00001...
  • Page 201 - motor status monitoring - machine thermal overload Nominal protection starting (TM>; 49M) 0.1...5000.0A 0.1A The motor's locked rotor current in amperes. current - motor start/ locked rotor monitoring (Ist>; 48/14) - mechanical jam protection (Im>; 51M) © Arcteq Relays Ltd IM00001...
  • Page 202 - motor status monitoring - machine thermal overload protection locked (TM>; 49M) rotor 0.1...5000.0A 0.1A The maximum locked rotor current in amperes. - motor start/ current locked rotor monitoring (Ist>; 48/14) - mechanical jam protection (Im>; 51M) © Arcteq Relays Ltd IM00001...
  • Page 203 If the (TM>; 49M) service factor is not known, this parameter should be left at its default setting of 1.00 x I © Arcteq Relays Ltd IM00001...
  • Page 204 The negative sequence current biasing factor. This factor depends on the NPS-bias motor's construction and is in relation to the positive and negative 0.1…10.0 factor sequence rotor resistances. A typical value for this is the default setting 3.0. © Arcteq Relays Ltd IM00001...
  • Page 205 T 0…3000.0min 1.0min 10.0min heating and cooling. This setting is visible when the time constants option const "Multiple" and the "Set manually" option from "Estimate short TC and timings" are both selected. © Arcteq Relays Ltd IM00001...
  • Page 206 0: Linear est. calculated compensation based on end temperatures or by a user-settable lin. or Linear 1: Set curve curve. The default setting is "0: Linear est." which means the internally curve calculated correction for ambient temperature. © Arcteq Relays Ltd IM00001...
  • Page 207 40 % ALARM 1 activation threshold. level Enable 0: Disabled TM> Disabled Enabling/disabling the ALARM 2 signal and the IO. 1: Enabled Alarm 2 TM> Alarm 2 0.0…150.0 % 40 % ALARM 2 activation threshold. level © Arcteq Relays Ltd IM00001...
  • Page 208 2: Blocked Displays the mode of TOLM block. TM> LN 3: Test This parameter is visible only when Allow setting of individual LN mode is enabled in General behaviour 4: Test/ menu. Blocked 5: Off © Arcteq Relays Ltd IM00001...
  • Page 209 - TM> T est. with act. curr.: estimation of the used thermal capacity including the current at a given moment - TM> T at a given moment: the thermal capacity used at that moment © Arcteq Relays Ltd IM00001...
  • Page 210 The function registers its operation into the last twelve (12) time-stamped registers. The register of the function records the ON event process data for TRIP, BLOCKED, etc. signals. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 211: Underexcitation Protection (Q<; 40)

    Figure. 5.4.18 - 110. Underexcitation modes. The underexcitation function uses a total of eight (8) separate setting groups which can be selected from one common source. The function can operate on instant or time-delayed mode (DT). © Arcteq Relays Ltd IM00001...
  • Page 212 If the protection relay has more than one CT module, the Measured side parameter determines which current measurement is used for the power measurement. Table. 5.4.18 - 170. Measurement inputs of the Q< function. Signal Description Time base 3PH Reactive power (P) Total three-phase reactive power © Arcteq Relays Ltd IM00001...
  • Page 213 The relay's Info page displays useful, real-time information on the state of the protection function. It is accessed either through the relay's HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. © Arcteq Relays Ltd IM00001...
  • Page 214 This function supports definite time delay (DT). For detailed information on this delay type please refer to the chapter "General properties of a protection function" and its section "Operating time characteristics for trip and reset". © Arcteq Relays Ltd IM00001...

  • Page 215: Underexcitation Protection (X<; 40)

    One way for the relay to sense underexcitation is by measuring the impedance. When the measured impedance enters the defined circle, the function will trip. The image below presents the basic principle of the function. © Arcteq Relays Ltd IM00001...
  • Page 216 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. Measured input The function block uses phase-to-phase impedance values, phase-to-phase impedance values or positive sequence impedance values. A -20ms averaged value used for pre-fault data registering. © Arcteq Relays Ltd IM00001...
  • Page 217 Sets the diameter of tripping area. (pri) The pick-up activation of the function is not directly equal to the START signal generation of the function. The START signal is allowed if the blocking condition is not active. © Arcteq Relays Ltd IM00001...
  • Page 218 This function supports definite time delay (DT). For detailed information on this delay type please refer to the chapter "General properties of a protection function" and its section "Operating time characteristics for trip and reset". © Arcteq Relays Ltd IM00001...

  • Page 219: Stator Earth Fault Protection (U03Rd>; 64S)

    100 % stator earth fault protection functions. The figure below demonstrates the overlapping range of the neutral overvoltage and the 100 % stator earth fault protection function. © Arcteq Relays Ltd IM00001...
  • Page 220 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the 100 % stator earth fault protection function. © Arcteq Relays Ltd IM00001...
  • Page 221 The function has an inbuilt low-current blocking feature to prevent faulty trips. It is set by the Low current blocking I1< set parameter. If this parameter is set above zero (0), the measured positive sequence current must be above the set limit for the function to trip. © Arcteq Relays Ltd IM00001...
  • Page 222 Measured U Measured third harmonic residual voltage in relation to voltage 0.00...1250.00%U 0.01%U harm (%) transformer nominal. Measured U Measured third harmonic residual voltage on the primary side of 0.00...1250.00V 0.01V harm (Pri) voltage transformer. © Arcteq Relays Ltd IM00001...
  • Page 223 • t = operating time • k = time dial setting • U = measured voltage • U = pick-up setting • a = IDMT multiplier setting The following table presents the setting parameters for the function's time characteristics. © Arcteq Relays Ltd IM00001...
  • Page 224 ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.4.20 - 188. Event messages. Event block name Event names SEF1 Start ON © Arcteq Relays Ltd IM00001...

  • Page 225: Voltage-Restrained Overcurrent Protection (Iv>; 51V)

    80 % of the normal. A fixed pick-up level of voltage-controlled overcurrent protection is easier to coordinate with other relays. However, the voltage-restrained overcurrent protection function is less prone to making unwanted operations on motor starting currents and system swings. © Arcteq Relays Ltd IM00001...
  • Page 226 START and TRIP events simultaneously with an equivalent time stamp. The time stamp resolution is 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. The following figure presents a simplified function block diagram of the non-directional overcurrent function. © Arcteq Relays Ltd IM00001...
  • Page 227 ( I ) for each of the three phases. The reset ratio of 97 % is built into the function and is always relative to the current pick-up value. © Arcteq Relays Ltd IM00001...
  • Page 228 0.00...1250.00xIn 0.01xIn level now up level changes with positive sequence voltage setting changes. Measured Calculated positive sequence voltage at the moment. This influences 0.00...1250.00%Un 0.01%Un voltage now the overcurrent pick-up level used by the function. © Arcteq Relays Ltd IM00001...
  • Page 229 The function registers its operation into the last twelve (12) time-stamped registers. The register of the function records the ON event process data for START, TRIP or BLOCKED. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 230: Volts-Per-Hertz Overexcitation Protection (V/Hz>; 24)

    The blocking signal and the setting group selection control the operating characteristics of the function during normal operation, i.e. the user or user-defined logic can change function parameters while the function is running. © Arcteq Relays Ltd IM00001...
  • Page 231 Figure. 5.4.22 - 118. Simplified function block diagram of the V/Hz> function. Measured input The function block uses analog system voltages and system frequency measurement values. Table. 5.4.22 - 196. Measurement inputs of the volts-per-hertz function. Signal Description Time base System voltage RMS System voltage RMS © Arcteq Relays Ltd IM00001...
  • Page 232 The pick-up activation of the function is not directly equal to the START signal generation of the function. The START signal is allowed if the blocking condition is not active. Inverse operating time characteristics are calculated according to the following equation: © Arcteq Relays Ltd IM00001...
  • Page 233 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.22 - 119. Inverse (above) and inverse and DT (below) time characteristics with the TimeDial k setting effect. © Arcteq Relays Ltd IM00001...
  • Page 234 In the release delay option the operating time counter calculates the operating time during the release. When using this option the function does not trip if the input signal is not re-activated while the release time count is on-going. © Arcteq Relays Ltd IM00001...
  • Page 235 The variables the user can set are binary signals from the system. The blocking signal needs to reach the device minimum of 5 ms before the set operating delay has passed in order for the blocking to activate in time. © Arcteq Relays Ltd IM00001...
  • Page 236 Start/Trip -20ms frequency Voltages (AB/BC/AC) fault Start/Trip voltages Frequency fault Start/Trip frequency Voltages (AB/BC/AC) pre-fault Start -200ms voltages Frequency pre-fault Start -200ms frequency Trip time remaining 0 ms...1800 s Used SG Setting group 1...8 active © Arcteq Relays Ltd IM00001...

  • Page 237: Underimpedance Protection (Z<; 21U)

    • input magnitude selection • input magnitude processing • threshold comparator • block signal check • time delay characteristics • output processing. The inputs for the function are the following: • operating mode selections • setting parameters © Arcteq Relays Ltd IM00001...
  • Page 238 Impedance of phase-to-phase (P3-P1) Pos.Seq.Imp Positive sequence impedance General settings The following general settings define the general behavior of the function. These settings are static i.e. it is not possible to change them by editing the setting group. © Arcteq Relays Ltd IM00001...
  • Page 239 When the function has detected a fault and counts down time towards a remaining to -1800.000...1800.000s 0.005s trip, this displays how much time is left before tripping occurs. trip meas 0.00...1250.00 0.01 The ratio between the lowest measured impedance and the pick-up value. the moment © Arcteq Relays Ltd IM00001...
  • Page 240 The function registers its operation into the last twelve (12) time-stamped registers. The register of the function records the ON event process data for START, TRIP or BLOCKED. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 241: Inadvertend Energizing Protection (I> U< I.a.e; 50/27)

    Table. 5.4.24 - 209. Measurement inputs of the Z< function. Signal Description Time base IL1RMS RMS measurement of phase L1 (A) current IL2RMS RMS measurement of phase L2 (B) current IL3RMS RMS measurement of phase L3 (C) current Pos. Seq. Voltage Positive sequence voltage © Arcteq Relays Ltd IM00001...
  • Page 242 "start" condition. activation Current 0.05 If "start" condition is on and each phase current is above this limit the 0.05...3.00 xIn 0.05 xIn limit I>/< function will trip. © Arcteq Relays Ltd IM00001...
  • Page 243 The blocking signal can also be tested in the commissioning phase by a software switch signal when the relay's testing mode "Enable stage forcing" is activated ( General → Device ). © Arcteq Relays Ltd IM00001...

  • Page 244: Inadvertend Energizing Protection (I> U< I.a.e; 50/27)

    The operational logic consists of the following: • input magnitude processing • threshold comparator • block signal check • time delay characteristics • output processing. The inputs for the function are the following: • operating mode selections © Arcteq Relays Ltd IM00001...
  • Page 245 Set mode of IAE block. I>U< I.A.E LN 3: Test 0: On This parameter is visible only when Allow setting of individual LN mode is mode 4: Test/ enabled in General menu. Blocked 5: Off © Arcteq Relays Ltd IM00001...
  • Page 246 The relay's Info page displays useful, real-time information on the state of the protection function. It is accessed either through the relay's HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. © Arcteq Relays Ltd IM00001...
  • Page 247 ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.4.25 - 219. Event messages. Event block name Event names IAE1 Start ON © Arcteq Relays Ltd IM00001...

  • Page 248: Pole Slip Protection (78)

    (3) output signals. In the instant operating mode the function outputs START and TRIP events simultaneously with an equivalent time stamp. The time stamp resolution is 1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. © Arcteq Relays Ltd IM00001...
  • Page 249 Set mode of OOS block. Pole slip [78] LN 3: Test 0: On This parameter is visible only when Allow setting of individual LN mode is mode 4: Test/ enabled in General menu. Blocked 5: Off © Arcteq Relays Ltd IM00001...
  • Page 250 How many slips need to be detected for the function to 1...5 slips 1 slips trip slips trip. Reset slip detection after 0.000...1800.000 0.005 Maximum time between slips before the function resets 1.000 s last detected slip the slip counter to zero. © Arcteq Relays Ltd IM00001...
  • Page 251 0: Normal 1: Start Pole slip condition Displays status of the protection function. 2: Trip 3: Blocked 0: Ok 1: Incorrect VT Configuration status Displays the status of settings currently in use. 2: Incorrect char. © Arcteq Relays Ltd IM00001...
  • Page 252 Table. 5.4.26 - 226. Register content. Date and time Event In blinder time Used SG dd.mm.yyyyhh:mm:ss.mss Event name Duration of reactance being between the blinders. Setting group 1...8 active © Arcteq Relays Ltd IM00001...

