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Arcteq AQ-L3 9 Series Manual

Line differential protection device
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AQ-L3x9
Line differential protection device
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Summary of Contents for Arcteq AQ-L3 9 Series

  • Page 1 AQ-L3x9 Line differential protection device Instruction manual...

  • Page 2: Table Of Contents

    6.4.3 Dead line detection (DLD) ..................149 6.4.4 Voltage transformer supervision (VTS)..............151 6.4.5 Current transformer supervision (CTS) ..............153 6.4.6 Synchrocheck (dV/da/df; 25) ................... 154 6.4.7 Auto-reclosing (MV) (79) ..................161 6.4.8 Auto-reclosing (HV) (79)..................166 6.4.9 Switch-on-to-fault ....................173 © Arcteq Relays Ltd IM00075...
  • Page 3 11.5 Tests and environmental conditions.................. 214 12 Or 12 Ordering inf dering informa ormation tion ............................................216 13 Contact and r 13 Contact and re e f f er erence inf ence informa ormation tion....................................217 © Arcteq Relays Ltd IM00075...
  • Page 4 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 5: Document Informa Ormation Tion

    • Technical data updated. • Order code updated. R R e e vision vision 1.05 1.05 Date February 2015 Changes • Current and voltage measurement descriptions revised. R R e e vision vision 1.06 1.06 Date March 2015 © Arcteq Relays Ltd IM00075...
  • Page 6 2.00 2.00 Date February 2023 • Updated the Arcteq logo on the cover. • An overall visual update for the manual's layout and design. • Added the "Safety information" chapter. • Added the "Abbreviations" chapter. Changes • Added the previously separate documents "AQ 300 Operator's manual" and "AQ 300 Web server description"...

  • Page 7: Safety Information

    Please note that although these warnings relate to direct damage to personnel and/or equipment, it should be understood that operating damaged equipment may also lead to further, indirect damage to personnel and/or equipment. Therefore, we expect any user to fully comply with these special messages. © Arcteq Relays Ltd IM00075...

  • Page 8: Abbr Bbre E Via Viations Tions

    C C V V T T capacitive voltage transformer direct current DI DI digital input(s) dead line detection digital output(s) electronic fast transients electromagnetic compatibility Ethernet Overboard electrostatic discharge human—machine interface IDMT IDMT inverse definite minimum time © Arcteq Relays Ltd IM00075...
  • Page 9 SCADA A supervisory control and data acquisition SDRAM synchronous dynamic random access memory single-line diagram SOTF switch-on-to-fault time multiplier setting V V T T voltage transformer V V T T S S voltage transformer supervision © Arcteq Relays Ltd IM00075...

  • Page 10: General

    This manual describes the specific application of the AQ-L3x9 line protection IED. Arcteq protection IED can be ordered in two mechanical sizes. The AQ-L359 comes in half of 19 inch rack arrangement and the AQ-L399 comes in full 19 inch rack arrangement allowing for larger quantity of IO cards.

  • Page 11: Ied User Interface Erface

    10Base-T Ethernet connection to the user's computer. Touch The main screen, a 3.5" (320 x 240 pixels) portrait-oriented TFT display with a resistive touch screen screen interface. Optionally, the touch screen can be 5.7" and landscape-oriented. © Arcteq Relays Ltd IM00075...

  • Page 12: Led Assignment

    It also supports single-line diagrams (SLD). The touch screen can be accessed and controlled remotely via the device's web interface. For more information on the remote user interface, please refer to "The embedded web server" chapter below. © Arcteq Relays Ltd IM00075...
  • Page 13 Main menu The main menu is the first one shown when the device is turned on. It displays general information such as the device and station names, the current time, and language options (when available). © Arcteq Relays Ltd IM00075...
  • Page 14 (see the image below) where you can enter the password. When the password is entered correctly, the lock status indicator on the main menu becomes unlocked, as does the menu in question. The device can be unlocked from any of the menus. © Arcteq Relays Ltd IM00075...

  • Page 15: Parameter Menu

    The parameter set that is currently active has a red box around it (see the figure below). When you want to edit or activate a parameter set, touching its name to select and highlight it and then press the "Edit" or "Activate" button. © Arcteq Relays Ltd IM00075...
  • Page 16 Back butt t on on returns you to the previous screen. Within all function blocks, the parameter values can have one of the following four types of input: • Integer A whole number, entered with the number pad. © Arcteq Relays Ltd IM00075...
  • Page 17 Make sure that only one person edits the parameters at any one time, either in the touch screen or in the web interface! Simultaneous editing leads to confusion as to what the values of a parameter set actually are. © Arcteq Relays Ltd IM00075...
  • Page 18 This allows you to take a closer look at the events. The first row of an event displays the function block's name, the second row displays the event's name and value, and the third row displays the event's time stamp (see the image below). © Arcteq Relays Ltd IM00075...
  • Page 19 In the system settings menu you can set certain parameter values that are related to the device itself (as opposed to its protection functions and operations). The menu works similarly to the parameters menu and the same properties apply. © Arcteq Relays Ltd IM00075...
  • Page 20 For example, let us say we have the following network depicted in the top-left image in the figure below as a single-line drawing. We have set the operation buttons to function as "ON" and "OFF", and now we would like to switch the line disconnecter Q2 on. © Arcteq Relays Ltd IM00075...

  • Page 21: The Embedded Web Server

    You can perform the following actions with the embedded web server: • modify user parameters • check the event list and disturbance records • manage the password • display the measured data and the generated binary information • perform commands © Arcteq Relays Ltd IM00075...

  • Page 22: System Requirements

    The following table catalogues the different Ethernet communication versions available for the different AQ-300 CPU versions. Table. 5.4.1 - 6. The available Ethernet communication in different CPU versions. CPU version Station Bus Redundant Station Bus Process Bus RJ45 Legacy port/protocol CPU+0001 Prep CPU+0002 Prep CPU+0003 © Arcteq Relays Ltd IM00075...
  • Page 23 IP address, the gateway address, the netmask, the DNS and NTP server addresses. W W eb br eb bro o wser se wser set t tings tings © Arcteq Relays Ltd IM00075...
  • Page 24 As seen in the beginning of this chapter, the CPU version "+0001" also has an integrated RJ4 port. When using a UTP crossover cable with RJ45 connectors at both ends, you can connect the device directly to a computer (see the figure below). © Arcteq Relays Ltd IM00075...
  • Page 25 Please note that the cable's RJ45 connector can also be connected to an Ethernet switch. When this is the case, all the network's IEDs with client functionalities (e.g. a computer) have access to the device. © Arcteq Relays Ltd IM00075...

