Arcteq AQ-G257 Instruction Manual
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Arcteq AQ-G257 Instruction Manual

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AQ-G257
Generator protection IED
Instruction manual

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Summary of Contents for Arcteq AQ-G257

  • Page 1 AQ-G257 Generator protection IED Instruction manual...

  • Page 3: Table Of Contents

    4.2 Configuring user levels and their passwords................. 14 5 Functions unctions ...................................................... 16 5.1 Functions included in AQ-G257 ................... 16 5.2 Measurements........................18 5.2.1 Current measurement and scaling in differential applications ........18 5.2.2 Voltage measurement and scaling ................29 5.2.3 Power and energy calculation ..................
  • Page 4 7 Connections and applic 7 Connections and applica a tion examples tion examples..................................427 7.1 Connections of AQ-G257 ....................427 7.2 Application examples and their connections............... 429 7.3 Trip circuit supervision (95) ....................431 8 Construction and installa 8 Construction and installation tion ....................
  • Page 5 9.3 Tests and environmental ....................491 10 Or 10 Ordering inf dering informa ormation tion ............................................494 11 Contact and r 11 Contact and re e f f er erence inf ence informa ormation tion....................................496 © Arcteq Relays Ltd IM00017...
  • Page 6 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 7 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Copyright Copyright © Arcteq Relays Ltd. 2022. All rights reserved. © Arcteq Relays Ltd IM00017...

  • Page 8: 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 IM00017...
  • Page 9 - Tech data updated: overfrequency, underfrequency and rate-of-change-of-frequency. - Improvements to many drawings and formula images. - AQ-G257 Functions included list Added: Additional instance of underimpedance, voltage memory, indicator objects, vector jump protection, running hour counter and measurement recorder. - Added "32N" ANSI code to directional earth fault protection modes "unearthed" and "petersen coil grounded".

  • Page 10: Version 1 Revision Notes

    - Added spare part codes and compatibilities to option cards. 1.2 Version 1 revision notes Table. 1.2 - 2. Version 1 revision notes Revision 1.00 Date 13.4.2016 Changes The first revision for AQ-G257 IED. Revision 1.01 Date 9.2.2017 © Arcteq Relays Ltd IM00017...
  • Page 11 Power factor protection description added Over/Under/Reverse protection descriptions removed. Replaced with power protection function description. Order code revised Revision 1.03 Date 14.8.2018 Added mA output option card description and ordercode Changes Added HMI display technical data © Arcteq Relays Ltd IM00017...

  • Page 12: 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 IM00017...
  • Page 13 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 IM00017...

  • Page 14: General

    Version: 2.06 3 General The AQ-G257 generator protection IED is a member of the AQ-200 product line. The hardware and software are modular: the hardware modules are assembled and configured according to the application's I/O requirements and the software determines the available functions. This manual describes the specific application of the AQ-G257 generator protection IED.

  • Page 15: 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 IM00017...

  • Page 16: 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 IM00017...
  • Page 17 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 IM00017...

  • Page 18: Functions Unctions

    Instruction manual Version: 2.06 5 Functions 5.1 Functions included in AQ-G257 The AQ-G257 generator protection relay includes the following functions as well as the number of stages in those functions. Table. 5.1 - 3. Protection functions of AQ-G257. Name (number of...
  • Page 19 Voltage memory PGS (1) PGx>/< Programmable stage ARC (1) IArc>/I0Arc> 50Arc/50NArc Arc fault protection (optional) Table. 5.1 - 4. Control functions of AQ-G257. Name ANSI Description Setting group selection Object control and monitoring (10 objects available) Indicator object monitoring (10 indicators available) Vector jump ∆φ...

  • Page 20: 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 IM00017...
  • Page 21 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 IM00017...
  • Page 22 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 IM00017...
  • Page 23 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 IM00017...
  • Page 24 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 IM00017...
  • Page 25 [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 IM00017...
  • Page 26 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 IM00017...
  • Page 27 P/S Table. 5.2.1 - 10. 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 IM00017...
  • Page 28 Sec") Table. 5.2.1 - 14. 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 IM00017...
  • Page 29 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 IM00017...
  • Page 30 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 IM00017...

  • Page 31: 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 IM00017...
  • Page 32 - 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 IM00017...
  • Page 33 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 IM00017...
  • Page 34 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 IM00017...
  • Page 35 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 IM00017...
  • Page 36 Table. 5.2.2 - 25. 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 IM00017...
  • Page 37 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 IM00017...
  • Page 38 The phase angle measurement from each of the four voltage inputs. Table. 5.2.2 - 29. 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 IM00017...
  • Page 39 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 IM00017...
  • Page 40 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 IM00017...
  • Page 41 Perc.") 0: Per unit Harmonics 0: Per Defines how the harmonics are displayed: in p.u. values, as 1: Primary V display unit primary voltage values, or as secondary voltage values. 2: Secondary V © Arcteq Relays Ltd IM00017...

  • Page 42: Power And Energy Calculation

    (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. In these equations, phi (φ) is the angle difference between voltage and current. © Arcteq Relays Ltd IM00017...
  • Page 43 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: Only line y line-t -to-line v o-line volta oltages a ges av v ailable ailable © Arcteq Relays Ltd IM00017...
  • Page 44 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 IM00017...
  • Page 45 Indicates the total number of pulses sent. sent Table. 5.2.3 - 38. 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 IM00017...
  • Page 46 904.00…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 IM00017...
  • Page 47 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 IM00017...
  • Page 48 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 IM00017...

  • Page 49: 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 IM00017...
  • Page 50 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 51 "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 IM00017...

  • Page 52: Protection Functions

    5.3.1 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 IM00017...
  • Page 53 A A Q Q -G257 -G257 Instruction manual Version: 2.06 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 IM00017...
  • Page 54 Figure. 5.3.1 - 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 IM00017...
  • Page 55 • 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 IM00017...
  • Page 56 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 IM00017...
  • Page 57 "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 IM00017...
  • Page 58 = 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 IM00017...
  • Page 59 1: Yes reset. release time The behavior of the stages with different release time configurations are presented in the figures below. Figure. 5.3.1 - 25. No delayed pick-up release. © Arcteq Relays Ltd IM00017...
  • Page 60 -G257 Instruction manual Version: 2.06 Figure. 5.3.1 - 26. Delayed pick-up release, delay counter is reset at signal drop-off. Figure. 5.3.1 - 27. Delayed pick-up release, delay counter value is held during the release time. © Arcteq Relays Ltd IM00017...

  • Page 61: 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 IM00017...
  • Page 62 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. 5.3.2 - 29. Simplified function block diagram of the I> function. © Arcteq Relays Ltd IM00017...
  • Page 63 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 IM00017...
  • Page 64 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 IM00017...
  • Page 65 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 IM00017...
  • Page 66 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 IM00017...
  • Page 67 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 IM00017...

  • Page 68: 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 IM00017...
  • Page 69 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. 5.3.3 - 31. Simplified function block diagram of the I0> fucntion. © Arcteq Relays Ltd IM00017...
  • Page 70 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 IM00017...
  • Page 71 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 IM00017...
  • Page 72 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.3.3 - 60. 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 IM00017...

  • Page 73: 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 IM00017...
  • Page 74 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. 5.3.4 - 32. Simplified function block diagram of the Idir> function. © Arcteq Relays Ltd IM00017...
  • Page 75 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 IM00017...
  • Page 76 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 IM00017...
  • Page 77 In a short- circuit the angle comes from impedance calculation. Figure. 5.3.4 - 34. Operation sector area when the sector center has been set to -45 degrees. © Arcteq Relays Ltd IM00017...
  • Page 78 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 IM00017...
  • Page 79 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.3.4 - 67. 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 IM00017...
  • Page 80 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 IM00017...