  • Page 253: Generator/Transformer Differential Protection (Idb>/Idi>/I0Dhv>/I0Dlv>; 87T/87N/ 87G)

    The following table gives a rough idea what protection methods and elements as well as risks exist for the different types of transformers. Overlooking these points when designing transformers increase the risk of costly problems with the transformer. © Arcteq Relays Ltd IM00001...
  • Page 254 If the transformer has forced cooling, monitoring and protection for cooling systems should be applied. Separated relays for control, monitoring and protection. © Arcteq Relays Ltd IM00001...
  • Page 255 • the transformer's vector group (for matching the transformer vectors in p.u.) • the ratios and properties of the transformers HV and LV sides. This chapter shows the setting and the principle of transformer differential protection step by step. © Arcteq Relays Ltd IM00001...
  • Page 256 However, if one feels inclined to calculate the amplitude matching factor, they can do so with the formulas presented below. © Arcteq Relays Ltd IM00001...
  • Page 257 This is called amplitude matching of the HV and LV sides. In modern differential relays this is done automatically when the nominal values and CT ratings are set for the transformer. Thus, these calculations only have nice-to-know informational value. © Arcteq Relays Ltd IM00001...
  • Page 258 LV side is leading 30 degrees; '5' and '7' are just the other ends of the windings thus causing a 180-degree difference between the '1' and '11' clock numbers. The following example explains transformer current vectors and what a connection might look like. © Arcteq Relays Ltd IM00001...
  • Page 259 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.27 - 131. Yd1 transformer's internal connection (in theory). © Arcteq Relays Ltd IM00001...
  • Page 260 Y-connected vector diagram. The images below present the differential algorithm itself (one calculating formula for each phase difference); first the "subtract" formulas, then the "add" formulas. Selection is based on the CT connections. © Arcteq Relays Ltd IM00001...
  • Page 261 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.27 - 133. "Subtract" formula. Figure. 5.4.27 - 134. "Add" formula. Figure. 5.4.27 - 135. CTs' starpoints requiring the "Add" mode. © Arcteq Relays Ltd IM00001...
  • Page 262 Next, these two formulas are combined in a graph: the x-axis presents the measured differential current, and the y-axis presents the calculated bias current. The following graph shows the differential function characteristic, both biased and non-biased. © Arcteq Relays Ltd IM00001...
  • Page 263 ). It is the basic sensitivity limit: when the measured differential current is below this limit, the d>pick-up transformer still operates normally and the protection does not trigger. In other words, the pick-up current setting must be higher than the combination of all the normal operation factors that cause differential currents. © Arcteq Relays Ltd IM00001...
  • Page 264 3) Relay measurement accuracy (primary and secondary) (RE The relay measurement error is below 0.5 %, its optional accuracy below 0.2 % per measurement channel: the combined value for both sides is either 1 % or 0.4 %. © Arcteq Relays Ltd IM00001...
  • Page 265 This causes a difference in the nominal current condition, which can be noticed as a differential current in the relay. Usually tap changer positions are presented as deviation steps for the secondary voltage to both positive and negative direction from the center (see the second image below). © Arcteq Relays Ltd IM00001...
  • Page 266 If there is no tap changer, the maximum uncertainty can be calculated sufficiently enough by summing the maximum inaccuracies of the CTs on the HV and LV sides. © Arcteq Relays Ltd IM00001...
  • Page 267 Slope 1 is calculated by using the transformer and CT nominal values in the maximum full load (Turnpoint 2) of the transformer with highest possible differential current causing tap position. Generally the Slope 1 setting is calculated as follows: © Arcteq Relays Ltd IM00001...
  • Page 268 CTs differently (starpoint towards or away from the transformer). Thus, the differential current is always calculated as follows: © Arcteq Relays Ltd IM00001...
  • Page 269 Therefore, the differential current is the following: If the Maximum mode is used for biasing (due to a single end fault), the bias current is the same as the differential current. Therefore, the Slope 2 setting is calculated as follows: © Arcteq Relays Ltd IM00001...
  • Page 270 CTs, the connection between the CTs, as well as the cross-section and material of the wires. Let us begin with the burden the wiring causes to the relay, and calculate the resistance in a conductor: © Arcteq Relays Ltd IM00001...
  • Page 271 It is recommended that you use the worst-case scenario as the basis for calculating the CT burden. In most cases these +75 ºC values are sufficient. If the ambient temperature in your application is higher than +75 ºC, the resistance should be calculated for that specific temperature. © Arcteq Relays Ltd IM00001...
  • Page 272 If the CTs have the possibility to saturate (that is, the calculated through fault current is bigger than the ALF on either CT side), the setting of the instant stage must be set high enough so that it does not operate on through fault saturation. © Arcteq Relays Ltd IM00001...
  • Page 273 (using these same formulas) in the Transformer status monitoring (TRF) module. When everything is set up correctly in the relay and when the transformer is feeding the load with nominal power, the result should look like the following example configuration when the example settings and transformer are used. © Arcteq Relays Ltd IM00001...
  • Page 274 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.4.27 - 142. Example configuration for the transformer differential function. © Arcteq Relays Ltd IM00001...
  • Page 275 Our example presented only one type of transformer and its properties. Another very common variation is the type of transformer where the star side (HV, LV, or both) is earthed and thus forms a route outside the differential zone (see the image below). © Arcteq Relays Ltd IM00001...
  • Page 276 (in p.u.) before differential calculation and thus negates the effect of an external earth fault. Correctly selected transformer settings prevent the differential function from being tripped by out-of-zone earth faults (see the image below). © Arcteq Relays Ltd IM00001...
  • Page 277 However, enabling the REF protection requires that both the phase current measurements and the starpoint current are available and can be connected to the relay's residual current channel on the corresponding (HV/LV) side measurement. © Arcteq Relays Ltd IM00001...
  • Page 278 (external) earth faults, and the how a heavy fault going fully through the second biased section (Slope 2) can cause saturation in the CTs' phase currents. The recommended base settings: • Pick-up (base sensitivity): typically 5 % to 10 % of the phase current CT error (Px) © Arcteq Relays Ltd IM00001...
  • Page 279 The differential relay sees the energization current as a differential current since it only flows through the primary side winding only. The saturation of the transformer core generates the 2 harmonic component which can be used to block the biased sensitive differential stage during energization. © Arcteq Relays Ltd IM00001...
  • Page 280 (in amperes), the fourth graph depicts the fundamental (50 Hz) FFT- calculated currents (in amperes), and fifth graph depicts the 2 harmonic components relative to the corresponding fundamental component currents (with the 15 % setting limit). © Arcteq Relays Ltd IM00001...
  • Page 281 While the results are very low compared to the magnetizing inrush current magnitudes, the differential relay would still definitely trip without the 2 harmonic blocking. The situation is the same with all of the calculted setting variations. © Arcteq Relays Ltd IM00001...
  • Page 282 Figure. 5.4.27 - 148. Inrush blocking by using the 2 harmonic (relative to fundamental frequency). Figure. 5.4.27 - 149. Example of transformer magnetizing inrush currents. A conservative setting recommendation for standard type transformers: • enabling the 2 harmonic blocking © Arcteq Relays Ltd IM00001...
  • Page 283 Figure. 5.4.27 - 150. Transformer behavior in case of overvoltage caused by overexcitation. © Arcteq Relays Ltd IM00001...
  • Page 284 The figures below present the system voltage and the magnitude of the 5 harmonic component (both in per-unit), absolute and scaled to the transformer nominal. © Arcteq Relays Ltd IM00001...
  • Page 285 (that is, no overvoltage relays are available), this blocking can be enabled with the setting of 30...40 % with the disturbance recorder enabled. If a trip occurs as a result of overexcitation, the settings can be adjusted based on the data captured by the disturbance recorder. © Arcteq Relays Ltd IM00001...
  • Page 286 HV and the LV side. HV side The HV side nominal voltage of the transformer. This nominal 0.1…500.0kV 0.1kV 110.0kV value is used to calculate the nominal currents of the voltage HV side. © Arcteq Relays Ltd IM00001...
  • Page 287 LV side current grounded monitoring grounded grounded calculation. The selection is visible only if the option 1: Grounded - transformer "Manual set" is selected for the vector group setting. differential © Arcteq Relays Ltd IM00001...
  • Page 288 Idb> Pick- 0.01…100.00% 0.01% 10.00% The base sensitivity for the differential characteristics. Turnpoint 0.01…50.00×I 0.01×I 1.00×I Turnpoint 1 for the differential characteristics. Slope 1 0.01…250.00% 0.01% 10.00% Slope 1 for the differential characteristics. © Arcteq Relays Ltd IM00001...
  • Page 289 LV side" setting is enabled. Slope 2 of the LV side restricted earth fault differential LV I0d> 0.01…250.00% 0.01% 200.00% characteristics. This setting is only visible if the "Enable I0d> (REF) Slope 2 LV side" setting is enabled. © Arcteq Relays Ltd IM00001...
  • Page 290 The data register is available, based on the changes in the tripping events. Table. 5.4.27 - 231. Event messages. Event block name Event names DIF1 Idb> Trip ON DIF1 Idb> Trip OFF DIF1 Idb> Blocked (ext) ON © Arcteq Relays Ltd IM00001...
  • Page 291 The function registers its operation into the last twelve (12) time-stamped registers. The table below presents the structure of the function's register content. Table. 5.4.27 - 232. Register content. Name Description Date and time dd.mm.yyyy hh:mm:ss.mss Event Event name © Arcteq Relays Ltd IM00001...

  • Page 292: Resistance Temperature Detectors (Rtd)

    (2) separate alarms from one selected input. The user can set alarms and measurements to be either in degrees Celsius or Fahrenheit. The following figure shows the principal structure of the resistance temperature detection function. © Arcteq Relays Ltd IM00001...
  • Page 293 When using a thermocouple module, the thermo element type also needs to be set for each of the measurement channels. Once these settings are done the RTDs are ready for other functions. © Arcteq Relays Ltd IM00001...
  • Page 294 There are sixteen (16) available sensor inputs in the function. An active alarm requires a valid channel measurement. It can be invalid if communication is not working or if a sensor is broken. © Arcteq Relays Ltd IM00001...
  • Page 295 Enables/disables the selection of Alarm 2 for the 0: Disable 1: Enable measurement channel x. 0: > Selects whether the measurement is above or S1...S16 Alarm2 >/< 0: > 1: < below the setting value. © Arcteq Relays Ltd IM00001...
  • Page 296 S4 Alarm2 OFF RTD1 S5 Alarm1 ON RTD1 S5 Alarm1 OFF RTD1 S5 Alarm2 ON RTD1 S5 Alarm2 OFF RTD1 S6 Alarm1 ON RTD1 S6 Alarm1 OFF RTD1 S6 Alarm2 ON RTD1 S6 Alarm2 OFF © Arcteq Relays Ltd IM00001...
  • Page 297 S14 Alarm1 OFF RTD1 S14 Alarm2 ON RTD1 S14 Alarm2 OFF RTD1 S15 Alarm1 ON RTD1 S15 Alarm1 OFF RTD1 S15 Alarm2 ON RTD1 S15 Alarm2 OFF RTD1 S16 Alarm1 ON RTD1 S16 Alarm1 OFF © Arcteq Relays Ltd IM00001...
  • Page 298 S12 Meas Invalid RTD2 S13 Meas Ok RTD2 S13 Meas Invalid RTD2 S14 Meas Ok RTD2 S14 Meas Invalid RTD2 S15 Meas Ok RTD2 S15 Meas Invalid RTD2 S16 Meas Ok RTD2 S16 Meas Invalid © Arcteq Relays Ltd IM00001...

  • Page 299: Arc Fault Protection (Iarc>/I0Arc>; 50Arc/50Narc)

    The arc protection card has four (4) sensor channels, and up to three (3) arc point sensors can be connected to each channel. The sensor channels support Arcteq AQ-01 (light sensing) and AQ-02 (pressure and light sensing) units. Optionally, the protection function can also be applied with a phase current or a residual current condition: the function trips only if the light and overcurrent conditions are met.
  • Page 300 26 output signals. The time stamp resolution is 1 ms. The function also a resettable cumulative counter for the TRIP and BLOCKED events for each zone. © Arcteq Relays Ltd IM00001...
  • Page 301 AQ-100 series units. The parameter I/I0 Arc> Self supervision test pulse should be activated when connecting the AQ-100 series units to the AQ-200 series arc protection card to prevent the pulses from activating ArcBI1. © Arcteq Relays Ltd IM00001...
  • Page 302 If either phase overcurrent or residual overcurrent is needed for the tripping decision, they can be enabled in the same way as light sensors in the zone. When a current channel is enabled, the measured current needs to be above the set current limit in addition to light sensing. © Arcteq Relays Ltd IM00001...
  • Page 303 Table. 5.4.29 - 238. Enabled Zone pick-up settings. Name Description Range Step Default Phase 0.05...40.00 0.01 current The phase current measurement's pick-up value (in p.u.). 1.2 x I pick-up © Arcteq Relays Ltd IM00001...
  • Page 304 HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. Table. 5.4.29 - 239. Information displayed by the function. Name Range Description © Arcteq Relays Ltd IM00001...
  • Page 305 START, TRIP, and BLOCKED. The user can select which event messages are stored in the main event buffer: ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. © Arcteq Relays Ltd IM00001...
  • Page 306 ARC1 Channel 2 Pressure ON ARC1 Channel 2 Pressure OFF ARC1 Channel 3 Light ON ARC1 Channel 3 Light OFF ARC1 Channel 3 Pressure ON ARC1 Channel 3 Pressure OFF ARC1 Channel 4 Light ON © Arcteq Relays Ltd IM00001...