  • Page 26: Getting Started

    Make sure you are connected to your AQ-300 device and that you have JavaScript enabled within your web browser. Type the IP address of the device into your browser's address bar to access its embedded web server (see the image below). © Arcteq Relays Ltd IM00075...
  • Page 27 The page automatically refreshes in the chosen language. Please note that changing the display language only affects the local browser, NOT other browser or the language of the touch screen. © Arcteq Relays Ltd IM00075...

  • Page 28: Menu Items

    The "Station bus MAC address" displays the network card's MAC address, which is a uniwue identification number assigned by Arcteq (the address range assigned by the IEEE authority). Please note that these fields are read-only and cannot be modified! ©...

  • Page 29: Parameters Menu

    A pop-up window notifies you if you have made changes and try to leave the page without saving them. Clicking Cancel Cancel returns you to the parameter page, whereas clicking OK OK ignores the changes. © Arcteq Relays Ltd IM00075...

  • Page 30: System Settings Menu

    (located below the menu bar on the left) enabled the device to use the values displayed on the screen at the time the button was clicked. Please note that if the device's IP address has changed, the device must first be accessed through the new IP address. © Arcteq Relays Ltd IM00075...
  • Page 31 If the "Time sync warning" parameter is enabled and the device synchronization is not synchronized, an alarm is raised (that is, the "Status" LED becomes yellow). Time zone Contains the settings to offset GMT and to define daylight savings time. settings © Arcteq Relays Ltd IM00075...
  • Page 32 HTML5, analogue measurements are drawn as vectors. Events menu This page displays the events that have occured in the device. The events are listed in the following format: [local time] : [function block] : [channel] : [new value]. © Arcteq Relays Ltd IM00075...

  • Page 33: Commands Menu

    If the command was unsuccessful, the device gives the reason for the error. Disturbance recorder This page displays a list of the disturbance records that the device has recorded. © Arcteq Relays Ltd IM00075...
  • Page 34 You can also click the V V ie iew w button to open a new browser window which then displays a simple preview of the disturbance record (see the image below). Figure. 5.4.3 - 26. Example of a disturbance record preview. © Arcteq Relays Ltd IM00075...
  • Page 35 Delet t e e button. You can upload a selected file with the Upload Upload button. Please ensure that the file size is below the limit and that you have enough storage left before commencing the upload. © Arcteq Relays Ltd IM00075...
  • Page 36 Figure. 5.4.3 - 30. Password manager. Stat t us/log us/log The Status/log submenu displays information from various logs. The log files are primarily meant for the manufacturer, but a user can also view them. Figure. 5.4.3 - 31. Status/log. © Arcteq Relays Ltd IM00075...
  • Page 37 "Relay DSP firmware" section with a "Comm. DSP firmware" file! This page also displays information about the firmware currently in use as well as of the configuration of the device. © Arcteq Relays Ltd IM00075...

  • Page 38: Troubleshooting

    If you notice improper functionalities, try to clear both the browser history and cache, and refresh the web page. If this does not clear the problem, please contact Arcteq for further instructions. © Arcteq Relays Ltd...

  • Page 39: Software Setup

    > Overfrequency protection TOF81_low f >> TUF81_high f < Underfrequency protection TUF81_low f << FRC81_high df/dt Rate of change of frequency protection FRC81_low BRF50MV CBFP 50BF Breaker failure protection DIFF87L IdL > Line differential protection © Arcteq Relays Ltd IM00075...

  • Page 40: Measurements

    Secondary I4. The options to choose from are 1A or 5A (in special applications, 0.2A or 1A). This parameter influences the internal number format and, naturally, accuracy. A small current is processed with finer resolution if 1A is selected. © Arcteq Relays Ltd IM00075...
  • Page 41 CT secondary 5A I0CT secondary 1A Phase current CT secondary currents starpoint is towards the line. Figure. 6.2.1 - 34. Example connection with phase currents connectef into summing "Holmgren" connection into the IO residual input. © Arcteq Relays Ltd IM00075...
  • Page 42 Table. 6.2.1 - 14. Floating point parameters of the current input function Parameter name Title Dim. Default Rated primary current of channel1-3 CT4_PriI13_FPar_ Rated Primary I1-3 4000 1000 Rated primary current of channel4 CT4_PriI4_FPar_ Rated Primary I4 4000 1000 © Arcteq Relays Ltd IM00075...

  • Page 43: Voltage Measurement And Scaling

    • perform the basic calculations ◦ Fourier basic harmonic magnitude and angle, ◦ True RMS value; • provide the pre-calculated voltage values to the subsequent software modules, • deliver the calculated basic Fourier component values for on-line displaying. © Arcteq Relays Ltd IM00075...
  • Page 44 Here, the primary rated voltage of the VT must be the value of the rated PHASE-TO-PHASE voltage. This option must not be selected if the distance protection function is supplied from the VT input. © Arcteq Relays Ltd IM00075...
  • Page 45 Rated secondary voltage of the input channels. 100 V or 200V type is selected by parameter setting, no hardware modification is needed. VT4_Type_EPar_ Range Type 100,Type 200 Type 100 Connection of the first three voltage inputs (main VT secondary) © Arcteq Relays Ltd IM00075...
  • Page 46 Fourier basic component of the voltage in channel UL1 Angle Ch - U1 degree Vector position of the voltage in channel UL1 Voltage Ch - U2 V(secondary) Fourier basic component of the voltage in channel UL2 © Arcteq Relays Ltd IM00075...

  • Page 47: Line Measurement

    SCADA system. Operation of the line measurement function block The inputs of the line measurement function are • the Fourier components and true RMS values of the measured voltages and currents • frequency measurement • parameters. © Arcteq Relays Ltd IM00075...