  • Page 81: 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 IM00017...
  • Page 82 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 IM00017...
  • Page 83 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 IM00017...
  • Page 84 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 IM00017...
  • Page 85 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 IM00017...
  • Page 86 In emergency situations a line with an earth fault can be used for a specific time. Figure. 5.3.5 - 38. Angle tracking of I0dir> function (Petersen coil earthed network model). © Arcteq Relays Ltd IM00017...
  • Page 87 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 IM00017...
  • Page 88 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 IM00017...
  • Page 89 CT errors. For all these reasons, Arcteq has developed an improved alternative to these traditional directional earth fault protections.
  • Page 90 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 91 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 IM00017...
  • Page 92 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 IM00017...
  • Page 93 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 IM00017...

  • Page 94: 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 IM00017...
  • Page 95 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 IM00017...
  • Page 96 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 IM00017...
  • Page 97 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 IM00017...
  • Page 98 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 IM00017...
  • Page 99 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 IM00017...

  • Page 100: 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 IM00017...
  • Page 101 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 IM00017...
  • Page 102 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 IM00017...
  • Page 103 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 IM00017...
  • Page 104 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 IM00017...
  • Page 105 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 IM00017...
  • Page 106 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 IM00017...

  • Page 107: 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 IM00017...
  • Page 108 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 IM00017...
  • Page 109 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 IM00017...
  • Page 110 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 IM00017...
  • Page 111 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 IM00017...
  • Page 112 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 IM00017...
  • Page 113 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 IM00017...
  • Page 114 (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 IM00017...
  • Page 115 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 IM00017...
  • Page 116 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 IM00017...
  • Page 117 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 IM00017...
  • Page 118 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 IM00017...
  • Page 119 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 IM00017...
  • Page 120 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Device configuration as a dedicated CBFP unit Figure. 5.3.8 - 54. Wiring diagram when the device is configured as a dedicated CBFP unit. © Arcteq Relays Ltd IM00017...
  • Page 121 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.3.8 - 95. Event messages. Event block name Event names CBF1 Start ON CBF1 Start OFF CBF1 Retrip ON CBF1 Retrip OFF © Arcteq Relays Ltd IM00017...

  • Page 122: 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 IM00017...
  • Page 123 Table. 5.3.9 - 97. 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 IM00017...
  • Page 124 20 ms averaged history value from -20 ms from START or TRIP event. Figure. 5.3.9 - 57. Selectable measurement magnitudes with 3LN+U4 VT connection. Figure. 5.3.9 - 58. Selectable measurement magnitudes with 3LL+U4 VT connection (P-E voltages not available without residual voltage). © Arcteq Relays Ltd IM00017...
  • Page 125 Table. 5.3.9 - 100. 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 IM00017...
  • Page 126 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 IM00017...
  • Page 127 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 IM00017...
  • Page 128 Table. 5.3.9 - 104. 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 IM00017...

  • Page 129: 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 IM00017...
  • Page 130 Table. 5.3.10 - 106. 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 IM00017...
  • Page 131 20 ms averaged history value from -20 ms from START or TRIP event. Figure. 5.3.10 - 61. Selectable measurement magnitudes with 3LN+U4 VT connection. Figure. 5.3.10 - 62. Selectable measurement magnitudes with 3LL+U4 VT connection (P-E voltages not available without residual voltage). © Arcteq Relays Ltd IM00017...
  • Page 132 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 IM00017...
  • Page 133 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 IM00017...
  • Page 134 • 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 IM00017...
  • Page 135 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 IM00017...
  • Page 136 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 IM00017...

  • Page 137: 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. 5.3.11 - 65. Normal situation. © Arcteq Relays Ltd IM00017...
  • Page 138 • 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 IM00017...
  • Page 139 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 IM00017...
  • Page 140 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 IM00017...
  • Page 141 • 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 IM00017...
  • Page 142 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 IM00017...
  • Page 143 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 IM00017...

  • Page 144: 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. 5.3.12 - 69. Normal situation. © Arcteq Relays Ltd IM00017...
  • Page 145 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. 5.3.12 - 72. Normal situation. © Arcteq Relays Ltd IM00017...
  • Page 146 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 IM00017...
  • Page 147 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 IM00017...
  • Page 148 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. 5.3.12 - 76. Example of the block setting operation. © Arcteq Relays Ltd IM00017...
  • Page 149 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 IM00017...
  • Page 150 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 IM00017...
  • Page 151 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 IM00017...

  • Page 152: 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 IM00017...
  • Page 153 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 IM00017...
  • Page 154 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 IM00017...
  • Page 155 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 IM00017...
  • Page 156 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 IM00017...

  • Page 157: 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 IM00017...
  • Page 158 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 IM00017...
  • Page 159 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 IM00017...
  • Page 160 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 IM00017...
  • Page 161 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 IM00017...
  • Page 162 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 IM00017...

  • Page 163: 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 IM00017...
  • Page 164 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 IM00017...
  • Page 165 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 IM00017...
  • Page 166 "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 IM00017...
  • Page 167 The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.3.15 - 146. Event messages. Event block name Event names PWR1 Start ON © Arcteq Relays Ltd IM00017...

  • Page 168: 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 IM00017...
  • Page 169 • 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 IM00017...
  • Page 170 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 IM00017...
  • Page 171 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 IM00017...
  • Page 172 Table. 5.3.16 - 152. 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 IM00017...

  • Page 173: 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 IM00017...
  • Page 174 = 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 IM00017...
  • Page 175 100 % 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 IM00017...
  • Page 176 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 IM00017...
  • Page 177 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 IM00017...
  • Page 178 (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 IM00017...
  • Page 179 Figure. 5.3.17 - 91. Simplified motor construction and time constants. Any normal induction machine such as electric motors have the following major components: © Arcteq Relays Ltd IM00017...
  • Page 180 (DOL) starting. Table. 5.3.17 - 154. Motor heating during DOL starting. The motor is de-energized and all parts of it are in the ambient temperature. © Arcteq Relays Ltd IM00017...
  • Page 181 Most motors are rotor- limited which results in the rotor heating up to dangerously high temperatures before the stator. © Arcteq Relays Ltd IM00017...
  • Page 182 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 IM00017...
  • Page 183 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 IM00017...
  • Page 184 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 IM00017...
  • Page 185 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.17 - 93. Measured motor temperature in heating/cooling test. © Arcteq Relays Ltd IM00017...
  • Page 186 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 IM00017...
  • Page 187 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 IM00017...
  • Page 188 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.17 - 96. Comparing single time constant thermal replica tripping curves to given motor thermal characteristics. © Arcteq Relays Ltd IM00017...
  • Page 189 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 IM00017...
  • Page 190 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.17 - 98. Thermal tripping curves with single time constant, pre-load 0% (cold). Figure. 5.3.17 - 99. Thermal tripping curves with single time constant, pre-load 90% (hot). © Arcteq Relays Ltd IM00017...
  • Page 191 Figure. 5.3.17 - 100. Thermal tripping curves with dual dynamic time constants and correction factor, pre-load 0% (cold) Figure. 5.3.17 - 101. Thermal tripping curves with dual dynamic time constants and correction factor, pre-load 90% (hot). © Arcteq Relays Ltd IM00017...
  • Page 192 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.17 - 102. Thermal cooling curves, single cooling time constant. Figure. 5.3.17 - 103. Thermal cooling curves, dynamic dual time constant. © Arcteq Relays Ltd IM00017...
  • Page 193 Figure. 5.3.17 - 104. Thermal cooling curves, dynamic triple time constant (motor is running without load in the first part with dedicated time constant). Figure. 5.3.17 - 105. NPS-biased thermal trip curves with k value of 1. © Arcteq Relays Ltd IM00017...
  • Page 194 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.17 - 106. NPS-biased thermal trip curves with k value of 3. Figure. 5.3.17 - 107. NPS-biased thermal trip curves with k value of 7. © Arcteq Relays Ltd IM00017...
  • Page 195 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 IM00017...
  • Page 196 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 IM00017...
  • Page 197 - 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 IM00017...
  • Page 198 - 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 IM00017...
  • Page 199 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 IM00017...
  • Page 200 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 IM00017...
  • Page 201 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 IM00017...
  • Page 202 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 IM00017...
  • Page 203 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 IM00017...
  • Page 204 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 IM00017...
  • Page 205 - 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 IM00017...
  • Page 206 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 IM00017...