  • Page 307: Voltage Memory

    The user can activate voltage memory (and find all related settings) by following this path in relay settings: Measurement → Transformers → VT Module (3U/4U) 1 → Voltage memory ("Activated"/"Disabled"). The activation of voltage memory depends of following criteria: © Arcteq Relays Ltd IM00001...
  • Page 308 Healthy state angles (before a fault) are used during a fault. This is why a drift between the assumed voltage angle and the actual measured phase current angle takes place. While voltage memory is used, the angle of phase currents drifts approximately one degree for each passing second (see the graph below). © Arcteq Relays Ltd IM00001...
  • Page 309 . When the mode 2LL+U0 is used, the memory is based on calculated phase-to-neutral voltages. Pick-up VMEM activ VMEM activa a tion v tion volta oltage ge and Mea Measur sured curr ed current condition 3I> ent condition 3I> © Arcteq Relays Ltd IM00001...
  • Page 310 ON, OFF, or both. Table. 5.4.30 - 243. Event messages. Event block name Event names M1VT1 Voltage memory enabled M1VT1 Voltage memory disabled M1VT1 Voltage low detected ON M1VT1 Voltage low detected OFF © Arcteq Relays Ltd IM00001...

  • Page 311: Control Functions

    Live Edit mode is active. Table. 5.5.1 - 245. Information displayed by the function. Name Range Step Description 0: Normal Common signals condition 1: Start Displays status of the function. 2: Trip © Arcteq Relays Ltd IM00001...

  • Page 312: Setting Group Selection

    The following figure presents a simplified function block diagram of the setting group selection function. Figure. 5.5.2 - 161. Simplified function block diagram of the setting group selection function. © Arcteq Relays Ltd IM00001...
  • Page 313 Disabled from a local HMI. This parameter overrides the local control of the setting Enabled groups and it remains on until the user disables it. © Arcteq Relays Ltd IM00001...
  • Page 314 0: Not control. Can be controlled with pulses or static signals. If static signal control is applied, group active all other SG requests will be processed regardless of the signal status of this setting Active group. © Arcteq Relays Ltd IM00001...
  • Page 315 The status of the Petersen coil controls whether Setting group 1 is active. If the coil is disconnected, Setting group 2 is active. This way, if the wire is broken for some reason, the setting group is always controlled to SG2. © Arcteq Relays Ltd IM00001...
  • Page 316 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.5.2 - 164. Setting group control – two-wire connection from Petersen coil status. © Arcteq Relays Ltd IM00001...
  • Page 317 The application-controlled setting group change can also be applied entirely from the relay's internal logics. For example, the setting group change can be based on the cold load pick-up function (see the image below). © Arcteq Relays Ltd IM00001...
  • Page 318 The function does not have a register. Table. 5.5.2 - 249. Event messages. Event block name Event names SG2 Enabled SG2 Disabled SG3 Enabled SG3 Disabled SG4 Enabled SG4 Disabled SG5 Enabled SG5 Disabled © Arcteq Relays Ltd IM00001...
  • Page 319 Force Request Fail Force ON Force Request Fail Force OFF SG Req. Fail Lower priority Request ON SG Req. Fail Lower priority Request OFF SG1 Active ON SG1 Active OFF SG2 Active ON SG2 Active OFF © Arcteq Relays Ltd IM00001...

  • Page 320: Object Control And Monitoring

    • digital input status indications (the OPEN and CLOSE status signals) • blockings (if applicable) • the OBJECT READY and SYNCHROCHECK monitor signals (if applicable). • Withdrawable cart IN and OUT status signals (if applicable). © Arcteq Relays Ltd IM00001...
  • Page 321 Circuit 2: Disconnector withdrawable cart is in/out status is monitored. See the next table ("Object breaker (MC) types") for a more detailed look at which functionalities each of the object types 3: Disconnector have. (GND) © Arcteq Relays Ltd IM00001...
  • Page 322 Functionalities Description Breaker cart position Circuit breaker position Circuit breaker control Withdrawable circuit Object ready check before closing The monitor and control configuration of the withdrawable breaker breaker circuit breaker. Synchrochecking before closing breaker Interlocks © Arcteq Relays Ltd IM00001...
  • Page 323 Determines the maximum length for a Close pulse from the output relay to the 0.02…500.00 0.02 command 0.2 s controlled object. If the object operates faster than this set time, the control pulse pulse is reset and a status change is detected. length © Arcteq Relays Ltd IM00001...
  • Page 324 Blocking and interlocking can be based on any of the following: other object statuses, a software function or a digital input. The image below presents an example of an interlock application, where the closed earthing switch interlocks the circuit breaker close command. © Arcteq Relays Ltd IM00001...
  • Page 325 The user can select which event messages are stored in the main event buffer: ON, OFF, or both. The function registers its operation into the last twelve (12) time-stamped registers. The events triggered by the function are recorded with a time stamp and with process data values. © Arcteq Relays Ltd IM00001...
  • Page 326 Contact Abrasion Alarm On OBJ1...OBJ10 Contact Abrasion Alarm Off OBJ1...OBJ10 Switch Operating Time Exceeded On OBJ1...OBJ10 Switch Operating Time Exceeded Off OBJ1...OBJ10 XCBR Loc On OBJ1...OBJ10 XCBR Loc Off OBJ1...OBJ10 XSWI Loc On OBJ1...OBJ10 XSWI LOC Off © Arcteq Relays Ltd IM00001...

  • Page 327: Indicator Object Monitoring

    Object status 1: Open neither of the status conditions (open or close) are active. Bad status is displayed ("Ind.X Object 2: Closed when both of the status conditions (open and close) are active. Status") 3: Bad © Arcteq Relays Ltd IM00001...
  • Page 328 CIN1 Close CIN1 CIN2 Intermediate CIN2 Open CIN2 Close CIN2 CIN3 Intermediate CIN3 Open CIN3 Close CIN3 CIN4 Intermediate CIN4 Open CIN4 Close CIN4 CIN5 Intermediate CIN5 Open CIN5 Close CIN5 CIN6 Intermediate CIN6 Open © Arcteq Relays Ltd IM00001...

  • Page 329: Synchrocheck (Δv/Δa/Δf; 25)

    (UL12, UL23 or UL31). • SYN3 – Supervises the synchronization condition between the channels U3 and U4. The seven images below present three different example connections and four example applications of the synchrocheck function. © Arcteq Relays Ltd IM00001...
  • Page 330 Figure. 5.5.5 - 169. Example connection of the synchrocheck function (3LN+U4 mode, SYN1 in use, UL1 as reference voltage). Figure. 5.5.5 - 170. Example connection of the synchrocheck function (2LL+U0+U4 mode, SYN1 in use, UL12 as reference voltage). © Arcteq Relays Ltd IM00001...
  • Page 331 Figure. 5.5.5 - 171. Example connection of the synchrocheck function (2LL+U3+U4 mode, SYN3 in use, UL12 as reference voltage). Figure. 5.5.5 - 172. Example application (synchrocheck over one breaker, with 3LL and 3LN VT connections). © Arcteq Relays Ltd IM00001...
  • Page 332 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.5.5 - 173. Example application (synchrocheck over one breaker, with 2LL VT connection). © Arcteq Relays Ltd IM00001...
  • Page 333 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 5.5.5 - 174. Example application (synchrocheck over two breakers, with 2LL VT connection). © Arcteq Relays Ltd IM00001...
  • Page 334 "live" or a "dead" state. The parameter SYNx U conditions is used to determine the conditions (in addition to the three aspects) which are required for the systems to be considered synchronized. The image below shows the different states the systems can be in. © Arcteq Relays Ltd IM00001...
  • Page 335 Instruction manual Version: 2.07 Figure. 5.5.5 - 176. System states. The following figures present simplified function block diagrams of the synchrocheck function. Figure. 5.5.5 - 177. Simplified function block diagram of the SYN1 and SYN2 function. © Arcteq Relays Ltd IM00001...
  • Page 336 Displays the mode of SYN block. 2: Blocked dV / da / df LN 3: Test This parameter is visible only when Allow setting of individual LN mode is behaviour 4: Test/Blocked enabled in General menu. 5: Off © Arcteq Relays Ltd IM00001...
  • Page 337 Setting parameters NOTE! TE! Before these settings can be accessed, a voltage channel (U3 or U4) must be set into the synchrocheck mode ("SS") in the voltage transformer settings ( Measurements → VT Module ). © Arcteq Relays Ltd IM00001...
  • Page 338 0: Not in use Selects the reference voltage of the stage. SYN2 V 1: UL12 0: Not Reference 2: UL23 in use SYN2 is available when both U3 and U4 have been set to SS mode. 3: UL31 © Arcteq Relays Ltd IM00001...
  • Page 339 SYN1 SYN1 Volt condition OK SYN1 SYN1 Volt cond not match SYN1 SYN1 Volt diff Ok SYN1 SYN1 Volt diff out of setting SYN1 SYN1 Angle diff Ok SYN1 SYN1 Angle diff out of setting © Arcteq Relays Ltd IM00001...
  • Page 340 SYN1 SYN2 Switch OFF SYN1 SYN3 Switch ON SYN1 SYN3 Switch OFF The function registers its operation into the last twelve (12) time-stamped registers. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 341: Milliampere Output Control

    Enable mA output channels 3 1: Enabled and 4 mA option Enable mA output channels 5 Enables and disables the outputs of the mA output Disabled card 2 and 6 Disabled card 2. 1: Enabled © Arcteq Relays Ltd IM00001...
  • Page 342 The mA output value when the measured value is equal output 0.0000…24.0000mA 0.0001mA 0mA to or greater than Input value 2. value 2 Figure. 5.5.6 - 179. Example of the effects of mA output channel settings. © Arcteq Relays Ltd IM00001...

  • Page 343: Synchronizer (Δv/Δa/Δf; 25)

    The user can synchronize up to eight (8) circuit breakers with the same synchronizing function by using different setting groups and the logic editor. The synchrocheck function is used to parallel or energize power lines. © Arcteq Relays Ltd IM00001...
  • Page 344 • Increase Voltage • Decrease Voltage • Increase Frequency • Decrease Frequency • Breaker Close Pulse • Long Sync Time • Nets Standstill • Nets Departing • Nets Enclosing The inputs for the function are the following: © Arcteq Relays Ltd IM00001...
  • Page 345 0deg Magnitude difference on closing BRK -200.000...200.000%Un 0.001%Un 0%Un Frequency difference on closing BRK -100.000...100.000Hz 0.001Hz Angle difference on closing BRK -360.000...360.000deg 0.001deg 0deg Estimated BRK Closing time 0.000...360.000s 0.005s Networks rotating time 0.000...360.000s 0.005s © Arcteq Relays Ltd IM00001...
  • Page 346 Table. 5.5.7 - 273. Synchronizer internal parameters. Name Range Step Default Maximum allowed voltage difference to start synchronizing 0.00...50.00%Un 0.01%Un 20.00%Un Block voltage up commands over 0.00...50.00%Un 0.01%Un 20.00%Un Block voltage down commands under -50.00...50.00%Un 0.01%Un -20.00%Un © Arcteq Relays Ltd IM00001...
  • Page 347 Synchronizing Blocked OFF GSYN Synchronizing Running ON GSYN Synchronizing Running OFF GSYN Synchr. Increase Voltage ON GSYN Synchr. Increase Voltage OFF GSYN Synchr. Decrease Voltage ON GSYN Synchr. Decrease Voltage OFF GSYN Synchr. Increase Frequency ON © Arcteq Relays Ltd IM00001...