  • Page 48: Measured Values

    MXU_U3_OLM_ Voltage L3 MXU_U12_OLM_ Voltage L12 MXU_U23_OLM_ Voltage L23 MXU_U31_OLM_ Voltage L31 MXU_f_OLM_ Frequency Another example is in figure, where the measured values available are shown as on-line information in a configuration for compensated networks. © Arcteq Relays Ltd IM00075...
  • Page 49 Operation Current Off, Amplitude, Integrated Amplitude Selection of the reporting mode for voltage measurement MXU_URepMode_EPar_ Operation Voltage Off, Amplitude, Integrated Amplitude Selection of the reporting mode for frequency measurement MXU_fRepMode_EPar_ Operation Frequency Off, Amplitude, Integrated Amplitude © Arcteq Relays Ltd IM00075...
  • Page 50 MXU_QDeadB_FPar_ Deadband value - Q MVar 100000 0.01 Range value for the reactive power MXU_QRange_FPar_ Range value - Q MVar 100000 0.01 Deadband value for the apparent power MXU_SDeadB_FPar_ Deadband value - S 100000 0.01 © Arcteq Relays Ltd IM00075...
  • Page 51 (deadband*1sec) area. As an example, the figure below shows that the integral of the current in time becomes higher than the Deadband value multiplied by 1sec, this results “report2”, etc. © Arcteq Relays Ltd IM00075...
  • Page 52 Range value for the apparent power MXU_SRange_FPar_ Range value - S 100000 0.01 Deadband value for the current MXU_IDeadB_FPar_ Deadband value - I 2000 Range value for the current MXU_IRange_FPar_ Range value - I 5000 © Arcteq Relays Ltd IM00075...

  • Page 53: Protection Functions

    The basic calculation can be based on peak value selection or on Fourier basic harmonic calculation, according to the parameter setting. Figure. 6.3.1 - 40. Operating characteristics of the instantaneous overcurrent protection function. © Arcteq Relays Ltd IM00075...
  • Page 54 Operating mode selection of the function. Can be disabled, Peak value Peak Operation operating based into measured current peak values or operating Fundamental value based into calculated current fundamental frequency RMS values. value Start 20…3000 Pick-up setting of the function. current © Arcteq Relays Ltd IM00075...

  • Page 55: Residual Instantaneous Overcurrent Protection (I0>; 50N/51N)

    Decision logic module generates the trip signal of the function. Below is presented the structure of the instantaneous residual overcurrent algorithm. Figure. 6.3.2 - 43. The structure of the residual instantaneous overcurrent algorithm. © Arcteq Relays Ltd IM00075...

  • Page 56: Three-Phase Time Overcurrent Protection (I>; 50/51)

    IDMT additional time delay is passed from the start conditions. The operation of the function is phase wise and it allows each phase to be tripped separately. Standard operation is three poles. © Arcteq Relays Ltd IM00075...
  • Page 57 • G = measured value of the Fourier base harmonic of the phase currents • G = pick-up setting value • TMS = time dial setting / preset time multiplier The parameters and operating curve types follow corresponding standards presented in the table below. © Arcteq Relays Ltd IM00075...
  • Page 58 In following figures the characteristics of IDMT curves are presented with minimum and maximum pick- up settings in respect of the IED measuring range. Figure. 6.3.3 - 46. IEC - NI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. © Arcteq Relays Ltd IM00075...
  • Page 59 Figure. 6.3.3 - 47. IEC - VI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. Figure. 6.3.3 - 48. IEC - EI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. © Arcteq Relays Ltd IM00075...
  • Page 60 Figure. 6.3.3 - 49. IEC - LTI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. Figure. 6.3.3 - 50. IEEE/ANSI - NI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. © Arcteq Relays Ltd IM00075...
  • Page 61 Figure. 6.3.3 - 51. IEEE/ANSI - MI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. Figure. 6.3.3 - 52. IEEE/ANSI - VI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. © Arcteq Relays Ltd IM00075...
  • Page 62 Figure. 6.3.3 - 53. IEEE/ANSI - EI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. Figure. 6.3.3 - 54. IEEE/ANSI - LTI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. © Arcteq Relays Ltd IM00075...
  • Page 63 Figure. 6.3.3 - 55. IEEE/ANSI - LTVI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. Figure. 6.3.3 - 56. IEEE/ANSI - LTEI operating curves with minimum and maximum pick-up settings and TMS settings from 0.05 to 20. © Arcteq Relays Ltd IM00075...
  • Page 64 NI (normally inverse) 0.46 IEEE/ANSI MI (moderately inverse) 4.85 IEEE/ANSI VI (very inverse) 21.6 IEEE/ANSI EI (extremely inverse) 29.6 IEEE/ANSI LTI (long time inverse) IEEE/ANSI LTVI (long time, very inverse) 13.46 IEEE/ANSI LTEI (long time, extremely inverse) © Arcteq Relays Ltd IM00075...

  • Page 65: Residual Time Overcurrent Protection (I0>; 50N/51N)

    The residual definite time overcurrent protection function operates with definite time characteristics, using the RMS values of the fundamental Fourier component of the neutral or residual current (IN=3Io). In the figure below is presented the operating characteristics of the function. © Arcteq Relays Ltd IM00075...
  • Page 66 Trip signal is generated after the set definite time delay. The function includes a blocking signal input which can be configured by user from either IED internal binary signals or IED binary inputs through the programmable logic. © Arcteq Relays Ltd IM00075...

  • Page 67: Three-Phase Directional Overcurrent Protection (Idir>; 67)

    The inputs of the function are the Fourier basic harmonic components of the three phase currents and those of the three phase voltages. In the figure below is presented the structure of the directional overcurrent protection algorithm. © Arcteq Relays Ltd IM00075...
  • Page 68 If the angle difference between the vectors is outside of the set characteristics the directional decision is “Backward”. © Arcteq Relays Ltd IM00075...
  • Page 69 The default setting of 60 deg means that the total width of the operating angle is 120 deg. Characteristic Characteristic angle setting. Defines the center angle of the 40…90 deg 60 deg angle characteristic. © Arcteq Relays Ltd IM00075...

  • Page 70: Residual Directional Overcurrent Protection (I0Dir>; 67N)

    The inputs of the function are the Fourier basic harmonic components of the zero sequence current and those of the zero sequence voltage. In the figure below is presented the structure of the residual directional overcurrent algorithm. © Arcteq Relays Ltd IM00075...
  • Page 71 “Forward” mode.The protection function supports operating angle mode and also wattmetric and varmetric operating characteristics. © Arcteq Relays Ltd IM00075...
  • Page 72 Angle setting of Characteristic Angle = 0 deg and Operating Angle 30 deg Forward operating characteristic would be area inside +30 deg and –30 deg. Characteristic –180…180 The base angle of the operating characteristics. Angle © Arcteq Relays Ltd IM00075...

  • Page 73: Current Unbalance Protection (60)

    The applied method selects maximum and minimum phase currents (fundamental Fourier components). If the difference between them is above the setting limit, the function generates a start signal. Structure of the current unbalance protection function is presented in the figure below © Arcteq Relays Ltd IM00075...
  • Page 74 The function can be disabled by parameter setting, and by an input signal programmed by the user. The trip command is generated after the set defined time delay. © Arcteq Relays Ltd IM00075...