  • Page 207: Underexcitation Protection (Q<; 40)

    Figure. 5.3.18 - 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 IM00017...
  • Page 208 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. 5.3.18 - 167. Measurement inputs of the Q< function. Signal Description Time base 3PH Reactive power (P) Total three-phase reactive power © Arcteq Relays Ltd IM00017...
  • Page 209 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 IM00017...
  • Page 210 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 IM00017...

  • Page 211: 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 IM00017...
  • Page 212 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 IM00017...
  • Page 213 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 IM00017...
  • Page 214 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 IM00017...
  • Page 215 • 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 IM00017...
  • Page 216 ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.3.19 - 179. Event messages. Event block name Event names SEF1 Start ON © Arcteq Relays Ltd IM00017...

  • Page 217: 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 IM00017...
  • Page 218 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 IM00017...
  • Page 219 ( 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 IM00017...
  • Page 220 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 IM00017...
  • Page 221 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 IM00017...

  • Page 222: 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 IM00017...
  • Page 223 Figure. 5.3.21 - 117. Simplified function block diagram of the V/Hz> function. Measured input The function block uses analog system voltages and system frequency measurement values. Table. 5.3.21 - 187. Measurement inputs of the volts-per-hertz function. Signal Description Time base System voltage RMS System voltage RMS © Arcteq Relays Ltd IM00017...
  • Page 224 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 IM00017...
  • Page 225 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.21 - 118. Inverse (above) and inverse and DT (below) time characteristics with the TimeDial k setting effect. © Arcteq Relays Ltd IM00017...
  • Page 226 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 IM00017...
  • Page 227 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 IM00017...
  • Page 228 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 IM00017...

  • Page 229: 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 IM00017...
  • Page 230 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 IM00017...
  • Page 231 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 IM00017...
  • Page 232 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 IM00017...

  • Page 233: Generator/Transformer Differential Protection (Idb>/Idi>/I0Dhv>/I0Dlv>; 87T/87N/ 87G)

    Similarly, it is pointless to have nothing but fuses protecting a transmission transformer of a few hundred MVA that feeds entire cities. © Arcteq Relays Ltd IM00017...
  • Page 234 If the transformer has forced cooling, monitoring and protection for cooling systems should be applied. Multifunction relays need protections and monitoring; dedicated relays require backup overcurrent and earth fault protections. © Arcteq Relays Ltd IM00017...
  • Page 235 On the other hand, differential protection has its negative properties: it is not very easy to set up to operate correctly, and it requires a second set of current transformers which increases installation costs. However, this cost is marginal in larger scale power transformers. © Arcteq Relays Ltd IM00017...
  • Page 236 The image below shows what a typical transformer name plate looks like, what data it includes and what to do with it. Figure. 5.3.23 - 124. Transformer name plate data. © Arcteq Relays Ltd IM00017...
  • Page 237 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 IM00017...
  • Page 238 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 IM00017...
  • Page 239 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.23 - 126. Yd1 transformer's internal connection (in theory). © Arcteq Relays Ltd IM00017...
  • Page 240 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 IM00017...
  • Page 241 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.23 - 128. "Subtract" formula. Figure. 5.3.23 - 129. "Add" formula. Figure. 5.3.23 - 130. CTs' starpoints requiring the "Add" mode. © Arcteq Relays Ltd IM00017...
  • Page 242 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 IM00017...
  • Page 243 ). 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 IM00017...
  • Page 244 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 IM00017...
  • Page 245 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 IM00017...
  • Page 246 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 IM00017...
  • Page 247 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 IM00017...
  • Page 248 CTs differently (starpoint towards or away from the transformer). Thus, the differential current is always calculated as follows: © Arcteq Relays Ltd IM00017...
  • Page 249 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 IM00017...
  • Page 250 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 IM00017...
  • Page 251 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 IM00017...
  • Page 252 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 IM00017...
  • Page 253 (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 IM00017...
  • Page 254 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.3.23 - 137. Example configuration for the transformer differential function. © Arcteq Relays Ltd IM00017...
  • Page 255 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 IM00017...
  • Page 256 (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 IM00017...
  • Page 257 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 IM00017...
  • Page 258 (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 IM00017...
  • Page 259 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 IM00017...
  • Page 260 (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 IM00017...
  • Page 261 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 IM00017...
  • Page 262 Figure. 5.3.23 - 143. Inrush blocking by using the 2 harmonic (relative to fundamental frequency). Figure. 5.3.23 - 144. Example of transformer magnetizing inrush currents. A conservative setting recommendation for standard type transformers: • enabling the 2 harmonic blocking © Arcteq Relays Ltd IM00017...
  • Page 263 Figure. 5.3.23 - 145. Transformer behavior in case of overvoltage caused by overexcitation. © Arcteq Relays Ltd IM00017...
  • Page 264 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 IM00017...
  • Page 265 (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 IM00017...
  • Page 266 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 IM00017...
  • Page 267 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 IM00017...
  • Page 268 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 IM00017...
  • Page 269 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 IM00017...
  • Page 270 The data register is available, based on the changes in the tripping events. Table. 5.3.23 - 204. Event messages. Event block name Event names DIF1 Idb> Trip ON DIF1 Idb> Trip OFF DIF1 Idb> Blocked (ext) ON © Arcteq Relays Ltd IM00017...
  • Page 271 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. 5.3.23 - 205. Register content. Name Description Date and time dd.mm.yyyy hh:mm:ss.mss Event Event name © Arcteq Relays Ltd IM00017...

  • Page 272: Resistance Temperature Detectors

    (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 IM00017...
  • Page 273 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 IM00017...
  • Page 274 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 IM00017...
  • Page 275 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 IM00017...
  • Page 276 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 IM00017...
  • Page 277 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 IM00017...
  • Page 278 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 IM00017...

  • Page 279: 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 280 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 IM00017...
  • Page 281 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 IM00017...
  • Page 282 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 IM00017...
  • Page 283 Table. 5.3.25 - 211. 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 IM00017...
  • Page 284 HMI display, or through the setting tool software when it is connected to the relay and its Live Edit mode is active. Table. 5.3.25 - 212. Information displayed by the function. Name Range Description © Arcteq Relays Ltd IM00017...
  • Page 285 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 IM00017...
  • Page 286 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 IM00017...