  • Page 348: Vector Jump (Δφ; 78)

    The operational logic consists of the following: • input magnitude selection • input magnitude processing • threshold comparator • two block signal checks (undervoltage block or stage external signal) • time delay characteristics • output processing. © Arcteq Relays Ltd IM00001...
  • Page 349 Table. 5.5.8 - 275. Measurement inputs of the vector jump function. Signal Description Time base Measured line-to-line voltage U Measured line-to-line voltage U Measured line-to-line voltage U Measured line-to-neutral voltage U Measured line-to-neutral voltage U Measured line-to-neutral voltage U © Arcteq Relays Ltd IM00001...
  • Page 350 The function's stage trip signal lasts for 20 ms and automatically resets after that time has passed. The setting value is common for all measured amplitudes. Figure. 5.5.8 - 183. Vector jump from the relay's point of view. © Arcteq Relays Ltd IM00001...
  • Page 351 The relay's Info page displays useful, real-time information on the state of the protection function. It is accessed either through the relay's HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. © Arcteq Relays Ltd IM00001...
  • Page 352 START, TRIP, and BLOCKED. The user can select which event messages are stored in the main event buffer: ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. © Arcteq Relays Ltd IM00001...

  • Page 353: Synchronizer (Δv/Δa/Δf; 25)

    The user can synchronize up to eight (8) circuit breakers with the same synchronizing function by using different setting groups and the logic editor. The synchrocheck function is used to parallel or energize power lines. © Arcteq Relays Ltd IM00001...
  • Page 354 • Increase Voltage • Decrease Voltage • Increase Frequency • Decrease Frequency • Breaker Close Pulse • Long Sync Time • Nets Standstill • Nets Departing • Nets Enclosing The inputs for the function are the following: © Arcteq Relays Ltd IM00001...
  • Page 355 0deg Magnitude difference on closing BRK -200.000...200.000%Un 0.001%Un 0%Un Frequency difference on closing BRK -100.000...100.000Hz 0.001Hz Angle difference on closing BRK -360.000...360.000deg 0.001deg 0deg Estimated BRK Closing time 0.000...360.000s 0.005s Networks rotating time 0.000...360.000s 0.005s © Arcteq Relays Ltd IM00001...
  • Page 356 Table. 5.5.9 - 284. Synchronizer internal parameters. Name Range Step Default Maximum allowed voltage difference to start synchronizing 0.00...50.00%Un 0.01%Un 20.00%Un Block voltage up commands over 0.00...50.00%Un 0.01%Un 20.00%Un Block voltage down commands under -50.00...50.00%Un 0.01%Un -20.00%Un © Arcteq Relays Ltd IM00001...
  • Page 357 Synchronizing Blocked OFF GSYN Synchronizing Running ON GSYN Synchronizing Running OFF GSYN Synchr. Increase Voltage ON GSYN Synchr. Increase Voltage OFF GSYN Synchr. Decrease Voltage ON GSYN Synchr. Decrease Voltage OFF GSYN Synchr. Increase Frequency ON © Arcteq Relays Ltd IM00001...

  • Page 358: Analog Input Scaling Curves

    39: RTD S16 Resistance 40: mA In 1 (I card 1) 41: mA In 2 (I card 2) Curve 1...4 input 0: No 0: No Enables calculation of the average of received signal. signal filtering 1: Yes © Arcteq Relays Ltd IM00001...
  • Page 359 2: Integer point (Ceiling) 3: Integer (Nearest) 0.000 Input value 1 0...4000 The measured input value at Curve Point 1. Scaled output 0.000 Scales the measured milliampere signal at Point 1..10 value 1 © Arcteq Relays Ltd IM00001...

  • Page 360: Logical Outputs

    Table. 5.5.11 - 288. Logical output user description. Name Range Default Description User editable 1...31 Logical Description of the logical output. This description is used in several menu description LOx characters output x types for easier identification. © Arcteq Relays Ltd IM00001...

  • Page 361: Logical Inputs

    Figure. 5.5.12 - 187. Extending a logical input pulse. Logical input descriptions Logical inputs can be given a description. The user defined description are displayed in most of the menus (logic editor, matrix, block settings etc.). © Arcteq Relays Ltd IM00001...

  • Page 362: Monitoring Functions

    The operational logic consists of the following: • input magnitude processing • threshold comparator • block signal check • time delay characteristics • output processing. The following conditions have to met simultaneously for the function alarm to activate: © Arcteq Relays Ltd IM00001...
  • Page 363 The time stamp resolution is 1 ms. The function also provides a resettable cumulative counter for the CTS ALARM and BLOCKED events. The following figure presents a simplified function block diagram of the current transformer supervision function. © Arcteq Relays Ltd IM00001...
  • Page 364 Signal Description Time base IL1RMS RMS measurement of phase L1 (A) current IL2RMS RMS measurement of phase L2 (B) current IL3RMS RMS measurement of phase L3 (C) current I01RMS RMS measurement of residual input I01 © Arcteq Relays Ltd IM00001...
  • Page 365 The reset ratio of 97 % and 103% are built into the function and is always relative to the value. The setting value is common for all measured amplitudes, and when the I exceeds the value (in single, dual or all currents) it triggers the pick-up operation of the function. © Arcteq Relays Ltd IM00001...
  • Page 366 -360.00...360.00 0.01 Displays the natural unbalance of angle after compensating it Natural unbalance ang with Compensate natural unbalance parameter. Measured current 0.01 0.00...50.00 xIn Current difference between summed phases and residual current. difference Isum, I0 © Arcteq Relays Ltd IM00001...
  • Page 367 "General properties of a protection function" and its section "Operating time characteristics for trip and reset". Typical cases of current transformer supervision The following nine examples present some typical cases of the current transformer supervision and their setting effects. © Arcteq Relays Ltd IM00001...
  • Page 368 Figure. 5.6.1 - 191. Secondary circuit fault in phase L1 wiring. When a fault is detected and all conditions are met, the CTS timer starts counting. If the situation continues until the set time has passed, the function issues an alarm. © Arcteq Relays Ltd IM00001...
  • Page 369 If any of the phases exceed the I high limit setting, the operation of the function is not activated. This behavior is applied to short-circuits and earth faults even when the fault current exceeds the I high limit setting. © Arcteq Relays Ltd IM00001...
  • Page 370 Figure. 5.6.1 - 195. Normal situation, residual current also measured. When the residual condition is added with the "I0 input selection", the sum of the current and the residual current are compared against each other to verify the wiring condition. © Arcteq Relays Ltd IM00001...
  • Page 371 Figure. 5.6.1 - 197. Broken primary phase current wiring. In this example, all other condition are met except the residual difference. That is now 0 × I , which indicates a primary side fault. © Arcteq Relays Ltd IM00001...
  • Page 372 The function registers its operation into the last twelve (12) time-stamped registers; this information is available for all provided instances separately. The register of the function records the ON event process data for ACTIVATED, BLOCKED, etc. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 373: Voltage Transformer Supervision (60)

    1 ms. The function also provides a resettable cumulative counter for the START, ALARM BUS, ALARM LINE and BLOCKED events. Figure. 5.6.2 - 199. Secondary circuit fault in phase L1 wiring. The following figure presents a simplified function block diagram of the voltage transformer supervision function. © Arcteq Relays Ltd IM00001...
  • Page 374 RMS measurement of voltage U RMS measurement of voltage U Positive sequence voltage Negative sequence voltage Zero sequence voltage Angle of U voltage Angle of U voltage Angle of U voltage Angle of U voltage Angle of U voltage © Arcteq Relays Ltd IM00001...
  • Page 375 The voltage transformer supervision can also report several different states of the measured voltage. These can be seen in the function's INFO menu. © Arcteq Relays Ltd IM00001...
  • Page 376 The blocking of the function causes an HMI display event and a time-stamped blocking event with information of the startup voltage values and its fault type to be issued. © Arcteq Relays Ltd IM00001...
  • Page 377 Event 1: Voltage OK 2: Bus live, VTS Setting group 0.00...360.00deg alarm hh:mm:ss.mss name 2: Low OK, Seq. reversed 1...8 active voltage 3: Bus live, VTS 0...1800s OK, Seq. undefined 4: Bus live, VTS fault © Arcteq Relays Ltd IM00001...

  • Page 378: Circuit Breaker Wear

    "Open" operations as well as the ALARM 1 and ALARM 2 events. The function can also monitor the operations left for each phase. The following figure presents a simplified function block diagram of the circuit breaker wear function. © Arcteq Relays Ltd IM00001...
  • Page 379 The circuit breaker characteristics are set by two operating points, defined by the nominal breaking current, the maximum allowed breaking current and their respective operation settings. This data is provided by the circuit breaker's manufacturer. © Arcteq Relays Ltd IM00001...
  • Page 380 Let us examine the settings, using a low-duty vacuum circuit breaker as an example. The image below presents the technical specifications provided by the manufacturer, with the data relevant to our settings highlighted in red: © Arcteq Relays Ltd IM00001...
  • Page 381 With these settings, Alarm 1 is issued when the cumulative interruption counter for any of the three phases dips below the set 1000 remaining operations ("Alarm 1 Set"). Similarly, when any of the counters dips below 100 remaining operations, Alarm 2 is issued. © Arcteq Relays Ltd IM00001...
  • Page 382 CBWEAR1 Alarm 2 OFF The function registers its operation into the last twelve (12) time-stamped registers. The register of the function records the ON event process data. The table below presents the structure of the function's register content. © Arcteq Relays Ltd IM00001...

  • Page 383: Current Total Harmonic Distortion (Thd)

    (8) separate setting groups which can be selected from one common source. The operational logic consists of the following: • input magnitude processing • threshold comparator • block signal chec • time delay characteristics • output processing. The inputs of the function are the following: © Arcteq Relays Ltd IM00001...
  • Page 384 The selection of the calculation method is made with a setting parameter (common for all measurement channels). General settings The following general settings define the general behavior of the function. These settings are static i.e. it is not possible to change them by editing the setting group. © Arcteq Relays Ltd IM00001...
  • Page 385 The relay's Info page displays useful, real-time information on the state of the protection function. It is accessed either through the relay's HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. © Arcteq Relays Ltd IM00001...
  • Page 386 Defines the delay for the alarm timer from the residual current 0.000…1800.000s 0.005s 10.000s delay I01's measured THD. I02 THD alarm Defines the delay for the alarm timer from the residual current 0.000…1800.000s 0.005s 10.000s delay I02's measured THD. © Arcteq Relays Ltd IM00001...

  • Page 387: Voltage Total Harmonic Distortion (Thd)

    The function's monitoring of the voltage can be used to alarm of the harmonic content rising too high; this can occur when there is an electric quality requirement in the protected unit, or when the harmonics generated by the process need to be monitored. © Arcteq Relays Ltd IM00001...
  • Page 388 The time stamp resolution is 1 ms. The function also provides a resettable cumulative counter for the START, ALARM and BLOCKED events. The following figure presents a simplified function block diagram of the total harmonic distortion monitor function. © Arcteq Relays Ltd IM00001...
  • Page 389 This parameter is visible only when Allow setting of individual LN mode is 4: Test/ enabled in General menu. Blocked 5: Off Measurement Amplitude Defines which available measured magnitude the function uses. magnitude Amplitude 2: Power © Arcteq Relays Ltd IM00001...
  • Page 390 The blocking of the function causes an HMI display event and a time-stamped blocking event with information of the startup current values and its fault type to be issued. © Arcteq Relays Ltd IM00001...

  • Page 391: Disturbance Recorder (Dr)

    The maximum sample rate of the recorder's analog channels is 64 samples per cycle. The recorder also supports 95 digital channels simultaneously with the twenty (20) measured analog channels. Maximum capacity of recordings is 100. © Arcteq Relays Ltd IM00001...
  • Page 392 Voltage measurement module voltage supply supervision (VT card 2) Phase current I (CT card 3) IL1''' IL2''' Phase current I (CT card 3) Phase current I (CT card 3) IL3''' Residual current I coarse* (CT card 3) I01'''c © Arcteq Relays Ltd IM00001...
  • Page 393 Pha.Lx pow. THD Phase Lx power THD (L1, L2, L3) calc.I0 Calculated I0 Res.I0x ampl. THD Residual I0x amplitude THD (I01, I02) calc.I0 Pha.angle Calculated I0 phase angle Res.I0x pow. THD Residual I0x power THD (I01, I02) © Arcteq Relays Ltd IM00001...
  • Page 394 Current Pri. (IL1, IL2, IL3) Current Sec. (I01, I02) ILx Reactive Primary reactive current ILx I0x Residual Reactive Secondary residual reactive current I0x Current Pri. (IL1, IL2, IL3) Current Sec. (I01, I02) Power, GYB, frequency © Arcteq Relays Ltd IM00001...
  • Page 395 Internal Relay Fault active front panel are pressed. is active. buttons Status (Protection, control and (see the individual function description for PushButton x Status of Push Button 1...12 is ON monitoring event signals) the specific outputs) © Arcteq Relays Ltd IM00001...
  • Page 396 Manual 0: - Triggers disturbance recording manually. This parameter will return 0: - trigger 1: Trig back to "-" automatically. Clear all 0: - 0: - Clears all disturbance recordings. records 1: Clear © Arcteq Relays Ltd IM00001...
  • Page 397 Sets the recording length before the trigger. time 0…8 freely Selects the analog channel for recording. Please see the list of all Analog recording selectable available analog channels in the section titled "Analog and digital CH1...CH20 channels recording channels". © Arcteq Relays Ltd IM00001...
  • Page 398 For example, let us say the nominal frequency is 50 Hz, the selected sample rate is 64 s/c, nine (9) analog channels and two (2) digital channels record. The calculation is as follows: Therefore, the maximum recording length in our example is approximately 496 seconds. © Arcteq Relays Ltd IM00001...
  • Page 399 The recorder is configured by using the setting tool software or relay HMI, and the results are analyzed with the AQviewer software (is automatically downloaded and installed with AQtivate). Registered users can download the latest tools from the Arcteq website (arcteq.fi./downloads/).
  • Page 400 → DR path . The user can also launch the AQviewer software from the Disturbance recorder menu. AQviewer software instructions can be found in AQtivate 200 Instruction manual (arcteq.fi./downloads/). Events The disturbance recorder function (abbreviated "DR" in event block names) generates events and registers from the status changes of the function: the recorder generates an event each time it is triggered (manually or by dedicated signals).