  • Page 75: Circuit Breaker Failure Protection (Cbfp; 50Bf/52Bf)

    “Pulse length”. The breaker failure protection function can be enabled or disabled by setting the parameter “Operation” to “Off”. Dynamic blocking is possible using the binary input “Block”. The conditions can be programmed by the user. © Arcteq Relays Ltd IM00075...
  • Page 76 Time delay for CBFP tripping command for the back-up breakers from Time 200 ms 000 ms the pick-up of the CBFP function monitoring. Delay Pulse 0…60 100 ms CBFP pulse length setting. length 000 ms © Arcteq Relays Ltd IM00075...

  • Page 77: Overvoltage Protection (U>; 59)

    6.3.10 Undervoltage protection (U<; 27) The undervoltage protection function measures three voltages. If any of them is below the set pick-up value and above the defined minimum level, then a start signal is generated for the phases individually. © Arcteq Relays Ltd IM00075...

  • Page 78: Residual Overvoltage Protection (U0>; 59N)

    6.3.11 Residual overvoltage protection (U0>; 59N) The residual definite time overvoltage protection function operates according to definite time characteristics, using the RMS values of the fundamental Fourier component of the zero sequence voltage (UN=3Uo). © Arcteq Relays Ltd IM00075...

  • Page 79: Thermal Overload Protection (T>; 49)

    “overtemperature” and the ambient temperature. The ambient temperature can be set manually. If the calculated temperature (calculated “overtemperature”+ambient temperature) is above the threshold values, status signals are generated: Alarm temperature, Trip temperature and Unlock/restart inhibit temperature. © Arcteq Relays Ltd IM00075...
  • Page 80 Temperature setting for the tripping of the overloading. When the Trip 60…200 calculated temperature exceeds the set alarm limit function issues a temperature trip signal. © Arcteq Relays Ltd IM00075...

  • Page 81: Line Differential Protection (87L) - Transformer Not In Protected Zone

    30 dB is permitted to prevent the disturbance of operation.) The hardware module applied is the CPU module of the AQ 300 series protection IED. The two devices are interconnected via the “process bus”. © Arcteq Relays Ltd IM00075...
  • Page 82 Fourier phasors and the result is the magnitude of the three differential currents.The parameters needed for the calculation are listed in table below. © Arcteq Relays Ltd IM00075...
  • Page 83 The parameters needed for the calculation are listed in the table above ("Current compensation parameters"). Line diff Line differ erential charact ential characteristics eristics The line differential characteristic is drawn in the figure below. © Arcteq Relays Ltd IM00075...
  • Page 84 Repeated errors are recognized and the function is disabled. This fact is signaled by the “CommFail” output signal. In error state, if healthy signals are resumed, then the system restarts operation automatically. Measured values The measured and displayed values of the line differential protection function © Arcteq Relays Ltd IM00075...

  • Page 85: Function Block

    Table. 6.3.13 - 41. The binary input signals of the line differential function. Binary input signal Explanation DIFF87L_D D iffBlk iffBlk_GrO_ Block DIFF87L_Send01 Send01_GrO_ Free configurable signal to be sent via communication channel DIFF87L_Send12 Send12_GrO_ Free configurable signal to be sent via communication channel © Arcteq Relays Ltd IM00075...

  • Page 86: Setting Parameters

    (For details see the document “Remote user interface description”.) Figure below shows the opened section for the “Process bus settings”. Select the parameters for both devices identically, as shown in this figure. © Arcteq Relays Ltd IM00075...

  • Page 87: Line Differential Protection (87L) - Transformer In Protected Zone

    Figure. 6.3.14 - 75. Structure of the line differential protection algorithm with transformer in protected zone. The inputs are • the Fourier base component values of three phase currents received from the remote end © Arcteq Relays Ltd IM00075...
  • Page 88 This module performs the necessary calculations for the evaluation of the “percentage differential characteristics”. This curve is the function of the restraint current, which is calculated based on the magnitude of the phase-shifted phase currents. The result of this calculation is needed for the decision logic. © Arcteq Relays Ltd IM00075...

  • Page 89: Individual Components

    I2Tshift) values of both sides respectively, using matrix transformation. The method of transformation is defined by the „Code” parameter, identifying the transformer vector group connection. The table below summarizes the method of transformation, according to the connection group of the transformers with two voltage levels. © Arcteq Relays Ltd IM00075...
  • Page 90 Instruction manual Version: 2.00 Table. 6.3.14 - 44. Vector shift compensation with transformation to the delta delta side. conn. Code Transformation of the local side currents Transformation of the remote side currents group Dy11 Dz10 © Arcteq Relays Ltd IM00075...
  • Page 91 (’). (The positive direction of the currents is directed in on both sides.) The current measuring software modules process these Fourier base harmonic values of the differential currents. The principal scheme of the vector group compensation Figure below shows the principal scheme of the vector shift compensation. © Arcteq Relays Ltd IM00075...
  • Page 92 The phase currents and the differential currents can be high in case of transformerenergizing, due to the current distortion caused by the transformer iron core asymmetricsaturation. In this case the second harmonic content of the differential current is applied todisable the operation of the differential protection function. © Arcteq Relays Ltd IM00075...
  • Page 93 The inputs are the basic, the second and the fifth harmonic Fourier components of the differential currents: The basic harmonic Fourier components of the differental currents: The second harmonic Fourier components of the differental currents: The fifth harmonic Fourier components of the differental currents: © Arcteq Relays Ltd IM00075...
  • Page 94 The module, which evaluates the differential characteristics, compares the magnitude of the differential currents and those of the restraint currents. For this calculation the current magnitudes are needed. These magnitudes are calculated in this module. © Arcteq Relays Ltd IM00075...
  • Page 95 The local currents after phase-shift: The remote currents after phase-shift: The outputs are the magnitude of the calculated currents: The magnitudes of the differential currents after phase-shift: The magnitudes of the local currents after phase-shift: © Arcteq Relays Ltd IM00075...
  • Page 96 “true” value if the differential currents in the individual phases are above the limit, defined by parameter setting. The decisions of the phases are connected in OR gate to result the general start status signal. © Arcteq Relays Ltd IM00075...
  • Page 97 • Unrestrained start signals of the differential characteristic module • Harmonic restraint signals of the 2nd harmonic restraint decision • Harmonic restraint signals of the 5th harmonic restraint decision • Disabling status signals defined by the user, using graphic equation editor DIF87L_Blk_GrO © Arcteq Relays Ltd IM00075...
  • Page 98 Substation “B” CT11.5 — 6000/1 A/A The rated current of the transformer: I1np = 546 A (primary side) I1n = 0.91 A (secondary side) Calculated current on the secondary side of the transformer: I2np = 132/11.5*546 A =6275 A © Arcteq Relays Ltd IM00075...