  • Page 287: Programmable Stage (Pgx>/<; 99)

    (10) depending on how many the application needs. In the image below, the number of programmable stages have been set to two which makes PS1 and PS2 to appear. Inactive stages are hidden until they are activated. © Arcteq Relays Ltd IM00017...
  • Page 288 2: Blocked Displays the mode of PGS block. PSx >/< LN 3: Test This parameter is visible only when Allow setting of individual LN mode is behaviour 4: Test/ enabled in General menu. Blocked 5: Off © Arcteq Relays Ltd IM00017...
  • Page 289 Divides Signal 1 by Signal 2. The comparison uses the product of this calculation. 2: Max (Mag1, The bigger value of the chosen signals is used in the comparison. Mag2) 3: Min (Mag1, The smaller value of the chosen signals is used in the comparison. Mag2) © Arcteq Relays Ltd IM00017...
  • Page 290 2: Min (Mag1, Mag2, Mag3) The smallest value of the chosen signals is used in the comparison. 3: Mag1 OR Mag2 OR Mag3 Any of the signals fulfills the pick-up condition. Each signal has their own pick-up setting. © Arcteq Relays Ltd IM00017...
  • Page 291 Signal 1 or Signal 2 as well as Signal 3 fulfill the pick-up condition. The settings for different comparisons are in the setting groups. This means that each signal parameter can be changed by changing the setting group. © Arcteq Relays Ltd IM00017...
  • Page 292 (in p.u.) IL1 7 IL1 7 harmonic value (in p.u.) IL1 9 IL1 9 harmonic value (in p.u.) IL1 11 IL1 11 harmonic value (in p.u.) IL1 13 IL1 13 harmonic value (in p.u.) © Arcteq Relays Ltd IM00017...
  • Page 293 Description I01 ff (p.u.) I01 Fundamental frequency RMS value (in p.u.) I01 2 I01 2 harmonic value (in p.u.) I01 3 I01 3 harmonic value (in p.u.) I01 4 I01 4 harmonic value (in p.u.) © Arcteq Relays Ltd IM00017...
  • Page 294 Positive sequence current value (in p.u.) I2 Mag Negative sequence current value (in p.u.) IL1 Ang IL1 angle of current IL2 Ang IL2 angle of current IL3 Ang IL3 angle of current I01 Ang I01 angle of current © Arcteq Relays Ltd IM00017...
  • Page 295 Positive sequence voltage U2 neg.seq.V Mag Negative sequence voltage U0CalcAng Calculated residual voltage angle U1 pos.seq.V Ang Positive sequence voltage angle U2 neg.seq.V Ang Negative sequence voltage angle P P o o w w ers © Arcteq Relays Ltd IM00017...
  • Page 296 Reactance X L23 secondary (Ω) RL31Sec Resistance R L31 secondary (Ω) XL31Sec Reactance X L31 secondary (Ω) Z12Pri Impedance Z L12 primary (Ω) Z23Pri Impedance Z L23 primary (Ω) Z31Pri Impedance Z L31 primary (Ω) © Arcteq Relays Ltd IM00017...
  • Page 297 ZSeqSec Positive Impedance Z secondary (Ω) ZSeqAngle Positive Impedance Z angle GL1Pri Conductance G L1 primary (mS) BL1Pri Susceptance B L1 primary (mS) GL2Pri Conductance G L2 primary (mS) BL2Pri Susceptance B L2 primary (mS) © Arcteq Relays Ltd IM00017...
  • Page 298 Transformer thermal temperature RTD meas 1…16 RTD measurement channels 1…16 Ext RTD meas 1…8 External RTD measurement channels 1…8 (ADAM) mA input 7,8,15,16 mA input channels 7, 8, 15, 16 ASC 1…4 Analog scaled curves 1…4 © Arcteq Relays Ltd IM00017...
  • Page 299 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 IM00017...
  • Page 300 PGS1 PS4 >/< Start ON PGS1 PS4 >/< Start OFF PGS1 PS4 >/< Trip ON PGS1 PS4 >/< Trip OFF PGS1 PS4 >/< Block ON PGS1 PS4 >/< Block OFF PGS1 PS5 >/< Start ON © Arcteq Relays Ltd IM00017...
  • Page 301 PGS1 PS9 >/< Block OFF PGS1 PS10 >/< Start ON PGS1 PS10 >/< Start OFF PGS1 PS10 >/< Trip ON PGS1 PS10 >/< Trip OFF PGS1 PS10 >/< Block ON PGS1 PS10 >/< Block OFF © Arcteq Relays Ltd IM00017...

  • Page 302: 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 IM00017...
  • Page 303 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 IM00017...
  • Page 304 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 IM00017...
  • Page 305 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 IM00017...

  • Page 306: Inadvertend Energizing Protection (I> U< I.a.e; 50/27)

    Inadvertent energizing protection function is intended to be used for protection the generator from connecting the generator to network when it is not rotating. A machine that is accidentally energized from the power system can be damaged or completely destroyed. © Arcteq Relays Ltd IM00017...
  • Page 307 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 IM00017...
  • Page 308 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 IM00017...
  • Page 309 ON, OFF, or both. The events triggered by the function are recorded with a time stamp and with process data values. Table. 5.3.28 - 229. Event messages. Event block name Event names IAE1 Start ON © Arcteq Relays Ltd IM00017...

  • Page 310: Underexcitation Protection (X<; 40)

    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). The operational logic consists of the following: © Arcteq Relays Ltd IM00017...
  • Page 311 Set mode of URX block. 2: Blocked X< 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 IM00017...
  • Page 312 When the function has detected a fault and counts down time towards remaining to -1800.000...1800.000s 0.005s a trip, this displays how much time is left before tripping occurs. trip meas -1250.00...1250.00 0.01Z The ratio between the measured impedance and the pick-up value. at the moment © Arcteq Relays Ltd IM00017...
  • Page 313 Start ON URX1 Start OFF URX1 Trip ON URX1 Trip OFF URX1 Block ON URX1 Block OFF URX2 Start ON URX2 Start OFF URX2 Trip ON URX2 Trip OFF URX2 Block ON URX2 Block OFF © Arcteq Relays Ltd IM00017...

  • Page 314: Voltage Memory

    2. At least one phase current must be above the set value for the "Measured current condition 3I>" parameter. This setting limit is optional. Figure. 5.3.30 - 157. Distance protection characteristics and directional overcurrent. © Arcteq Relays Ltd IM00017...
  • Page 315 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 RMS measurement of voltage U RMS measurement of voltage U © Arcteq Relays Ltd IM00017...
  • Page 316 For example, let us say a 500 A current is measured on the primary side while the fixed frequency is set to 50 Hz. This results in the frequency dropping to 46 Hz, while the actual current measurement would be 460 A. Therefore, the system would have an error of 40 A. © Arcteq Relays Ltd IM00017...

  • Page 317: Control Functions

    The following figure presents a simplified function block diagram of the setting group selection function. © Arcteq Relays Ltd IM00017...
  • Page 318 If setting groups are controlled by pulses, the setting group activated by pulse will stay active until another setting groups receives and activation signal. Figure. 5.4.1 - 161. Example sequences of group changing (control with pulse only, or with both pulses and static signals). © Arcteq Relays Ltd IM00017...
  • Page 319 The selection of Setting group 1 ("SG1"). Has the highest priority input in setting group active 0: Not group control. Can be controlled with pulses or static signals. If static signal control is applied, active no other SG requests will be processed. Active © Arcteq Relays Ltd IM00017...
  • Page 320 Petersen coil is connected when the network is compensated, or whether it is open when the network is unearthed. © Arcteq Relays Ltd IM00017...
  • Page 321 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 IM00017...
  • Page 322 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.4.1 - 163. Setting group control – two-wire connection from Petersen coil status. © Arcteq Relays Ltd IM00017...
  • Page 323 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 IM00017...
  • Page 324 The function does not have a register. Table. 5.4.1 - 241. 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 IM00017...
  • Page 325 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 IM00017...