  • Page 401: Measurement Recorder

    The setting tool estimates the maximum recording time, which depends on the recording interval. When the measurement recorder is running, the measurements can be viewed in graph form with the AQtivate PRO software (see the image below). © Arcteq Relays Ltd IM00001...
  • Page 402 U4Volt Pri L2 Exp.React.Ind.E.Mvarh Sec.Pha.Curr.IL3 U1Volt Pri TRMS L2 Exp.React.Ind.E.kvarh Sec.Res.Curr.I01 U2Volt Pri TRMS L2 Imp.React.Ind.E.Mvarh Sec.Res.Curr.I02 U3Volt Pri TRMS L2 Imp.React.Ind.E.kvarh Sec.Calc.I0 U4Volt Pri TRMS L2 Exp/Imp React.Ind.E.bal.Mvarh Pha.Curr.IL1 TRMS Sec Pos.Seq.Volt.Pri L2 Exp/Imp React.Ind.E.bal.kvarh © Arcteq Relays Ltd IM00001...
  • Page 403 Pha.angle IL1 System Volt UL31 mag (kV) Other mea Other measur surements ements Pha.angle IL2 System Volt UL1 mag TM> Trip expect mode Pha.angle IL3 System Volt UL1 mag (kV) TM> Time to 100% T © Arcteq Relays Ltd IM00001...
  • Page 404 L2 Tan(phi) L1 Diff current Pha.Curr.I”L2 L2 Cos(phi) L1 Char current Pha.Curr.I”L3 L3 Apparent Power (S) L2 Bias current Res.Curr.I”01 L3 Active Power (P) L2 Diff current Res.Curr.I”02 L3 Reactive Power (Q) L2 Char current © Arcteq Relays Ltd IM00001...

  • Page 405: Measurement Value Recorder

    • Idir> (directional overcurrent) • I0> (non-directional earth fault) • I0dir> (directional earth fault) • f<(underfrequency) • f> (overfrequency) • U< (undervoltage) • U> (overvoltage) • U1/U2 >/< (sequence voltage) • U0> (residual voltage) • P> (over power) © Arcteq Relays Ltd IM00001...
  • Page 406 The three-phase apparent, active and reactive powers. SL1, SL2, SL3, PL1, PL2, PL3, The phase apparent, active and reactive powers. QL1, QL2, QL3 tanfi3PH, tanfiL1, tanfiL2, tanfiL3 The tan (φ) of three-phase powers and phase powers. © Arcteq Relays Ltd IM00001...
  • Page 407 Reported values When triggered, the function holds the recorded values of up to eight channels, as set. In addition to this tripped stage, the overcurrent fault type and the voltage fault types are reported to SCADA. © Arcteq Relays Ltd IM00001...
  • Page 408 45: U0> Trip 46: U0>> Trip 47: U0>>> Trip 48: U0>>>> Trip 0: - 1: A-G 2: B-G 3: A-B Overcurrent fault type The overcurrent fault type. 4: C-G 5: A-C 6: B-C 7: A-B-C © Arcteq Relays Ltd IM00001...

  • Page 409: Running Hour Counter

    This value can be edited by the user. The user input must be set in seconds, which is then converted by the device to hours, minutes and seconds (hh:mm:ss). Start 0...4294967295 Start counter. count Starts Start Clear 0: - Clears "Running hours" and "Start count". hours 1: Clear © Arcteq Relays Ltd IM00001...

  • Page 410: Programmable Stage (Pgx>/<; 99)

    1 ms. The function also provides a resettable cumulative counter for the START, TRIP and BLOCKED events. General settings The following general settings define the general behavior of the function. These settings are static i.e. it is not possible to change them by editing the setting group. © Arcteq Relays Ltd IM00001...
  • Page 411 Signals 1 OR 2 AND 3 need to fulfill the pick-up condition. Each Mag2) AND signal has their own pick-up setting. Mag3 0: Currents 1: Voltages 2: Powers PSx Magnitude selection Defines the measurement type used by the stage 3: Impedances and admittances 4: Others © Arcteq Relays Ltd IM00001...
  • Page 412 Angle of negative sequence current (degrees) I01ResP I01 primary current of a current-resistive component I01CapP I01 primary current of a current-capacitive component I01ResS I01 secondary current of a current-resistive component I01CapS I01 secondary current of a current-capacitive component © Arcteq Relays Ltd IM00001...
  • Page 413 Phase active power L1 / L2 / L3 P (kW) Phase reactive power L1 / L2 / L3 Q (kVar) tanfiLx Phase active power direction L1 / L2 / L3 cosfiLx Phase reactive power direction L1 / L2 / L3 © Arcteq Relays Ltd IM00001...
  • Page 414 Description G0Pri Conductance G0 primary (mS) B0Pri Susceptance B0 primary (mS) G0Sec Conductance G0 secondary (mS) B0Sec Susceptance B0 secondary (mS) Y0Pri Admittance Y0 primary (mS) Y0Sec Admittance Y0 secondary (mS) Y0Angle Admittance Y0 angle © Arcteq Relays Ltd IM00001...
  • Page 415 4: Test/Blocked enabled in General menu. 5: Off 0: Normal 1: Start Condition Displays status of the function. 2: Trip 3: Blocked Expected operating time -1800.000...1800.000s Displays the expected operating time when a fault occurs. © Arcteq Relays Ltd IM00001...
  • Page 416 Table. 5.7 - 348. Comparator modes Mode Description G G r r ea eat t er than er than. If the measured signal is greater than the set pick-up level, the comparison 0: Over > condition is fulfilled. © Arcteq Relays Ltd IM00001...
  • Page 417 START, TRIP, and BLOCKED. The user can select which event messages are stored in the main event buffer: ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. © Arcteq Relays Ltd IM00001...
  • Page 418 PS5 >/< Block ON PGS1 PS5 >/< Block OFF PGS1 reserved PGS1 reserved PGS1 PS6 >/< Start ON PGS1 PS6 >/< Start OFF PGS1 PS6 >/< Trip ON PGS1 PS6 >/< Trip OFF PGS1 PS6 >/< Block ON © Arcteq Relays Ltd IM00001...
  • Page 419 Date and time Event >/< Mag# Mag#/Set# Used SG remaining dd.mm.yyyy Event The numerical value of Ratio between the measured Setting group 0 ms...1800s hh:mm:ss.mss name the magnitude magnitude and the pick-up setting 1...8 active © Arcteq Relays Ltd IM00001...

  • Page 420: Genera Or Commander Applica A Tion Tion

    6 Generator commander application 6.1 General The Generator commander consists of two hardware equipments: the AQ-G257 IED and the AQ- GC30 IGBT rectifier bridge. The AQ-G257 IED can be equipped with several I/O units, from current and voltage measurement to analog and digital I/Os as well as RTDs.

  • Page 421: Functions Of The Generator Commander

    • Temperature: 0…150 °C 6.1.1 Functions of the Generator commander The diagram below presents all the main functions in the Generator commander. The excitation functions are described in detail in the following chapters, and a more detailed description of the protection functions can be found in the chapter titled "Functions"...

  • Page 422: Exciter Unit Dimensions

    Genera Generat t or Commander or Commander Instruction manual Version: 2.07 6.1.3 Exciter unit dimensions Figure. 6.1.3 - 211. Exciter unit – side view. © Arcteq Relays Ltd IM00001...

  • Page 423: Exciter Unit Connections

    Table. 6.1.4 - 351. Connector descriptions. Connector Description X1:1 Power supply - connector X1:2 Power supply + connector X1:3 Voltage input (0…10 V) X1:4 Earth for the voltage input and the mA input X1:5 mA input © Arcteq Relays Ltd IM00001...

  • Page 424: Function Descriptions

    "Activated" in order for the user to have access to nearly all Field data and Power circuit parameters. General settings Table. 6.2.1.1 - 352. General settings. Name Range Step Default Description Excitation 0: Disabled Activates and disables the Generator commander's excitation 0: Disabled control mode 1: Activated module. © Arcteq Relays Ltd IM00001...
  • Page 425 Version: 2.07 Name Range Step Default Description Commands 0: Disabled Indicates whether the Generator commander is connected to or to rectifier 0: Disabled 1: Enabled disconnected from the rectifier bridge(s). bridge(s) VLAN- PRIORITY Defines the virtual LAN priority channel for communication with the 0…7...
  • Page 426 ( General → Device info → "Enable stage forcing")! voltage on 11: IGBT shorted on 12: PWM enabled 13: Rectifier trip 14: Bridge 1 temp high 15: Bridge 2 temp high 16: Excitation 17: Excitation Overcurrent © Arcteq Relays Ltd IM00001...
  • Page 427 18: FCR Bus 19: MVAR Bus On 20: PF Bus Overriding control on 22: AVR Ref on Low limit 23: AVR Ref on High limit 24: FCR ref on Low limit 25: FCR ref on High limit © Arcteq Relays Ltd IM00001...
  • Page 428 23: Unload MVAR 24: MVAR mode on 25: PF mode Table. 6.2.1.1 - 353. Generator parameters (GEN). Name Range Step Default Description Generator nominal 0.001…500.000MVA 0.001MVA 5.000MVA Determines the generator's nominal apparent power. MVA (S) © Arcteq Relays Ltd IM00001...
  • Page 429 0.01V (AC) Displays the rated supply voltage to the rectifier. voltage to (AC) (AC) rectifier 0: Three-phase Power Three- AC supply Selects the number of power supply phases. supply phase 1: Single-phase phases AC supply supply © Arcteq Relays Ltd IM00001...

  • Page 430: Voltage Supervision

    Range Step Default Description Rated back-up 220V The Generator commander can have a back-up voltage connected supply 1…400V (DC) 1V (DC) (DC) to it. This parameter defines the rated value of that back-up voltage. voltage to Table. 6.2.1.1 - 355. Power circuit parameters (POW).
  • Page 431 Detection Determines the trip time for the field overcurrent 0.000…10.000s 0.005s 3.000s time delay protection. Open field © Arcteq Relays Ltd IM00001...
  • Page 432 If open circuits are monitored and the above- mentioned parameter conditions are met (high threshold > I < low threshold), the Generator commander performs a rectifier trip and stops the excitation after the set time in the "Open field detection time delay"...

  • Page 433: Excitation Control Modes

    12: AVR start Ref bypass AVR reference Displays the value of the AVR reference at the -500.00…500.00p.u./p.u. 0.01p.u./p.u. - moment. Minimum AVR Displays the minimum value allowed for the AVR reference -500.00…500.00p.u./p.u. 0.01p.u./p.u. - reference. allowed © Arcteq Relays Ltd IM00001...
  • Page 434 AVR when it is not synchronized to synchronized a grid. Max AVR Defines the maximum reference value that can reference not 0.00…2.00p.u. 0.01p.u. 1.15p.u. be set for the AVR when it is synchronized to a synchronized grid. © Arcteq Relays Ltd IM00001...

  • Page 435: Field Current Regulator

    When voltage matching is enabled and an input signal for voltage matching is selected, the Enable voltage 0: Disabled 0: Disabled Generator commander matches the generator matching 1: Enabled voltage with the selected voltage matching reference, as defined by the "Voltage matching reference select"...
  • Page 436 Defines the proportional gain for the FCR. (field voltage/field current) Integral gain 0.00…10.00 1/s 0.01 1/s 0.20 1/s Defines the integral gain for the FCR. KiFCR Defines the start-up reference value for the reference on 0.00…2.00p.u. 0.01p.u. 1.00p.u. generator. start © Arcteq Relays Ltd IM00001...