  • Page 99: Function Block

    The function block of the line differential function with transformer within protected zone is shown in figure bellow. This block shows all binary input and output status signals that are applicable in the AQtivate 300 software. © Arcteq Relays Ltd IM00075...
  • Page 100 DIFF87L_GenT _GenTr_ r_GrI_ General trip command Harmonic blocking DIFF87L_HarmBlk_ _HarmBlk_GrI_ Harmonic restr. Harmonic blocking Free configurable signals to be sent via communication channel DIFF87L_R _Rec01_ ec01_GrI_ Received Ch01 Free configurable signal received via communication channel © Arcteq Relays Ltd IM00075...
  • Page 101 On this figure k is the current ratio. The positive directions are supposed to be directed out of the transformer on both sides, as it is supposed by the differential protection. (If the directions suppose currents flowing through the transformer, then I2R input = kI/ √ 3(1-a © Arcteq Relays Ltd IM00075...
  • Page 102 Assume I current on the primary Y side between phases S and T. Figure. 6.3.14 - 86. Currents inside the transformer at ST fault on the Y side. On this figure k is the current ratio. The Y side currents are: © Arcteq Relays Ltd IM00075...
  • Page 103 Y ult on the Y side side Assume I fault current on the phase R in case of solidly grounded network. No power supply is supposed at the delta side: © Arcteq Relays Ltd IM00075...
  • Page 104 On the delta side there are no currents flowing out of the transformer: Assume I fault current at the Y side in phase R in case of solidly grounded neutral. Assume the power supply at the delta side: © Arcteq Relays Ltd IM00075...
  • Page 105 For the checking the positive directions defined in the Appendix is applied: Based on the figure "Currents in case of normal load (or three-phase fault)", the primary currents are: The transformed values of the primary side: © Arcteq Relays Ltd IM00075...
  • Page 106 Assume I fault current at the Y side of the transformer in phases S and T. According to the figure titled "Currents inside the transformer at ST fault on the Y side", the input currents from the primary side of the transformer: Transforming these currents: © Arcteq Relays Ltd IM00075...
  • Page 107 According to the figure titled "Currents inside the transformer at “st” fault on the delta side", the input currents to the differential protection are: These secondary side currents are transformed with the unit matrix, so only the turn's ratio has to be considered: © Arcteq Relays Ltd IM00075...
  • Page 108 Based on the figure titled "Currents inside the transformer at single phase fault at the Y side (Bauch effect)", the input currents from the Y side are: The transformation of the primary currents: The secondary currents can be seen in the above-mentioned figure: © Arcteq Relays Ltd IM00075...
  • Page 109 The transformation of these primary currents: The input currents from the delta side, based on the above-mentioned figure: These secondary currents are transformed with the unit matrix, so only the turn's ratio is considered: © Arcteq Relays Ltd IM00075...

  • Page 110: Setting Parameters

    The deviation of the frequency from the rated system frequency indicates unbalancebetween the generated power and the load demand. If the available generation is largecompared to the consumption by the load connected to the power system, then the systemfrequency is above the rated value. © Arcteq Relays Ltd IM00075...

  • Page 111: Underfrequency Protection (F<; 81U)

    No. 4 (busbar voltage) of the voltage input module. In some applications, the frequency is measured based on the weighted sum of the phase voltages. The accurate frequency measurement is performed by measuring the time period between two rising edges at zero crossing of a voltage signal. © Arcteq Relays Ltd IM00075...

  • Page 112: Rate-Of-Change Of Frequency Protection (Fd/Ft>/<; 81R)

    Table. 6.3.17 - 50. Setting parameters of the rate-of-change of frequency function. Setting Parameter value / Step Default Description range Operating mode selection for the function. Operation can be Operation either enabled "On" or disabled "Off". © Arcteq Relays Ltd IM00075...

  • Page 113: Pole Slip (78)

    “Pole slipping” as it is indicated in figure below on the impedance plane. (The stable swings return to the same quadrant of the impedance plane along lines “Stable swing”.) Figure. 6.3.18 - 90. Pole slipping. © Arcteq Relays Ltd IM00075...

  • Page 114: Main Features

    Figure. 6.3.18 - 91. Structure of the pole slipping algorithm. The inputs are • the Fourier components of three phase voltages • the Fourier components of three phase currents • binary inputs • parameters. The outputs are © Arcteq Relays Ltd IM00075...
  • Page 115 The following description explains the details of the individual components. Impedance calculation (Z_CALC) The impedance protection supplied by Arcteq Ltd. continuously measures the impedances in the three line-to-line measuring loops. The calculation is performed in the phase-to-phase loops based on the line-to-line voltages and the difference of the affected phase currents.
  • Page 116 Measured positive sequence impedance in the L3L1 loop Z_CALC includes three practically identical software modules for impedance calculation. The three routines for the phase-to-phase loops get line-to-line voltages calculated from the sampled phase voltages and they get differences of the phase currents. © Arcteq Relays Ltd IM00075...
  • Page 117 (“Dead time”).The procedure is processed for each line-to-line loop. The result is the setting of three internal status variables. This indicates that the calculated impedance performed the required number of pole slips. Figure. 6.3.18 - 94. Principal scheme of the quadrilateral characteristic decision. Input v Input val alues © Arcteq Relays Ltd IM00075...
  • Page 118 The trip logic module decides to generate the trip command. The condition is that at least two out of three phase-to-phase loops detect pole slip in a number required by parameter setting. And the function is not blocked or disabled. © Arcteq Relays Ltd IM00075...
  • Page 119 The current in phase L1 is sufficient for impedance calculation I L2 condition The current in phase L2 is sufficient for impedance calculation I L3 condition The current in phase L3 is sufficient for impedance calculation © Arcteq Relays Ltd IM00075...