  • Page 326: 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 IM00017...
  • Page 327 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 IM00017...
  • Page 328 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 IM00017...
  • Page 329 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 IM00017...
  • Page 330 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 IM00017...
  • Page 331 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 IM00017...
  • Page 332 Final trip ON OBJ1 Final trip OFF OBJ2 Object Intermediate OBJ2 Object Open OBJ2 Object Close OBJ2 Object Bad OBJ2 WD Intermediate OBJ2 WD Out OBJ2 WD In OBJ2 WD Bad OBJ2 Open Request ON © Arcteq Relays Ltd IM00017...
  • Page 333 Open Command ON OBJ3 Open Command OFF OBJ3 Close Request ON OBJ3 Close Request OFF OBJ3 Close Command ON OBJ3 Close Command OFF OBJ3 Open Blocked ON OBJ3 Open Blocked OFF OBJ3 Close Blocked ON © Arcteq Relays Ltd IM00017...
  • Page 334 Close Blocked OFF OBJ4 Object Ready OBJ4 Object Not Ready OBJ4 Sync Ok OBJ4 Sync Not Ok OBJ4 Open Command Fail OBJ4 Close Command Fail OBJ4 Final trip ON OBJ4 Final trip OFF OBJ5 Object Intermediate © Arcteq Relays Ltd IM00017...
  • Page 335 Object Intermediate OBJ6 Object Open OBJ6 Object Close OBJ6 Object Bad OBJ6 WD Intermediate OBJ6 WD Out OBJ6 WD In OBJ6 WD Bad OBJ6 Open Request ON OBJ6 Open Request OFF OBJ6 Open Command ON © Arcteq Relays Ltd IM00017...
  • Page 336 OBJ7 Close Request ON OBJ7 Close Request OFF OBJ7 Close Command ON OBJ7 Close Command OFF OBJ7 Open Blocked ON OBJ7 Open Blocked OFF OBJ7 Close Blocked ON OBJ7 Close Blocked OFF OBJ7 Object Ready © Arcteq Relays Ltd IM00017...
  • Page 337 Object Not Ready OBJ8 Sync Ok OBJ8 Sync Not Ok OBJ8 Open Command Fail OBJ8 Close Command Fail OBJ8 Final trip ON OBJ8 Final trip OFF OBJ9 Object Intermediate OBJ9 Object Open OBJ9 Object Close © Arcteq Relays Ltd IM00017...
  • Page 338 OBJ10 Object Bad OBJ10 WD Intermediate OBJ10 WD Out OBJ10 WD In OBJ10 WD Bad OBJ10 Open Request ON OBJ10 Open Request OFF OBJ10 Open Command ON OBJ10 Open Command OFF OBJ10 Close Request ON © Arcteq Relays Ltd IM00017...

  • Page 339: Indicator Object Monitoring

    (2) digital inputs. Alternatively, object status monitoring can be performed with a single digital input: the input's active state and its zero state (switched to 1 with a NOT gate in the Logic editor). © Arcteq Relays Ltd IM00017...
  • Page 340 ON, OFF, or both. Table. 5.4.3 - 251. Event messages (instances 1-10). Event block name Event names CIN1 Intermediate CIN1 Open CIN1 Close CIN1 CIN2 Intermediate © Arcteq Relays Ltd IM00017...
  • Page 341 CIN6 Intermediate CIN6 Open CIN6 Close CIN6 CIN7 Intermediate CIN7 Open CIN7 Close CIN7 CIN8 Intermediate CIN8 Open CIN8 Close CIN8 CIN9 Intermediate CIN9 Open CIN9 Close CIN9 CIN10 Intermediate CIN10 Open CIN10 Close CIN10 © Arcteq Relays Ltd IM00017...

  • Page 342: Synchrocheck (Δv/Δa/Δf; 25)

    The seven images below present three different example connections and four example applications of the synchrocheck function. Figure. 5.4.4 - 168. Example connection of the synchrocheck function (3LN+U4 mode, SYN1 in use, UL1 as reference voltage). © Arcteq Relays Ltd IM00017...
  • Page 343 Figure. 5.4.4 - 169. Example connection of the synchrocheck function (2LL+U0+U4 mode, SYN1 in use, UL12 as reference voltage). Figure. 5.4.4 - 170. Example connection of the synchrocheck function (2LL+U3+U4 mode, SYN3 in use, UL12 as reference voltage). © Arcteq Relays Ltd IM00017...
  • Page 344 -G257 Instruction manual Version: 2.06 Figure. 5.4.4 - 171. Example application (synchrocheck over one breaker, with 3LL and 3LN VT connections). Figure. 5.4.4 - 172. Example application (synchrocheck over one breaker, with 2LL VT connection). © Arcteq Relays Ltd IM00017...
  • Page 345 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 5.4.4 - 173. Example application (synchrocheck over two breakers, with 2LL VT connection). © Arcteq Relays Ltd IM00017...
  • Page 346 "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 IM00017...
  • Page 347 Instruction manual Version: 2.06 Figure. 5.4.4 - 175. System states. The following figures present simplified function block diagrams of the synchrocheck function. Figure. 5.4.4 - 176. Simplified function block diagram of the SYN1 and SYN2 function. © Arcteq Relays Ltd IM00017...
  • Page 348 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 IM00017...
  • Page 349 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 IM00017...
  • Page 350 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 IM00017...
  • Page 351 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 IM00017...
  • Page 352 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 IM00017...

  • Page 353: Milliampere Output Control

    Control → Device IO → mA outputs . The outputs are activated in groups of two: channels 1 and 2 are activated together, as are channels 3 and 4 (see the image below). Figure. 5.4.5 - 178. Activating mA output channels. © Arcteq Relays Ltd IM00017...
  • Page 354 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. 5.4.5 - 179. Example of the effects of mA output channel settings. © Arcteq Relays Ltd IM00017...

  • Page 355: 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 IM00017...
  • Page 356 • 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 IM00017...
  • Page 357 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 IM00017...
  • Page 358 Table. 5.4.6 - 265. 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 IM00017...
  • Page 359 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 IM00017...

  • Page 360: 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 IM00017...
  • Page 361 Table. 5.4.7 - 267. 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 IM00017...
  • Page 362 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. 5.4.7 - 183. Vector jump from the relay's point of view. © Arcteq Relays Ltd IM00017...
  • Page 363 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 IM00017...
  • Page 364 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 IM00017...

  • Page 365: Programmable Control Switch

    32 characters long. 0: User 1: Operator Access level for Determines which access level is required to be able to control the Mimic control Configurator Configurator programmable control switch via the Mimic. 3: Super user © Arcteq Relays Ltd IM00017...

  • Page 366: Analog Input Scaling Curves

    Range Step Default Description Analog input 0: Disabled Enables and disables the input. scaling 1: Activated Disabled 0: Disabled Enables and disables the scaling curve and the input Scaling curve 1...4 1: Activated Disabled measurement. © Arcteq Relays Ltd IM00017...
  • Page 367 The Nyquist rate states that the filter time constant must be at least double the period time of the disturbance process signal. For example, the value for the filter time constant is 2 seconds for a 1 second period time of a disturbance oscillation. © Arcteq Relays Ltd IM00017...
  • Page 368 1 0: Not 0: Not Allows the user to create their own curve with up to twenty (20) curve curvepoint used used points, instead of using a linear curve between two points. 3...20 1: Used © Arcteq Relays Ltd IM00017...

  • Page 369: Logical Outputs

    SCADA system (IEC 61850, Modbus, IEC 101, etc.). Logical inputs are volatile signals: their status will always return to "0" when the AQ-200 device is rebooted. 64 logical inputs are available. © Arcteq Relays Ltd IM00017...
  • Page 370 Table. 5.4.11 - 278. Logical input user description. Name Range Default Description User editable 1...31 Logical Description of the logical input. This description is used in several menu description LIx characters input x types for easier identification. © Arcteq Relays Ltd IM00017...