  • Page 437: Reactive Power Controller

    The diagram below presents the IEEE model of a three-step regulator that is used as a reactive power controller and modified with an output for adaptive set point speed V of the AVR control loop. RefAdjSlew © Arcteq Relays Ltd IM00001...
  • Page 438 The control mode is activated by the operator, and de-activated by selecting another control mode or when going into island mode. The reference value can be adjusted locally and remotely. Figure. 6.2.1.3.3 - 217. Generator capability curve. © Arcteq Relays Ltd IM00001...
  • Page 439 Reactive power Enables or disables the reactive power regulator, automatic 0: Disabled 0: Disabled as soon as the Generator commander gets the loading at 1: Enabled “synchronized” signal. synchronizing Defines the reference value for the reactive Automatic power regulator, after synchronizing.

  • Page 440: Power Factor Control

    Figure. 6.2.1.3.4 - 218. IEEE model of power factor controller. The power factor control mode is activated by the operator, and de-activated by selecting another control mode or when going into island mode. The reference value can be adjusted locally and remotely. © Arcteq Relays Ltd IM00001...

  • Page 441: Excitation Limiters

    The limiter has six setting points for the underexcitation curve. The limit is typically set with a value that is 5 % higher than the underexcitation protection. The diagram below depicts the transfer function of the underexcitation limiter (IEEE, type UEL2). © Arcteq Relays Ltd IM00001...
  • Page 442 These parameters define the limits of the reactive P=0.00 p.u. power and the points at which the underexcitation limiter begins to increase the Q-axis excitation. (P = active power.) coordinate at -1.00...1.00 0.01 -0.25 P=0.20 p.u. © Arcteq Relays Ltd IM00001...

  • Page 443: Stator Current Limiter

    4: Active (IP) overcurrent Defines the output of the SCL at the SCL output now -500.00…500.00p.u./p.u. 0.01p.u./p.u. 0.00p.u./p.u. moment. Stator current 0: Disabled Enables and disables the stator current 1: Enabled limiter 1: Enabled limiter. © Arcteq Relays Ltd IM00001...

  • Page 444: Field Current Limiter

    In order to contribute to the stabilization of the power grid during voltage disturbances, the limiter is time-delayed to allow it to overload for a short time. The diagram below depicts the transfer function of the delayed field current limiter. © Arcteq Relays Ltd IM00001...
  • Page 445 0.200 1/s DFCL DFCL. Defines the upper limit for the Upper limit for integrator 0.00...1.00 0.01 0.50 integrator. DFCL inverse time delay (0 Defines the upper limit for the -1.00...0.00 0.01 -0.20 = Instant) integrator. © Arcteq Relays Ltd IM00001...

  • Page 446: V/Hz Limiter

    0: Disabled Power system stabilizer (PSS2B) 0: Disabled 1: Enabled PSS block release time (after ext. block released) 6.000…180.000s 0.005s 6.000s PSS output signal to AVR control -5000.000…5000.000p.u. 0.001p.u. 0.000p.u. KS1 PSS gain 0.00...25.00 0.01 0.00 © Arcteq Relays Ltd IM00001...

  • Page 447: Excitation I/O

    (list of various inputs and outputs) Defines an external source that blocks the PSS. (1=blocked.) 6.2.2 Excitation I/O The inputs and outputs of the Generator commander are categorized as follows: • Direct output control • DI inputs to excitation • PP inputs to excitation •...

  • Page 448: Direct Output Control

    Genera Generat t or Commander or Commander Instruction manual Version: 2.07 6.2.2.1 Direct output control Table. 6.2.2.1 - 368. Generator commander output signals. Output signal name Description GMAG Field current limiter The delayed field current limiter is running. active GMAG Under excitation The underexcitation limiter is running.
  • Page 449 GMAG Low Q error hysteresis level. GMAG AVR reference on The AVR reference value is on the low limit. low limit GMAG AVR reference on The AVR reference value is on the high limit. high limit © Arcteq Relays Ltd IM00001...
  • Page 450 GMAG VHZ limit active The V/Hz limiter is running. GMAG ProcessPanel The Generator commander's control mode is "GMAG ProcessPanel activated" which means activated that the Commander is controlled locally via the IED's front panel. GMAG Parameters The Commander control mode is "GMAG Parameters (DI) activated" which means that the activated Commander is controlled locally via the IED's digital inputs.

  • Page 451: Di Inputs To Excitation

    This input is read only when the "Control mode" parameter under the "Local control" tab is set to "DI control". This input is used to close the field breaker. Close FB This input is read only when the "Control mode" parameter under the "Local control" tab is set to "DI command control". © Arcteq Relays Ltd IM00001...
  • Page 452 This input is used to quickly increase the FCR reference value during the motor start sequence. FCR starting ramp) Block process panel and remote This input is used to block the process panel and remote control, for example during a motor start. control © Arcteq Relays Ltd IM00001...

  • Page 453: Pp Inputs To Excitation

    Please note that in all the tables below "A" refers to a local bridge and "B" to a remote bridge. This also applies to the parameter names and menu/submenu/tab names in the AQtivate configuration and setting tool. © Arcteq Relays Ltd IM00001...
  • Page 454 System Indicates that the hardware system of the local/remote bridge is OK. system OK Failing System Bridge A/B Indicates that the Generator commander has established a System communication OK communication connection to the local/remote bridge. Failing System Bridge A/B health System Indicates that the health status of the local/remote bridge is OK.
  • Page 455 Displays the DC link current filtered measurement value of Bridge A/B DC link 0.000…500.000A 0.001A the local/remote bridge. This current is the excitation current (filtered) current. Bridge A/B supply 0.0…500.0V 0.1V Defines the supply voltage of the local/remote bridge. voltage © Arcteq Relays Ltd IM00001...

  • Page 456: Active Control Status

    1: Standby use" parameter is set to "Redundant". Indicates the commander status. Remote commander 0: Failing status 1: OK This setting is only visible when the "Commanders in use" parameter is set to "Redundant". © Arcteq Relays Ltd IM00001...
  • Page 457 1: On Active bridge 0.000…20.000mA 0.001mA - Displays the current measurement value of the active bridge. mA input value Active bridge U 0.000…10.000V 0.001V Displays the U input measurement value of the active bridge. input value © Arcteq Relays Ltd IM00001...

  • Page 458: Remote And Local Control

    "Bridge A/B HW system OK" under the "Bridge I/O" tab. bridge 0: Off 1: On When DO2 is ON, the Generator commander has established a communication connection to the selected bridge. See also the parameter "Bridge A/B communication OK" under the "Bridge I/O" tab. (a long list of...
  • Page 459 (remote) Selects whether or not the user can remotely set AVR speed 0: Off 0: Off the generator to 90 % of its nominal speed, thus 90 (remote) 1: On allowing for magnetization to begin. © Arcteq Relays Ltd IM00001...
  • Page 460 0: Off 1: On be closed remotely and indicated as such. (remote) Island mode 0: Off Selects whether or not the Generator commander 0: Off (remote) 1: On can be set to Island mode remotely. Command voltage 0: Off...

  • Page 461: Excitation Internal Parameters

    Defines the delay time for entering the island mode. Island operation Filter time for Defines the filter time for calculation of frequency calculation of 0.000…1800.000s 0.005s 0.500s derivative; used to detect the disturbed mode. frequency derivative © Arcteq Relays Ltd IM00001...
  • Page 462 FCR reference follow 0.005…50.000s 0.005s 0.010s For example, if the mode change takes place at filter T constant 13:01:22.456 and this parameter has been set to "1.000 s", the follow filter reference is fetched from 13:01:21.456. © Arcteq Relays Ltd IM00001...
  • Page 463 Displays the conductance measurement. (internal GMAG) Displays the additional compensation from IpIq compensation –500.00…500.00 0.01 –50.00 active and apparent powers for voltage control. Displays the bridge control signal of the power PWM control signal –500.00…500.00 0.01 –50.00 measurement. © Arcteq Relays Ltd IM00001...
  • Page 464 –500.00…500.00 0.01 –50.00 remotely via the bus. Displays the power factor reference value given PF ref bus –500.00…500.00 0.01 –50.00 remotely via the bus. Step test –500.00…500.00 0.01 –50.00 Displays the step response reference value. © Arcteq Relays Ltd IM00001...

  • Page 465: Events Recorded By The Generator Commander

    –500.000…50 Dislays the measured value of the PF control PF measured atm. 0.001 –50.00 000.000 mode at the moment. 6.2.5 Events recorded by the Generator commander Table. 6.2.5 - 384. Excitation events. Event block Event Event name Description name code...
  • Page 466 High temperature on Bridge 2 is OFF. bridge 2 OFF Control GMAG Excitation ON Excitation is running. EventMaskHi Exc On Cmd GMAG The excitation "Run" command is OFF. GMAG Excitation OFF Excitation is not running. © Arcteq Relays Ltd IM00001...
  • Page 467 The field breaker is open OFF. FB is closed GMAG1 The field breaker is closed ON. FB is closed GMAG1 The field breaker is closed OFF. Field flashing GMAG1 Field flashing is ON. Field flashing GMAG1 Field flashing is OFF. © Arcteq Relays Ltd IM00001...
  • Page 468 FCR bus ON the remote bus. EventMaskMid The FCR command is OFF, controlled through GMAG1 FCR bus OFF the remote bus. The MVAR command is ON, controlled through GMAG1 MVar Bus On the remote bus. © Arcteq Relays Ltd IM00001...
  • Page 469 The V/Hz limiter is running. active ON VHZ limit GMAG1 The V/Hz limiter is not running. active OFF The Generator commander's control Process panel mode "GMAG ProcessPanel activated" is ON, GMAG1 activated ON i.e. the device is controlled through the process panel.
  • Page 470 Instruction manual Version: 2.07 Event block Event Event name Description name code The Generator commander's control mode Parameters GMAG1 "GMAG Parameters (DI) activated" is ON, i.e. active ON the device is controlled through digital inputs. Parameters The Generator commander's control mode...
  • Page 471 The bridge's digital output 3 is OFF. GMAG2 PWM DO4 ON The bridge's digital output 4 is ON. PWM DO4 GMAG2 The bridge's digital output 4 is OFF. MVar mode GMAG2 The MVar mode is ON. © Arcteq Relays Ltd IM00001...

  • Page 472: Other Control Functions

    When the test function is activated, either locally or remotely, an open loop controller is activated. The output of the power rectifier can be controlled by "Increase" and "Decrease" commands. The other control loops goes into a follow-up mode, which enables a seamless transfer whenever the test mode is deactivated. © Arcteq Relays Ltd IM00001...

  • Page 473: Redundancy

    • DC field voltage • Control signal • PSS signal Their update time is 10 ms. Trending is done by a separate PC software tool, and it is primarily intended for tuning the control loops. © Arcteq Relays Ltd IM00001...

  • Page 474: Sy Y St Stem Int 7 S Em Integra Egration Tion

    In these cases without GPS synchronized clock source, the accuracy between the devices is still high. Settings Select PTP as the time synchronization source from Communication → Synchronization → General menu. The following settings are available in Communication → Synchronization → PTP menu. © Arcteq Relays Ltd IM00001...

  • Page 475: Modbus/Tcp And Modbus/Rtu

    1. Some masters might begin numbering holding register from 0 instead of 1; this will cause an offset of 1 between the relay and the master. Modbus map can be edited with Modbus Configurator ( Tools → Communication → Modbus Configurator ). © Arcteq Relays Ltd IM00001...

  • Page 476: Modbus I/O

    "0", the selected module is not in use. Module x 0: ADAM-4018+ Selects the module type. type 1: ADAM-4015 Channel Channels in 0…Channel 7 (or Selects the number of channels to be used by the module. None) © Arcteq Relays Ltd IM00001...

  • Page 477: Iec 61850

    AQ-25x frame units support both Edition 1 and 2 of IEC61850. The following services are supported by IEC 61850 in Arcteq devices: • Up to six data sets (predefined data sets can be edited with the IEC 61850 tool in AQtivate) •...
  • Page 478 0: All Determines which ports can use GOOSE communication. 2: Double ethernet card For more information on the IEC 61850 communication protocol support, please refer to the conformance statement documents (www.arcteq.fi/downloads/ → AQ-200 series → Resources). © Arcteq Relays Ltd IM00001...

  • Page 479: Goose

    Version: 2.07 7.1.6 GOOSE Arcteq relays support both GOOSE publisher and GOOSE subscriber. GOOSE subscriber is enabled with the "GOOSE subscriber enable" parameter at Communication → Protocols → IEC 61850/ GOOSE. The GOOSE inputs are configured using either the local HMI or the AQtivate software.
  • Page 480 The configuration of the GOOSE publisher is done using the IEC 61850 tool in AQtivate ( Tools → Communication → IEC 61850 ). Refer to AQtivate-200 Instruction manual for more information on how to set up GOOSE publisher. © Arcteq Relays Ltd IM00001...