  • Page 120: Teleprotection (85)

    The trip command is directed graphically to the appropriate input of the trip logic, which will energize the trip coil. Depending on the selected mode of operation, the simple binary signal sent and received via a communication channel can have several meanings: © Arcteq Relays Ltd IM00075...
  • Page 121 The signal is prolonged by a drop-down timer. Receipt of the signal at the other end initiates tripping in the local protection if it is in a started state. © Arcteq Relays Ltd IM00075...
  • Page 122 The signal is prolonged by a drop-down timer. Receipt of the signal at the other end initiates tripping if the local overreaching zone detects fault. Figure. 6.3.19 - 98. Permissive Underreach Transfer Trip with Overreach: Send signal generation. © Arcteq Relays Ltd IM00075...
  • Page 123 Figure. 6.3.19 - 100. Permissive Overreach Transfer Trip: Send signal generation. Figure. 6.3.19 - 101. Permissive Overreach Transfer Trip: Trip command generation. D D ir irectional comparison (D ectional comparison (Dir ir.Comparison) .Comparison) © Arcteq Relays Ltd IM00075...
  • Page 124 Receipt of the signal at the other end blocks the initiation of tripping of the local protection. The blocking signal received is prolonged if the duration of the received signal is longer than a specified minimal duration. © Arcteq Relays Ltd IM00075...
  • Page 125 The signal is transmitted when a fault is detected by the underreach protection. Receipt of the signal at the other end initiates tripping, independent of the local protection. © Arcteq Relays Ltd IM00075...

  • Page 126: Function Block

    Table. 6.3.19 - 62. The input and output signals of the teleprotection function block. Signal title Explanation Block Blocking signal Carrier fall Signal indicating the failure of the communication channel Receive opp. 1 Signal1 received from the opposite end © Arcteq Relays Ltd IM00075...

  • Page 127: Setting Parameters

    The current can be high during transformer energizing due to the current distortion caused by the transformer iron core asymmetrical saturation. In this case, the second harmonic content of the current is applied to disable the operation of the desired protection function(s). © Arcteq Relays Ltd IM00075...

  • Page 128: Stub Protection

    The stub protection function is basically a high-speed overcurrent protection function that is enabled by the open state of a circuit breaker or maybe an isolator. The inputs of the stub protection function are • The Fourier components of three phase currents © Arcteq Relays Ltd IM00075...
  • Page 129 Table. 6.3.21 - 66. The binary input status signals. Signal Binary input signal Explanation title Disabling the function The programmed True state of this input disables the operation of the STB50_Blk_ _Blk_GrO_ Disable function Activating the function © Arcteq Relays Ltd IM00075...

  • Page 130: Distance Protection

    Binary input signals and conditions can influence the operation: • Blocking/enabling • VT failure signal. Detection of power swing condition and out-of-step operation are available. The structure of the distance protection algorithm is described in figure below. © Arcteq Relays Ltd IM00075...
  • Page 131 I_COND calculates the current conditions necessary for the phase selection logic. • F F A A UL ULT L T LOCA OCAT T OR OR calculates the distance to fault after the trip command.The following description explains the details of the individual components. © Arcteq Relays Ltd IM00075...
  • Page 132 In case of a fault involving the earth (on a solidly grounded network), and if the earth current is over a certain level, the formula containing the complex earth fault compensation factor will be applied to calculate the correct impedance, which is proportional to the distance-to-fault. © Arcteq Relays Ltd IM00075...
  • Page 133 For example, in case of an L2L3 fault: In case of a phase-to-earth fault, the sampled phase voltage and the phase current modified by the zero sequence current have to be substituted: where: © Arcteq Relays Ltd IM00075...
  • Page 134 85% of the parameter setting value. In case of CVT swing detection; this calculation method has no effect on the operation of the distance protection function. Figure. 6.3.22 - 112. Impedance calculation principal scheme. © Arcteq Relays Ltd IM00075...
  • Page 135 1 RL1L2+j Measured positive sequence impedance in the L1L2 loop XL1L2 RL2L3+j Measured positive sequence impedance in the L2L3 loop XL2L3 RL3L1+j Measured positive sequence impedance in the L13L1 loop XL3XL1 © Arcteq Relays Ltd IM00075...
  • Page 136 DIS21_Imin_IPar_ (I minimum) and in case of phase-ground loops on parameters DIS21_I0Base_IPar_ (I0 Base sens.) and DIS21_I0Bias_IPar_ (I0 Bias). VTS Block Binary blocking signal due to error in the voltage measurement. © Arcteq Relays Ltd IM00075...
  • Page 137 If the decision is not possible (no voltage, no pre-fault voltage, no healthy phase voltage but directional decision is required), then the impedance is set to a value above the possible Calc(H) impedance setting R = 1 000 500 mΩ, X = 1 000 500 mΩ © Arcteq Relays Ltd IM00075...
  • Page 138 R = abs(R), X = abs(X) Calcula Calculation me tion method Calc(F thod Calc(F) ) If the voltage is not sufficient for a directional decision and no stored voltage samples are available, the impedance is set to a high value: © Arcteq Relays Ltd IM00075...
  • Page 139 Figure. 6.3.22 - 114. The characteristics of the distance protection in complex plane. If a measured impedance point is inside the polygon, the algorithm generates the true value of the related output binary signal. © Arcteq Relays Ltd IM00075...
  • Page 140 The result is the setting of 6 x 5 status variables, which indicate that the calculated impedance is within the processed characteristic, meaning that the impedance stage has started. © Arcteq Relays Ltd IM00075...
  • Page 141 Calculated impedance in the fault loop L3N using parameters of the zones individually RL1L2+j Calculated impedance in the fault loop L1L2 using parameters of the zones 1…5 XL1L2 individually RL2L3+j Calculated impedance in the fault loop L2L3 using parameters of the zones 1…5 XL2L3 individually © Arcteq Relays Ltd IM00075...
  • Page 142 This reference value is given as a parameter setting DIS21_LReact_FPar_. The calculated percentage value facilitates displaying the distance in kilometers if the total length of the line is correctly set by the parameter DIS21_Lgth_FPar_. © Arcteq Relays Ltd IM00075...
  • Page 143 Measured positive sequence impedance in the L3N loop, using the zero sequence ZL3 = RL3+j XL3 ohm current compensation factor for zone 1 ZL1L2 = Measured positive sequence impedance in the L1L2 loop RL1L2+j XL1L2 © Arcteq Relays Ltd IM00075...
  • Page 144 The binary input and output status signals of the dead line detection function are listed in tables below. Table. 6.3.22 - 78. The binary input signals of the distance protection function. Binary input signal Signal title Explanation DIS21_VTS_GrO_ Block from VTS Blocking signal due to error in the voltage measurement © Arcteq Relays Ltd IM00075...