  • Page 371: Monitoring Functions

    • At least one of the three-phase currents are below the I low limit setting. • The ratio between the calculated minum and maximum of the three-phase currents is below the I ratio setting. © Arcteq Relays Ltd IM00017...
  • Page 372 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 IM00017...
  • Page 373 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 IM00017...
  • Page 374 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 IM00017...
  • Page 375 -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 IM00017...
  • Page 376 "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 IM00017...
  • Page 377 Figure. 5.5.1 - 190. 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 IM00017...
  • Page 378 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 IM00017...
  • Page 379 Figure. 5.5.1 - 194. 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 IM00017...
  • Page 380 Figure. 5.5.1 - 196. 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 IM00017...
  • Page 381 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 IM00017...

  • Page 382: 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. 5.5.2 - 198. 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 IM00017...
  • Page 383 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 IM00017...
  • Page 384 The voltage transformer supervision can also report several different states of the measured voltage. These can be seen in the function's INFO tab in the relay's HMI or in AQtivate. © Arcteq Relays Ltd IM00017...
  • Page 385 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 IM00017...
  • Page 386 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 IM00017...

  • Page 387: 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 IM00017...
  • Page 388 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 IM00017...
  • Page 389 Let us examine the settings, using a low-duty vacuum circuit breaker (ISM25_LD_1/3) manufactured by Tavrida 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 IM00017...
  • Page 390 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 IM00017...
  • Page 391 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 IM00017...

  • Page 392: 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 IM00017...
  • Page 393 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 IM00017...
  • Page 394 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 IM00017...
  • Page 395 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 IM00017...

  • Page 396: 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 IM00017...
  • Page 397 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 IM00017...
  • Page 398 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 IM00017...
  • Page 399 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 IM00017...
  • Page 400 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 IM00017...
  • Page 401 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 IM00017...
  • Page 402 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 IM00017...
  • Page 403 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 IM00017...
  • Page 404 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 405 Once clicked, the "Add graph" pop-up window appears (see the image below on the right). In the example the line-to-neutral voltages UL1, UL2 and UL3 are selected and moved to the window on the right. Confirm the selection by clicking the "OK" button. © Arcteq Relays Ltd IM00017...
  • Page 406 (manually or by dedicated signals). Events cannot be masked off. The user can select which event messages are stored in the main event buffer: ON, OFF, or both. © Arcteq Relays Ltd IM00017...

  • Page 407: Running Hour Counter

    1: Clear Table. 5.5.6 - 314. Event messages. Event block name Event name RHC1 Running hour counter ON RHC1 Running hour counter OFF RHC1 Running hour counter cleared ON RHC1 Running hour counter cleared OFF © Arcteq Relays Ltd IM00017...

  • Page 408: 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 IM00017...
  • Page 409 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 IM00017...
  • Page 410 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 IM00017...
  • Page 411 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 IM00017...

  • Page 412: Measurement Value Recorder

    Measured input The function block uses analog current and voltage measurement values. Based on these values, the relay calculates the primary and secondary values of currents, voltages, powers, and impedances as well as other values. © Arcteq Relays Ltd IM00017...
  • Page 413 XL12, XL23, XL31, RL1, RL2, RL3 The phase-to-phase and phase-to-neutral resistances, reactances and impedances. XL1, XL2, XL3 Z12, Z23, Z31 ZL1, ZL2, ZL3 Z12Ang, Z23Ang, Z31Ang, The phase-to-phase and phase-to-neutral impedance angles. ZL1Ang, ZL2Ang, ZL3Ang © Arcteq Relays Ltd IM00017...
  • Page 414 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 IM00017...
  • Page 415 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 IM00017...
  • Page 416 The user can select which event messages are stored in the main event buffer: ON, OFF, or both. Table. 5.5.8 - 317. Event messages. Event block name Event name VREC1 Recorder triggered ON VREC1 Recorder triggered OFF © Arcteq Relays Ltd IM00017...

  • Page 417: Sy Y St Stem Int 6 S Em Integra Egration Tion

    • Write multiple holding registers (function code 16) • Read/Write multiple registers (function code 23) The following data can be accessed using both Modbus/TCP and Modbus/RTU: • Device measurements • Device I/O • Commands • Events • Time © Arcteq Relays Ltd IM00017...

  • Page 418: Modbus I/O

    Defines the Modbus unit address for the selected I/O Module (A, B, or C). If this setting 0…247 address is set to "0", the selected module is not in use. Module x 0: ADAM-4018+ Selects the module type. type 1: ADAM-4015 © Arcteq Relays Ltd IM00017...

  • Page 419: 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 420: Goose

    → AQ-200 series → Resources). 6.1.5 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 421: 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 422: Dnp3

    Selects the variation of the double point signal. 1: Var 2 0: Var 1 1: Var 2 Group 20 variation (CNTR) 0: Var 1 Selects the variation of the control signal. 2: Var 5 3: Var 6 © Arcteq Relays Ltd IM00017...
  • Page 423 Determines the data reporting deadband settings for this 0.01…5000.00V 0.01V 200V voltage deadband measurement. Angle Determines the data reporting deadband settings for this 0.1…5.0deg 0.1deg 1deg measurement deadband measurement. Integration time 0…10 000ms Displays the integration time of the protocol. © Arcteq Relays Ltd IM00017...

  • Page 424: Iec 101/104

    The measurement scaling coefficients are available for the following measurements, in addition to the general measurement scaling coefficient: • Active energy • Reactive energy • Active power • Reactive power • Apparent power • Power factor • Frequency © Arcteq Relays Ltd IM00017...
  • Page 425 Determines the data reporting deadband settings for this 0.01…5000.00V 0.01V 200V voltage deadband measurement. Angle Determines the data reporting deadband settings for this 0.1…5.0deg 0.1deg 1deg measurement deadband measurement. Integration time 0…10 000ms Displays the integration time of the protocol. © Arcteq Relays Ltd IM00017...

  • Page 426: Spa

    With the Real-time signals to communication menu the user can report to SCADA measurements that are not normally available in the communication protocols mapping. Up to eight (8) magnitudes can be selected. The recorded value can be either a per-unit value or a primary value (set by the user). © Arcteq Relays Ltd IM00017...
  • Page 427 Cos (φ) of three-phase powers and phase powers. cosfiL2 cosfiL3 Impedances and admittances RL12, RL23, RL31 XL12, XL23, XL31 RL1, RL2, RL3 XL1, XL2, XL3 Phase-to-phase and phase-to-neutral resistances, reactances and impedances. Z12, Z23, Z31 ZL1, ZL2, ZL3 © Arcteq Relays Ltd IM00017...
  • Page 428 Displays the measured value of the selected magnitude of the selected slot. -10 000 000.000…10 000 Magnitude X 0.001 - 000.000 The unit depends on the selected magnitude (either amperes, volts, or per-unit values). © Arcteq Relays Ltd IM00017...

  • Page 429: Connections Of Aq-G257

    A A Q Q -G257 -G257 Instruction manual Version: 2.06 7 Connections and application examples 7.1 Connections of AQ-G257 Figure. 7.1 - 208. AQ-G257 variant without add-on modules. © Arcteq Relays Ltd IM00017...
  • Page 430 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 7.1 - 209. AQ-G257 variant with digital input and output modules. © Arcteq Relays Ltd IM00017...

  • Page 431: Application Examples And Their Connections

    A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 7.1 - 210. AQ-G257 application example with function block diagram. AQ-G257 Device I/O Add-on 6 (IL) 4 voltage 1...3 9 slots 4 (I0) channels Protection functions I2> CBFP Ih>...
  • Page 432 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 IM00017...