  • Page 481: Iec 103

    (slave) station. The IEC 103 protocol can be selected for the serial ports that are available in the device. A primary (master) station can then communicate with the Arcteq device and receive information by polling from the slave device. The transfer of disturbance recordings is not supported.
  • Page 482 Determines the data reporting deadband settings for this Power factor deadband 0.01…0.99 0.01 0.05 measurement. Determines the data reporting deadband settings for this Frequency deadband 0.01…1.00Hz 0.01Hz 0.1Hz measurement. Determines the data reporting deadband settings for this Current deadband 0.01…50.00A 0.01A measurement. © Arcteq Relays Ltd IM00001...

  • Page 483: Iec 101/104

    Enabled 0…65 IP port 2404 Defines the IP port used by the protocol. Common 0…65 Defines the common address of the application service data unit (ASDU) for address of ASDU the IEC 104 communication protocol. © Arcteq Relays Ltd IM00001...
  • Page 484 0.1…1000.0kVA 0.1kVA 2kVA power deadband measurement. Determines the data reporting deadband settings for this Power factor deadband 0.01…0.99 0.01 0.05 measurement. Determines the data reporting deadband settings for this Frequency deadband 0.01…1.00Hz 0.01Hz 0.1Hz measurement. © Arcteq Relays Ltd IM00001...

  • Page 485: Spa

    25…28: I0>, I0>>, I0>>>, The user can choose between non-directional overcurrent, in use source I0>>>> (I0) directional overcurrent, non-directional earth fault, directional 29…32: earth fault, and fault locator functions. I0d>, I0d>>, I0d>>>, I0d>>>> (I0) 33: FLX © Arcteq Relays Ltd IM00001...

  • Page 486: Real-Time Measurements To Communication

    U1 Pos.seq V Ang, U2 Neg.seq V Ang Positive and negative sequence angles. Powers S3PH P3PH Three-phase apparent, active and reactive power. Q3PH SL1, SL2, SL3, PL1, PL2, PL3, Phase apparent, active and reactive powers. QL1, QL2, QL3 © Arcteq Relays Ltd IM00001...
  • Page 487 0: No values to primary 1: Yes primary. 0: Currents 1: Voltages Slot X magnitude 2: Powers Selects the measured magnitude catecory of the selection 3: Impedance (ZRX) and Currents chosen slot. admittance (YGB) 4: Others © Arcteq Relays Ltd IM00001...

  • Page 488: Modbus Gateway

    Any AQ-250 device can be setup as a Modbus Gateway (i.e. master). Modbus Gateway device can import messages (measurements, status signals etc.) from external Arcteq and third-party devices. RS-485 serial communication port. Up to 32 sub units can be connected to an AQ-200 master unit.
  • Page 489 The Modbus Gateway generates events the status changes in imported bits and double bits. The user can select which event messages are stored in the main event buffer: ON, OFF, or both. Table. 7.4 - 411. Event messages Event block name Event names MGWB1 Bit 1...Bit 32 (ON, OFF) © Arcteq Relays Ltd IM00001...
  • Page 490 Bit 33...Bit 64 (ON, OFF) MGWB3 Bit 65...Bit 96 (ON, OFF) MGWB4 Bit 97...Bit 128 (ON, OFF) MGWD1 Double Bit 1... Double bit 16 (ON/ON, OFF/OFF, ON/OFF, OFF/ON) MGWD2 Double Bit 17... Double bit 32 (ON/ON, OFF/OFF, ON/OFF, OFF/ON) © Arcteq Relays Ltd IM00001...

  • Page 491: Connections And Applica A Tion Examples

    Genera Generat t or Commander or Commander Instruction manual Version: 2.07 8 Connections and application examples 8.1 Connections of AQ-G257 Figure. 8.1 - 225. AQ-G257 variant without add-on modules. © Arcteq Relays Ltd IM00001...
  • Page 492 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 8.1 - 226. AQ-G257 variant with digital input and output modules. © Arcteq Relays Ltd IM00001...

  • Page 493: Application Examples And Their Connections

    Since three line-to-neutral voltages are connected, this application uses the voltage measurement mode "3LN" (see the image below). Additionally, both of the current transformers have the three phase currents connected; the first CT also has the residual current (I01) connected. © Arcteq Relays Ltd IM00001...
  • Page 494 Since three line-to-neutral voltages are connected, this application uses the voltage measurement mode "3LN" (see the image below). Additionally, both of the current transformers have the three phase currents connected; however, neither of the CTs has the residual current connected. © Arcteq Relays Ltd IM00001...

  • Page 495: Two-Phase, Three-Wire Aron Input Connection

    This chapter presents the two-phase, three-wire ARON input connection for any AQ-200 series IED with a current transformer. The example is for applications with protection CTs for just two phases. The connection is suitable for both motor and feeder applications. © Arcteq Relays Ltd IM00001...

  • Page 496: Trip Circuit Supervision (95)

    (52b) even after the circuit breaker is opened. This requires a resistor which reduces the current: this way the coil is not energized and the relay output does not need to cut off the coil's inductive current. © Arcteq Relays Ltd IM00001...
  • Page 497 Non-latched outputs are seen as hollow circles in the output matrix, whereas latched contacts are painted. See the image below of an output matrix where a non-latched trip contact is used to open the circuit breaker. © Arcteq Relays Ltd IM00001...
  • Page 498 There is one main difference between non-latched and latched control in trip circuit supervision: when using the latched control, the trip circuit (in an open state) cannot be monitored as the digital input is shorted by the IED's trip output. © Arcteq Relays Ltd IM00001...
  • Page 499 Logical output can be used in the output matrix or in SCADA as the user wants. The image below presents a block scheme when a non-latched trip output is not used. © Arcteq Relays Ltd IM00001...
  • Page 500 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 8.4 - 235. Example block scheme. © Arcteq Relays Ltd IM00001...

  • Page 501: Construction And Installation Tion

    The images below present the modules of both the non-optioned model (AQ- X257-XXXXXXX-AAAAAAAAA AAAAAAAAA) and the fully optioned model (AQ-X257-XXXXXXX-BBBCCCCC BBBCCCCCJ J ). Figure. 9.1 - 236. Modular construction of AQ-X257-XXXXXXX-AAAAAAAAA © Arcteq Relays Ltd IM00001...
  • Page 502 In field upgrades, therefore, the add-on module must be ordered from Arcteq Relays Ltd. or its representative who can then provide the module with its corresponding unlocking code to allow the device to operate correctly once the hardware configuration has been upgraded.
  • Page 503 P215-PH0AAAA-BBC) matches with the existing modules in the device. If the code and the modules do not match, the device issues and alarm. An alarm is also issued if the device expects to find a module here but does not find one. © Arcteq Relays Ltd IM00001...

  • Page 504: Cpu Module

    Slots I…M in groups of five. Slot N has a double (LC) fiber Ethernet communication option card installed. These same principles apply to all non-standard configurations in the AQ-X257 IED family. 9.2 CPU module Figure. 9.2 - 239. CPU module. © Arcteq Relays Ltd IM00001...
  • Page 505 Selects whether the status of the digital input is 1 or 0 when the input DIx Polarity 0: NO 1: NC (Normally is energized. closed) DIx Activation 0.000…1800.000 0.001 0.000 s Defines the delay for the status change from 0 to 1. delay © Arcteq Relays Ltd IM00001...

  • Page 506: Current Measurement Module

    The mechanical delay of the relay is no not t included in these approximations! 9.3 Current measurement module Figure. 9.3 - 240. Module connections with standard and ring lug terminals. Connector Description CTM 1-2 Phase current measurement for phase L1 (A). © Arcteq Relays Ltd IM00001...

  • Page 507: Voltage Measurement Module

    For further details please refer to the "Current measurement" chapter in the “Technical data” section of this document. 9.4 Voltage measurement module Figure. 9.4 - 241. Voltage measurement module. Connector Description VTM 1-2 Configurable voltage measurement input U1. © Arcteq Relays Ltd IM00001...

  • Page 508: Digital Input Module (Optional)

    Figure. 9.5 - 242. Digital input module (DI8) with eight add-on digital inputs. Description (x = the number of digital inputs in other modules that preceed this one in the Connector configuration) DIx + 1 DIx + 2 DIx + 3 © Arcteq Relays Ltd IM00001...
  • Page 509 Selects whether or not a 30-ms deactivation delay is added to take the DIx AC 0: Disabled alternating current into account. The "DIx Release threshold" parameter is Mode 1: Enabled Disabled hidden and forced to 10 % of the set "DIx Activation threshold" parameter. © Arcteq Relays Ltd IM00001...
  • Page 510 Control → Device IO → Digital inputs → Digital input voltages . Table. 9.5 - 416. Digital input channel voltage measurement. Name Range Step Description DIx Voltage now 0.000...275.000 V 0.001 V Voltage measurement of a digital input channel. © Arcteq Relays Ltd IM00001...

  • Page 511: Digital Output Module (Optional)

    Table. 9.6 - 417. Digital output user description. Name Range Default Description User editable 1...31 Description of the digital output. This description is used in several menu OUTx description OUTx characters types for easier identification. © Arcteq Relays Ltd IM00001...

  • Page 512: Point Sensor Arc Protection Module (Optional)

    The rated voltage of the binary input is 24 VDC. The threshold picks up at ≥16 VDC. The binary input can be used for external light information or for similar applications. It can also be used as a part of various ARC schemes. Please note that the binary input's delay is 5…10ms. © Arcteq Relays Ltd IM00001...

  • Page 513: Rtd Input Module (Optional)

    The RTD input module is an add-on module with eight (8) RTD input channels. Each input supports 2-wire, 3-wire and 4-wire RTD sensors. The sensor type can be selected with software for two groups, four channels each. The card supports Pt100 and Pt1000 sensors © Arcteq Relays Ltd IM00001...

  • Page 514: Serial Rs-232 Communication Module (Optional)

    Description • Serial-based communications • Wavelength 660 nm Serial fiber (GG/ • Compatible with 50/125 μm, 62.5/125 μm, 100/140 μm, and COM E PP/GP/PG) 200 μm Plastic-Clad Silica (PCS) fiber • Compatible with ST connectors © Arcteq Relays Ltd IM00001...

  • Page 515: Lc Or Rj45 100 Mbps Ethernet Communication Module (Optional)

    The option card includes two serial communication interfaces: COM E is a serial fiber interface with glass/plastic option, COM F is an RS-232 interface. 9.10 LC or RJ45 100 Mbps Ethernet communication module (optional) Figure. 9.10 - 249. LC and RJ45 100 Mbps Ethernet module connectors. © Arcteq Relays Ltd IM00001...

  • Page 516: Double St 100 Mbps Ethernet Communication Module (Optional)

    Two-pin connector • Duplex ST connectors • 62.5/125 μm or 50/125 μm multimode fiber • Transmitter wavelength: 1260…1360 nm (nominal: 1310 nm) ST connectors • Receiver wavelength: 1100…1600 nm • 100BASE-FX • Up to 2 km © Arcteq Relays Ltd IM00001...
  • Page 517 The images below present two example configurations: the first displays a ring configuration (note how the third party devices are connected in a separate ring), while the second displays a multidrop configuration. Figure. 9.11 - 251. Example of a ring configuration. © Arcteq Relays Ltd IM00001...

  • Page 518: Double Rj45 10/100 Mbps Ethernet Communication Module (Optional)

    Figure. 9.11 - 252. Example of a multidrop configuration. 9.12 Double RJ45 10/100 Mbps Ethernet communication module (optional) Figure. 9.12 - 253. Double RJ-45 10/100 Mbps Ethernet communication module. Connector Description • IRIG-B input Two-pin connector © Arcteq Relays Ltd IM00001...

  • Page 519: Milliampere (Ma) I/O Module (Optional)

    For other redundancy options, please refer to the option card "LC 100 Mbps Ethernet communication module". Figure. 9.12 - 254. Example of a multidrop configuration. 9.13 Milliampere (mA) I/O module (optional) Figure. 9.13 - 255. Milliampere (mA) I/O module connections. © Arcteq Relays Ltd IM00001...

  • Page 520: Dimensions And Installation

    (½) of the rack's width, meaning that a total of two devices can be installed to the same rack next to one another. The figures below describe the device dimensions (first figure), the device installation (second), and the panel cutout dimensions and device spacing (third). Figure. 9.14 - 256. Device dimensions. © Arcteq Relays Ltd IM00001...
  • Page 521 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 9.14 - 257. Device installation. © Arcteq Relays Ltd IM00001...
  • Page 522 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 Figure. 9.14 - 258. Panel cut-out and spacing of the IED. © Arcteq Relays Ltd IM00001...

  • Page 523: Technic Echnical Da Al Data Ta

    From 6…75 Hz fundamental, up to the 31 harmonic current Current measurement range 5 mA…150 A (RMS) 0.002…10.000 × I < ±0.5 % or < ±3 mA Current measurement inaccuracy 10…150 × I < ±0.5 % © Arcteq Relays Ltd IM00001...