  • Page 145: Control, Monitoring And Measurements

    6.4 Control, monitoring and measurements 6.4.1 Common function The AQ300 series devices – independently of the configured protection functions – have some common functionality. The Common function block enables certain kind of extension this common functionality: © Arcteq Relays Ltd IM00075...
  • Page 146 The Common function block has binary input signals. The conditions ar The conditions are de e defined b fined by the user appl y the user applying ying the graphic logic edit the graphic logic editor or. . © Arcteq Relays Ltd IM00075...
  • Page 147 Output 3 to indicate the state of group 3 as Local Common_Remote3_GrI_ Remote 3 Output 3 to indicate the state of group 3 as Remote Common_Local4_GrI_ Local 4 Output 4 to indicate the state of group 4 as Local © Arcteq Relays Ltd IM00075...

  • Page 148: Trip Logic (94)

    Figure. 6.4.2 - 122. Operation logic of the trip logic function. The trip requirements can be programmed by the user. The aim of the decision logic is todefine a minimal impulse duration even if the protection functions detect a very short-timefault. © Arcteq Relays Ltd IM00075...

  • Page 149: Application Example

    #2 has been assigned as MV side trip to activate trip contact E04. The trip contact assignments can be modified or the same trip logic can activate multiple contacts by adding a new trip assignment. Figure. 6.4.2 - 125. Instructions on adding/modifying trip assignment. © Arcteq Relays Ltd IM00075...

  • Page 150: Setting Parameters

    Figure. 6.4.3 - 126. Principal scheme of the dead line detection function. The function block of the dead line detection function is shown in figure bellow. This block shows all binary input and output status signals that are applicable in the AQtivate 300 software. © Arcteq Relays Ltd IM00075...
  • Page 151 Operating mode selection for the function. Operation can be either Operation disabled "Off" or enabled "On". Min. 10…100 Minimum voltage threshold for detecting the live line status. All operate 60 % measured phase to ground voltages have to be under this setting level. voltage © Arcteq Relays Ltd IM00075...

  • Page 152: Voltage Transformer Supervision (Vts)

    Thus, the “VTS Failure” signal remains active at reclosing. • If the “Dead line” state is started and the “VTS Failure” signal has not been continuous for at least 100 ms, then the “VTS failure” signal resets. © Arcteq Relays Ltd IM00075...
  • Page 153 The function block of voltage transformer supervision function is shown in figure below. This block shows all binary input and output status signals that are applicable in the graphic equation editor. © Arcteq Relays Ltd IM00075...

  • Page 154: Current Transformer Supervision (Cts)

    If the difference between them is above the setting limit, the function generates a start signal. For function to be operational the highest measured phase current shall be above 10 % of the rated current and below 150% of the rated current. © Arcteq Relays Ltd IM00075...

  • Page 155: Synchrocheck (Dv/Da/Df; 25)

    If the conditions for safe closing cannot be fulfilled within an expected time, then closing is declined. NOTICE! TICE! For capacitive reference voltage measurement, the voltage measurement card can be ordered with <50 mVA burden special input. © Arcteq Relays Ltd IM00075...
  • Page 156 Started closing procedure can be interrupted by a cancel command defined by the user. In “bypass” operation mode, the function generates the release signals and simply transmits the close command. In the following figure is presented the operating logic of the synchrocheck function. © Arcteq Relays Ltd IM00075...
  • Page 157 (VTS Block). The activation of voltage transformer supervision function of the selected bus section blocks the operation (VTS Bus1 Block or VTS Bus2 Block). Figure. 6.4.6 - 133. Synchrocheck common difference calculation function structure. © Arcteq Relays Ltd IM00075...
  • Page 158 First, the function tries switching with synchro check. This is possible if: the voltage difference is within the defined limits (Udiff SynChk Auto/Manual)) the frequency difference is within the defined limits (FrDiff SynChk Auto) and the phase angle difference is within the defined limits (MaxPhaseDiff Auto/ Manual)). © Arcteq Relays Ltd IM00075...
  • Page 159 Switching request signal initiated by the automatic reclosing SYN25_SwStA_GrO_ Auto function. SYN25_CancelA_GrO_ Cancel Auto Signal to interrupt (cancel) the automatic switching procedure. SYN25_Blk_GrO_ Block Blocking signal of the function. SySwitch SYN25_SwStM_GrO_ Switching request signal initiated by manual closing. Manual © Arcteq Relays Ltd IM00075...
  • Page 160 "Live". Voltage setting limit for "Dead line" detection. When measured U Dead 10…60 % 30 % voltage is below the setting value the line is considered "Dead". © Arcteq Relays Ltd IM00075...
  • Page 161 "Off" manual switch checking is disabled. If selection is "ByPass" Operation manual switching is enabled with bypassing the bus and line ByPass energization status checking. When the selection is "On" also the energization status of bus and line are checked before processing the command. © Arcteq Relays Ltd IM00075...

  • Page 162: Auto-Reclosing (Mv) (79)

    Following additional requirements apply to performing automatic reclosing: • The automatic reclosing function can be blocked with any available signal or combination of signals defined by user. © Arcteq Relays Ltd IM00075...
  • Page 163 The timer parameters for earth faults are: 1. Dead Time EF 2. Dead Time EF 3. Dead Time EF 4. Dead Time EF In case of evolving faults, the dead times depend on the first fault detection. © Arcteq Relays Ltd IM00075...
  • Page 164 The conditions to start the dynamic blocked state are: • There is no trip command during the “Action time”. • The duration of the starting impulse for the MV automatic reclosing function is too long. © Arcteq Relays Ltd IM00075...

  • Page 165: Setting Parameters

    Reclosing reclosing or perform three-phase automatic reclosing cycle). 3Ph Rec. CB State Enabled Disabled Enable CB state monitoring for "Not Ready" state. monitoring Disabled Reclaim 100…100 000 2 000 ms Reclaim time setting. time © Arcteq Relays Ltd IM00075...
  • Page 166 4 000 ms Time 1 PH phase fault. Accelerate Enabled Disabled Acceleration of the 1 reclosing cycle trip command. 1. Trip Disabled Accelerate Enabled Disabled Acceleration of the 2 reclosing cycle trip command. 2. Trip Disabled © Arcteq Relays Ltd IM00075...