  • Page 433: 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 IM00017...
  • Page 434 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 IM00017...
  • Page 435 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 IM00017...
  • Page 436 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 IM00017...
  • Page 437 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 7.3 - 217. Example block scheme. © Arcteq Relays Ltd IM00017...

  • Page 438: Construction And Installa

    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. 8.1 - 218. Modular construction of AQ-X257-XXXXXXX-AAAAAAAAA © Arcteq Relays Ltd IM00017...
  • Page 439 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 440 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 IM00017...

  • Page 441: 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. 8.2 CPU module Figure. 8.2 - 221. CPU module. © Arcteq Relays Ltd IM00017...
  • Page 442 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 IM00017...

  • Page 443: Current Measurement Module

    Fine residual current measurement I02. A basic current measurement module with five channels includes three-phase current measurement inputs as well as coarse and fine residual current inputs. The CT module is available with either standard or ring lug connectors. © Arcteq Relays Ltd IM00017...

  • Page 444: Voltage Measurement Module

    (VTs) or directly to low-voltage systems secured by fuses. The nominal voltage can be set between 100…400 V. Voltages are calibrated in a range of 0…240 V, which provides ± 0.2 % inaccuracy in the same range. © Arcteq Relays Ltd IM00017...

  • Page 445: Digital Input Module (Optional)

    DIx + 3 DIx + 4 Common earthing for the first four digital inputs. DIx + 5 DIx + 6 DIx + 7 DIx + 8 X 10 Common earthing for the other four digital inputs. © Arcteq Relays Ltd IM00017...
  • Page 446 (NC) defines whether or not the digital input is considered activated when the digital input channel is energized. The diagram below depicts the digital input states when the input channels are energized and de- energized. © Arcteq Relays Ltd IM00017...
  • Page 447 Control → Device IO → Digital inputs → Digital input voltages . Table. 8.5 - 340. 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 IM00017...

  • Page 448: Digital Output Module (Optional)

    Table. 8.6 - 341. 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 IM00017...

  • Page 449: 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 IM00017...

  • Page 450: 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 IM00017...

  • Page 451: 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 IM00017...

  • Page 452: 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. 8.10 LC or RJ45 100 Mbps Ethernet communication module (optional) Figure. 8.10 - 231. LC and RJ45 100 Mbps Ethernet module connectors. © Arcteq Relays Ltd IM00017...

  • Page 453: 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 IM00017...
  • Page 454 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. 8.11 - 233. Example of a ring configuration. © Arcteq Relays Ltd IM00017...

  • Page 455: Double Rj45 10/100 Mbps Ethernet Communication Module (Optional)

    Figure. 8.11 - 234. Example of a multidrop configuration. 8.12 Double RJ45 10/100 Mbps Ethernet communication module (optional) Figure. 8.12 - 235. Double RJ-45 10/100 Mbps Ethernet communication module. Connector Description • IRIG-B input Two-pin connector © Arcteq Relays Ltd IM00017...

  • Page 456: Milliampere (Ma) I/O Module (Optional)

    For other redundancy options, please refer to the option card "LC 100 Mbps Ethernet communication module". Figure. 8.12 - 236. Example of a multidrop configuration. 8.13 Milliampere (mA) I/O module (optional) Figure. 8.13 - 237. Milliampere (mA) I/O module connections. © Arcteq Relays Ltd IM00017...

  • Page 457: 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. 8.14 - 238. Device dimensions. © Arcteq Relays Ltd IM00017...
  • Page 458 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 8.14 - 239. Device installation. © Arcteq Relays Ltd IM00017...
  • Page 459 A A Q Q -G257 -G257 Instruction manual Version: 2.06 Figure. 8.14 - 240. Panel cut-out and spacing of the IED. © Arcteq Relays Ltd IM00017...

  • Page 460: 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 IM00017...

  • Page 461: 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 IM00017...

  • Page 462: Power And Energy Measurement

    Inaccuracy 10 mHz 9.1.2 CPU & Power supply 9.1.2.1 Auxiliary voltage Table. 9.1.2.1 - 347. Power supply model A Rated values Rated auxiliary voltage 85…265 V (AC/DC) < 20 W Power consumption < 40 W © Arcteq Relays Ltd IM00017...

  • Page 463: Cpu Communication Ports

    Data transfer rate 100 MB System integration Cannot be used for system protocols, only for local programming Table. 9.1.2.2 - 350. Rear panel system communication port A. Port Port media Copper Ethernet RJ-45 Number of ports Features © Arcteq Relays Ltd IM00017...

  • Page 464: 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 IM00017...

  • Page 465: Cpu Digital Outputs

    Maximum wire diameter 2.5 mm 9.1.3 Option cards 9.1.3.1 Digital input module Table. 9.1.3.1 - 355. Technical data for the digital input module. Rated values Rated auxiliary voltage 5…265 V (AC/DC) Current drain 2 mA © Arcteq Relays Ltd IM00017...

  • Page 466: 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 IM00017...

  • Page 467: Milliampere Module (Ma Out & Ma In)

    Table. 9.1.3.4 - 360. 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 IM00017...

  • Page 468: Rtd Input Module

    Table. 9.1.3.7 - 363. 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 IM00017...

  • Page 469: Display

    ±20 ms Retardation time (overshoot) <30 ms Instant operation time Start time and instant operation time (trip): ratio = 2 Typically 25 ms ratio = 5 Typically 16 ms ratio = 10 Typically 12 ms Reset © Arcteq Relays Ltd IM00017...

  • Page 470: Non-Directional Earth Fault Protection (I0>; 50N/51N)

    <55 ms Reset Reset ratio 97 % of the pick-up current setting Reset time setting 0.010…10.000 s, step 0.005 s Inaccuracy: Reset time ±1.0 % or ±50 ms Instant reset time and start-up reset <50 ms © Arcteq Relays Ltd IM00017...

  • Page 471: Directional Overcurrent Protection (Idir>; 67)

    = 1.05…3 <50 ms Reset Reset ratio: - Current 97 % of the pick-up current setting - U1/I1 angle 2.0° Reset time setting 0.010…10.000 s, step 0.005 s Inaccuracy: Reset time ±1.0 % or ±50 ms © Arcteq Relays Ltd IM00017...

  • Page 472: Directional Earth Fault Protection (I0Dir>; 67N/32N)

    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: ±1.5 % or ±25 ms - IDMT operating time ±20 ms - IDMT minimum operating time Instant operation time © Arcteq Relays Ltd IM00017...

  • Page 473: Negative Sequence Overcurrent/ Phase Current Reversal/ Current Unbalance Protection (I2>; 46/46R/46L)

    <70 ms Reset Reset ratio 97 % of the pick-up setting Reset time setting 0.010…10.000 s, step 0.005 s Inaccuracy: Reset time ±1.5 % or ±60 ms Instant reset time and start-up reset <55 ms © Arcteq Relays Ltd IM00017...

  • Page 474: Harmonic Overcurrent Protection (Ih>; 50H/51H/68H)

    • Tripping: When using the harmonic overcurrent stage for tripping, please ensure that the operation time is set to 20 ms (DT) or longer to avoid nuisance tripping caused by the above- mentioned reasons. © Arcteq Relays Ltd IM00017...

  • Page 475: Circuit Breaker Failure Protection (Cbfp; 50Bf/52Bf)

    , setting step 0.01 %U Pick-up setting Inaccuracy: - Voltage ±1.5 %U Operating time Definite time function operating time setting 0.00…1800.00 s, setting step 0.005 s Inaccuracy: - Definite time (U ratio 1.05→) ±1.0 % or ±35 ms © Arcteq Relays Ltd IM00017...

  • Page 476: Undervoltage Protection (U<; 27)

    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): ratio 1.05→ <65 ms © Arcteq Relays Ltd IM00017...