  • Page 524: Voltage Measurement

    4 independent VT inputs (U1, U2, U3 and U4) Measurement Sample rate 64 samples per cycle in frequency range 6...75Hz Voltage measuring range 0.50…480.00 V (RMS) 1…2 V ±1.5 % Voltage measurement inaccuracy 2…10 V ±0.5 % 10…480 V ±0.35 % © Arcteq Relays Ltd IM00001...

  • Page 525: Power And Energy Measurement

    Inaccuracy 10 mHz 10.1.2 CPU & Power supply 10.1.2.1 Auxiliary voltage Table. 10.1.2.1 - 423. Power supply model A Rated values Rated auxiliary voltage 85…265 V (AC/DC) < 20 W Power consumption < 40 W © Arcteq Relays Ltd IM00001...

  • Page 526: Cpu Communication Ports

    Data transfer rate 100 MB System integration Cannot be used for system protocols, only for local programming Table. 10.1.2.2 - 426. Rear panel system communication port A. Port Port media Copper Ethernet RJ-45 Number of ports Features © Arcteq Relays Ltd IM00001...

  • Page 527: Cpu Digital Inputs

    Settings Pick-up delay Software settable: 0…1800 s Polarity Software settable: Normally On/Normally Off Current drain 2 mA Terminal block connection Terminal block Phoenix Contact MSTB 2,5/5-ST-5,08 Solid or stranded wire 2.5 mm Maximum wire diameter © Arcteq Relays Ltd IM00001...

  • Page 528: Cpu Digital Outputs

    Maximum wire diameter 2.5 mm 10.1.3 Option cards 10.1.3.1 Digital input module Table. 10.1.3.1 - 431. Technical data for the digital input module. Rated values Rated auxiliary voltage 5…265 V (AC/DC) Current drain 2 mA © Arcteq Relays Ltd IM00001...

  • Page 529: Digital Output Module

    8, 25 or 50 kLx (the sensor is selectable in the order code) Point sensor detection radius 180 degrees Typically <5 ms with dedicated semiconductor outputs (HSO) Start and instant operating time (light only) Typically <10 ms regular output relays © Arcteq Relays Ltd IM00001...

  • Page 530: Milliampere Module (Ma Out & Ma In)

    Table. 10.1.3.4 - 436. Technical data for the milliampere module. Signals Output magnitudes 4 × mA output signal (DC) Input magnitudes 1 × mA input signal (DC) mA input Range (hardware) 0...33 mA Range (measurement) 0...24 mA Inaccuracy ±0.1 mA © Arcteq Relays Ltd IM00001...

  • Page 531: Rtd Input Module

    Table. 10.1.3.7 - 439. Technical data for the double LC 100 Mbps Ethernet communication module. Protocols Protocols HSR and PRP Ports Quantity of fiber ports LC fiber connector Communication port C & D Wavelength 1300 nm Fiber cable 50/125 μm or 62.5/125 μm multimode (glass) © Arcteq Relays Ltd IM00001...

  • Page 532: Double St 100 Mbps Ethernet Communication Module

    Current input magnitudes TRMS phase currents Peak-to-peak phase currents Pick-up Pick-up current setting 0.10…50.00 × I , setting step 0.01 × I 0.10…50.00 %I , setting step 0.01 %I Inrush 2nd harmonic blocking fund fund © Arcteq Relays Ltd IM00001...
  • Page 533 ±3 mA (0.005…10.0 × I - Starting I01 (1 A) - Starting I02 (0.2 A) ±1.5 %I0 or ±1.0 mA (0.005…25.0 × I - Starting I0Calc (5 A) ±1.0 %I0 or ±15 mA (0.005…4.0 × I Operating time © Arcteq Relays Ltd IM00001...
  • Page 534 , setting step 0.01 × I Pick-up current setting Inaccuracy: - Current ±0.5 %I or ±15 mA (0.10…4.0 × I - U1/I1 angle (U > 15 V) ±0.20° - U1/I1 angle (U = 1…15 V) ±1.5° © Arcteq Relays Ltd IM00001...
  • Page 535 0.00…360.00 deg, setting step 0.10 deg - Tripping area size (+/-) 45.00…135.00 deg, setting step 0.10 deg 0.005…40.00 × I , setting step 0.001 × I Pick-up current setting Pick-up voltage setting 1.00…75.00 %U0 , setting step 0.01 %U0 © Arcteq Relays Ltd IM00001...
  • Page 536 ±1.0 %-unit or ±100 mA (0.10…4.0 × I - Starting I2pu - Starting I2/I1 ±1.0 %-unit or ±100 mA (0.10…4.0 × I Operating time Definite time function operating time setting 0.00…1800.00 s, setting step 0.005 s © Arcteq Relays Ltd IM00001...
  • Page 537 0…250.0000, step 0.0001 B IDMT constant 0…5.0000, step 0.0001 C IDMT constant 0…250.0000, step 0.0001 Inaccuracy: - IDMT operating time ±1.5 % or ±20 ms - IDMT minimum operating time ±20 ms Instant operation time © Arcteq Relays Ltd IM00001...
  • Page 538 0.050…1800.000 s, setting step 0.005 s Inaccuracy: - Current criteria (I ratio 1.05→) ±1.0 % or ±55 ms - DO or DI only ±15 ms Reset Reset ratio 97 % of the pick-up current setting Reset time <50 ms © Arcteq Relays Ltd IM00001...
  • Page 539 (+ U Voltage input magnitudes RMS line-to-line or line-to-neutral voltages Pick-up 1 voltage Pick-up terms 2 voltages 3 voltages 0.00…120.00 %U , setting step 0.01 %U Pick-up setting Inaccuracy: - Voltage ±1.5 %U or ±30 mV © Arcteq Relays Ltd IM00001...
  • Page 540 1.00…50.00 % U0 , setting step 0.01 × I Inaccuracy: ±1.5 %U0 or ±30 mV - Voltage U0 - Voltage U0Calc ±150 mV Operation time Definite time function operating time setting 0.00…1800.00 s, setting step 0.005 s © Arcteq Relays Ltd IM00001...
  • Page 541 C IDMT constant 0…250.0000, step 0.0001 Inaccuracy: - IDMT operating time ±1.5 % or ±20 ms - IDMT minimum operating time ±20 ms Instant operation time Start time and instant operation time (trip): <65 ms ratio <0.95/1.05→ © Arcteq Relays Ltd IM00001...
  • Page 542 • The tracked frequency mode: When tracked mode is used, the system's nominal frequency can be anything between 7...75 Hz. 10.2.1.13 Rate-of-change of frequency protection (df/dt>/<; 81R) Table. 10.2.1.13 - 454. Technical data for the rate-of-change of frequency function. Input signals © Arcteq Relays Ltd IM00001...
  • Page 543 0.01…5.00 × I , setting step 0.01 × I Cold condition: - Long heat T const (cold) 0.0…500.0 min, setting step 0.1 min - Short heat T const (cold) 0.0…500.0 min, setting step 0.1 min © Arcteq Relays Ltd IM00001...
  • Page 544 0.00…1800.00 s, setting step 0.005 s time setting Inaccuracy: - Definite time (P ratio ±1.0 % or ±35 ms 1.05→) Instant operation time Start time and instant operation time (trip): <40 ms - PQS /PQS ratio 1.05→ © Arcteq Relays Ltd IM00001...
  • Page 545 During three-phase short-circuits the angle memory is active for 0.5 seconds in case the voltage drops below the squelch limit (0.5 V). During this 0.5 s time the impedance is calculated based on the 1.0 V secondary voltage value and voltage angles before the fault. © Arcteq Relays Ltd IM00001...
  • Page 546 Current input calculation Positive sequence current (I1) Voltage inputs Residual voltage from U3 or U4 voltage channel Voltage input magnitude Zero sequence voltage third harmonic Pick-up 1.00…95.00 %U0 , setting step 0.01 %U0 Pick-up voltage setting © Arcteq Relays Ltd IM00001...
  • Page 547 Typically <500 ms 10.2.1.20 Power factor protection (PF<; 55) Table. 10.2.1.20 - 461. Technical data for the power factor protection function. Measurement inputs Phase current inputs: I (A), I (B), I Current inputs Voltage inputs (+ U © Arcteq Relays Ltd IM00001...
  • Page 548 Start time and instant operation time (trip): - VHZ /VHZ ratio 1.05) <40 ms Reset Reset ratio 97 % of the pick-up setting Reset time setting 0.000…150.000 s, step 0.005 s Inaccuracy: Reset time ±1.0 % or ±25 ms © Arcteq Relays Ltd IM00001...
  • Page 549 Measurement inputs Phase current inputs: I (A), I (B), I Residual current channel I (Coarse) Current inputs (CT1 and CT2 current measurement module) Residual current channel I (Fine) Calculated residual current: I (A), I (B), I © Arcteq Relays Ltd IM00001...
  • Page 550 8, 25 or 50 kLx (the sensor is selected in the order code) ±3 % of the set pick-up value > 0.5 × I setting. 5 mA < 0.5 × I setting. Starting inaccuracy (IArc> and I0Arc>) Point sensor detection radius 180 degrees Operation time © Arcteq Relays Ltd IM00001...
  • Page 551 <50 ms Note! • Voltage memory is activated only when all line voltages fall below set pick-up value. • Voltage memory activation captures healthy situation voltage angles, one cycle before actual activation (50Hz/20ms before “bolted” fault) © Arcteq Relays Ltd IM00001...
  • Page 552 Any or all system line-to-line voltage(s) Any or all system line-to-neutral voltage(s) Monitored voltages Specifically chosen line-to-line or line-to-neutral voltage U4 channel voltage Pick-up Pick-up setting 0.05…30.00°, setting step 0.01° Inaccuracy: - Voltage angle ±30% overreach or 1.00 ° © Arcteq Relays Ltd IM00001...
  • Page 553 • When SYN3 is used, SYN1 and SYN2 must have the same reference voltage. • In 3LN mode the synchronization to the L-N and L-L voltages is possible. In 3LL/2LL modes the synchronization is only supported to the L-L voltage. © Arcteq Relays Ltd IM00001...
  • Page 554 , setting step 0.01 × U - Angle shift limit 2.00…90.00 deg, setting step 0.10 deg Inaccuracy: ±1.5 %U - Voltage - U angle (U> 1 V) ±1.5° External line/bus side pick-up (optional) 0 → 1 Time delay for alarm © Arcteq Relays Ltd IM00001...

  • Page 555: Circuit Breaker Wear Monitoring

    Amplitude THD Pick-up setting for all comparators 0.10…200.00 % , setting step 0.01 % ±3 % of the set pick-up value > 0.5 × I setting; 5 mA < 0.5 Inaccuracy × I setting. Time delay © Arcteq Relays Ltd IM00001...

  • Page 556: Disturbance Recorder

    Table. 10.3 - 477. Disturbance tests. All tests CE-approved and tested according to EN 60255-26 Emissions Conducted emissions: 150 kHz…30 MHz EN 60255-26 Ch. 5.2, CISPR 22 Radiated emissions: 30…1 000 MHz EN 60255-26 Ch. 5.1, CISPR 11 © Arcteq Relays Ltd IM00001...
  • Page 557 Operational: +55 °C, 16 h Cold test Storage: –40 °C, 16 h EN 60255-1, IEC 60068-2-1 Operational: –20 °C, 16 h Table. 10.3 - 481. Environmental conditions. IP classes IP54 (front) Casing protection class IP21 (rear) © Arcteq Relays Ltd IM00001...
  • Page 558 Height: 208 mm Dimensions Width: 257 mm (½ rack) Depth: 165 mm (no cards or connectors) Weight 1.5 kg With packaging (gross) Height: 250 mm Dimensions Width: 343 mm Depth: 256 mm Weight 2.0 kg © Arcteq Relays Ltd IM00001...
  • Page 559 Genera Generat t or Commander or Commander Instruction manual Version: 2.07 11 Ordering information Accessories Order code der code Descrip Description tion Not t e e Manufact Manufactur urer er © Arcteq Relays Ltd IM00001...
  • Page 560 Co. Ltd. ADAM-4018+- External 8-ch Thermocouple mA Input module, Advanced Requires an external power module pre-configured Co. Ltd. Not available in Generator Commander AQX121 Raising frame 120mm Arcteq Ltd. applications. Not available in Generator Commander AQX122 Raising frame 40mm Arcteq Ltd.
  • Page 561 Arcteq Relays Ltd. Visiting and postal address Kvartsikatu 2 A 1 65300 Vaasa, Finland Contacts Phone: +358 10 3221 370 Website: arcteq.fi Technical support: support.arcteq.fi +358 10 3221 388 (EET 9:00 – 17.00) E-mail (sales): sales@arcteq.fi © Arcteq Relays Ltd IM00001...

Table of Contents