  • Page 477: Neutral Overvoltage Protection (U0>; 59N)

    Reset ratio 97 % of the pick-up voltage setting Reset time setting 0.000 … 150.000 s, step 0.005 s Inaccuracy: Reset time ±1.0 % or ±50 ms Instant reset time and start-up reset <50 ms © Arcteq Relays Ltd IM00017...

  • Page 478: Sequence Voltage Protection (U1/U2>/<; 47/27P/59Np)

    CT1IL1, CT2IL1, VT1U1, VT2U1 Frequency reference 2 CT1IL2, CT2IL2, VT1U2, VT2U2 Frequency reference 3 CT1IL3, CT2IL3, VT1U3, VT2U3 Pick-up f> pick-up setting 10.00…70.00 Hz, setting step 0.01 Hz f< pick-up setting 7.00…65.00 Hz, setting step 0.01 Hz © Arcteq Relays Ltd IM00017...

  • Page 479: Rate-Of-Change Of Frequency Protection (Df/Dt>/<; 81R)

    ±20 mHz (I > 30 % of rated secondary) Operation time Definite time function operating time setting 0.00…1800.00 s, setting step 0.005 s Inaccuracy: - Definite time (I ratio +/- 50 mHz) ±1.5 % or ±110 ms (max. step size: 100 mHz) © Arcteq Relays Ltd IM00017...

  • Page 480: Machine Thermal Overload Protection (Tm>; 49M)

    Selectable between °C and °F Ambient temperature effect Linear or manually set curve k min. and max. range 0.01...5.00 × I , setting step 0.01 × I Ambient temperature min. and max. range –60…500 deg, setting step 1 deg © Arcteq Relays Ltd IM00017...

  • Page 481: Power Protection (P, Q, S>/<; 32)

    • With very small under power pick-up settings time delay inaccuracy might double. 9.2.1.16 Underimpedance protection (Z<; 21U) Table. 9.2.1.16 - 380. Technical data for the underimpedance function. Measurement inputs Phase current inputs: I (A), I (B), I Current inputs Voltage inputs © Arcteq Relays Ltd IM00017...

  • Page 482: Voltage-Restrained Overcurrent Protection (Iv>; 51V)

    Pick-up voltage setting (point 1 & 2) Inaccuracy: ±0.5 %I or ±15 mA (0.10…4.0 × I - Current - Voltage ±1.5 %U or ±30 mV Operation time Definite time function operating time setting 0.00…1800.00 s, setting step 0.005 s © Arcteq Relays Ltd IM00017...

  • Page 483: Stator Earth Fault Protection (U03Rd>; 64S)

    Start time and instant operation time (trip): ratio <0.95 <60 ms Reset Reset ratio 103 % of the pick-up voltage setting Reset time setting 0.010…150.000 s, step 0.005 s Inaccuracy: Reset time ±1.0 % or ±30 ms © Arcteq Relays Ltd IM00017...

  • Page 484: Resistance Temperature Detectors

    Instant operation time Start time and instant operation time (trip): - at least 0.01 below the setting <50 ms Reset Reset ratio 1.03 of the power factor setting Reset time <50 ms Not t e! e! © Arcteq Relays Ltd IM00017...

  • Page 485: Volts-Per-Hertz Overexcitation Protection (V/Hz>; 24)

    Phase current inputs: I (A), I (B), I Current inputs Voltage inputs Calclucated measurements Three-phase reactive power Pick-up Pick-up setting -1 000 000.00…0.00 kVar, setting step 0.01 kVar Inaccuracy: - Reactive power Typically <1.0 %Q © Arcteq Relays Ltd IM00017...

  • Page 486: Generator/Transformer Differential Protection (Idb>/Idi>/I0Dhv>/I0Dlv>; 87T/ 87N/87G)

    0.01…50.00 %, step 0.01 %, default 15.00 % harmonic blocking pick-up 0.01…50.00 %, step 0.01 %, default 35.00 % harmonic blocking pick-up Inaccuracy: ±3.0 %I or ±30 mA (0.10…4.0 × I - Differential current Instant operation time © Arcteq Relays Ltd IM00017...

  • Page 487: Arc Fault Protection (Iarc>/I0Arc>; 50Arc/50Narc) (Optional)

    <35 ms Not t e! e! • The maximum length of the arc sensor cable is 200 meters. 9.2.1.25 Voltage memory Table. 9.2.1.25 - 389. Technical data for the voltage memory function. Measurement inputs Voltage inputs © Arcteq Relays Ltd IM00017...

  • Page 488: Control Functions

    Operation time Reaction time <5 ms from receiving the control signal 9.2.2.2 Object control and monitoring Table. 9.2.2.2 - 391. Technical data for the object control and monitoring function. Signals Digital inputs Input signals Software signals © Arcteq Relays Ltd IM00017...

  • Page 489: Vector Jump (Δφ; 78)

    Voltage inputs U1, U2, U3 or U4 voltage channel RMS line-to-line or line-to-neutral voltages Voltage input magnitudes U3 or U4 voltage channel RMS Pick-up U diff < setting 2.00…50.00 %U , setting step 0.01 %U © Arcteq Relays Ltd IM00017...

  • Page 490: Monitoring Functions

    0.10…40.00 × I , setting step 0.01 × I difference 0.10…40.00 × I , setting step 0.01 × I ratio 0.01…100.00 %, setting step 0.01 % 0.01…100.00 %, setting step 0.01 % - I2/I1 ratio © Arcteq Relays Ltd IM00017...

  • Page 491: Voltage Transformer Supervision (60)

    Reset time setting 0.010…10.000 s, step 0.005 s Inaccuracy: Reset time ±2.0 % or ±80 ms Instant reset time and start-up reset <50 ms VTS MCB trip bus/line (external input) <50 ms Not t e! e! © Arcteq Relays Ltd IM00017...

  • Page 492: Circuit Breaker Wear Monitoring

    - Instant operating time, when I ratio 1.05 < Typically <25 ms < 3 Reset Reset time Typically <10 ms Reset ratio 97 % 9.2.3.5 Disturbance recorder Table. 9.2.3.5 - 398. Technical data for the disturbance recorder function. Recorded values © Arcteq Relays Ltd IM00017...

  • Page 493: Event Logger

    Between wire and earth: 4 kV, 1.2/50 µs Radiated RF electromagnetic field: f = 80…1 000 MHz, 10 V/m EN 60255-26, IEC 61000-4-3 Conducted RF field: f = 150 kHz…80 MHz, 10 V (RMS) EN 60255-26, IEC 61000-4-6 © Arcteq Relays Ltd IM00017...
  • Page 494 Temperature ranges Ambient service temperature range –35…+70 °C Transport and storage temperature range –40…+70 °C Other Altitude <2000 m Overvoltage category Pollution degree Casing and package Table. 9.3 - 405. Dimensions and weight. Without packaging (net) © Arcteq Relays Ltd IM00017...
  • Page 495 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 IM00017...

  • Page 496: Ordering Inf Dering Informa Ormation Tion

    Accessories Order code der code Descrip Description tion Not t e e Manufact Manufactur urer er External 6-channel 2 or 3 wires RTD Input Advanced ADAM-4015-CE Requires an external power module module, pre-configured Co. Ltd. © Arcteq Relays Ltd IM00017...
  • Page 497 Pressure and light point sensor unit (25,000 lux AQ-02B Max. cable length 200 m Arcteq Ltd. threshold) Pressure and light point sensor unit (50,000 lux AQ-02C Max. cable length 200 m Arcteq Ltd. threshold) © Arcteq Relays Ltd IM00017...

  • Page 498: Contact And R Ence Informa Ormation Tion

    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 IM00017...

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