  • Page 167: Auto-Reclosing (Hv) (79)

    In case of a manual close command which is assigned to the logic variable REC79_ManCl_GrO_ (Manual Close) using graphic equation programming, a preset parameter value decides how long the HV automatic reclosing function should be disabled after the manual close command. © Arcteq Relays Ltd IM00075...
  • Page 168 (as a consequence of multi- phase faults). The timer parameters for single-phase trip commands are: • REC79_1PhDT1_TPar_ 1. Dead Time 1Ph • REC79_1PhDT2_TPar_ 2. Dead Time 1Ph © Arcteq Relays Ltd IM00075...
  • Page 169 The three-phase cycles are controlled by the status variable REC79_3PhTr_GrO_ (3Ph Trip). If this is TRUE, three-phase cycles are performed. The conditions are defined by the user applying the graphic equation editor. © Arcteq Relays Ltd IM00075...
  • Page 170 If fault is detected after the expiry of this timer, then the cycles restart with the first reclosing cycle. © Arcteq Relays Ltd IM00075...
  • Page 171 This signal needs user-programmed graphic equations to generate the accelerated trip command. © Arcteq Relays Ltd IM00075...
  • Page 172 “CB open” and the circuit breaker is in Open state. • In case of a general block. In a “Not ready” state, the REC79_Blocked_GrI_ (Blocked) status signal is TRUE (similar to “Dynamic blocking” conditions). © Arcteq Relays Ltd IM00075...
  • Page 173 Time limitation of the starting signal. Max.Tim DeadTime 0…1 000 000 3 000 ms Delaying the start of the dead-time counter. Max.Delay 10…1 000 000 Supervision 1 000 ms Waiting time for circuit breaker ready signal. Time © Arcteq Relays Ltd IM00075...

  • Page 174: Switch-On-To-Fault

    This means that the voltage samples stored in the memory have zero values. In this case the decision on the trip command is based on the programming of the protection function for the “switch- onto-fault” condition. © Arcteq Relays Ltd IM00075...

  • Page 175: Arcteq Relays Ltd

    • ManSOTF cond Signal enabling switch-onto-fault detection as a consequence of a manual close command. Figure. 6.4.9 - 137. The function block of the switch-on-to-fault function. Table. 6.4.9 - 96. The timer parameter of the function. Parameter Title Unit Step Default Drop-off time delay for the output signals. © Arcteq Relays Ltd IM00075...

  • Page 176: Voltage Variation (Voltage Sag And Swell)

    • Voltage interruption, when the RMS value of the measured voltage is below a minimum level specified by a parameter. For the evaluation, the duration of the voltage interruption should be between a minimum and a maximum time value defined by parameters. Figure. 6.4.10 - 140. Voltage interruption. © Arcteq Relays Ltd IM00075...
  • Page 177 The sag and swell detection algorithm offers measured values, status signals and counter values for displaying: • The duration of the latest detected short-time voltage variation • Binary signals: ◦ Swell ◦ Sag ◦ Interruption • Timer values: ◦ Sag counter ◦ Swell counter © Arcteq Relays Ltd IM00075...

  • Page 178: Disturbance Recorder

    The pre-fault time, max-fault time and post-fault time can be defined by parameters. © Arcteq Relays Ltd IM00075...
  • Page 179 Downloading can be initiated from a web browser tool or from the software tools.This procedure assures that the three component files (.cfg, .dat and .inf) are stored in the same location. The evaluation can be performed using any COMTRADE evaluator software, e.g. Arcteq’s AQview software. Consult your nearest Arcteq representative for availability.

  • Page 180: Event Recorder

    (TOC67) hig OC67) high h se set t ting sta ting stage Start L1 Start signal in phase L1 Start L2 Start signal in phase L2 Start L3 Start signal in phase L3 Start Start signal © Arcteq Relays Ltd IM00075...
  • Page 181 Low setting stage start signal in phase L2 Low Start L3 Low setting stage start signal in phase L3 Low General Start Low setting stage general start signal Low General Trip Low setting stage general trip command © Arcteq Relays Ltd IM00075...
  • Page 182 The function releases manual close command In progress Man The manual close command is in progress Close_Man Close command in manual mode of operation A A ut utoma omatic r tic reclosing function (REC79) eclosing function (REC79) © Arcteq Relays Ltd IM00075...
  • Page 183 Close command is enabled Enable Open Open command is enabled Local Local mode of operation Operation counter Operation counter DC OPCap D D isconnect isconnector Ear or Earth th Status value Status of the earthing switch © Arcteq Relays Ltd IM00075...

  • Page 184: Measured Values

    RMS value of the Fourier fundamental harmonic current component in phase L1 Angle Ch – I1 Phase angle of the Fourier fundamental harmonic current component in phase L1* Current Ch – I2 RMS value of the Fourier fundamental harmonic current component in phase L2 © Arcteq Relays Ltd IM00075...
  • Page 185 True RMS value of the voltage in phase L3 Voltage L12 True RMS value of the voltage in phase L1L2 Voltage L23 True RMS value of the voltage in phase L2L3 Voltage L31 True RMS value of the voltage in phase L3L1 © Arcteq Relays Ltd IM00075...

  • Page 186: Status Monitoring For Switching Devices

    All four fast acting trip contacts contain build-in trip circuit supervision function. The output voltage of the circuit is 5V (+-1V). The pickup resistance is 2.5kohm (+-1kohm). CAUTION! UTION! Pay attention to the polarity of the auxiliary voltage supply as outputs are polarity dependent. © Arcteq Relays Ltd IM00075...

  • Page 187: Line Diff Ential Communica A Tion Applic Tion Applica A Tions Tions

    Long-haul applications up to 35 dB line attenuation, that is 100...120 km in practice, the single mode 1550 nm fiber can be used. Figure. 7.1 - 144. Direct link communication scheme. Via LAN/Telecom network Figure. 7.1 - 145. LAN/Telecom network communication scheme. © Arcteq Relays Ltd IM00075...

  • Page 188: Pilot Wire Application

    2...4 mA @ 47 V DC Table. 7.2 - 103. Ethernet interface specification. Standard IEEE 802.3, VLAN IIEEE 802.1Q, QoS IEEE 802.1P Data Rate 100Base-TX, Full/Half Duplex Interface/connector Type @ Europrot+ side Multi-mode 1310 nm, ST connector © Arcteq Relays Ltd IM00075...

  • Page 189: Line Differential Communication Via Telecom Networks

    Communication via C37.94 N×64 kbit/s interface The IEEE C37.94 standard describes the N time 64 kbit/s optical fiber interface between teleprotection and multiplexer equipment. The data rate can be 1...12×64 kbit/s with 64 kbit/s steps. © Arcteq Relays Ltd IM00075...
  • Page 190 Mbit/s interface (E1). Besides E1 in European networks, the T1 interface (1.54 Mbit/s) in America is also available. Figure. 7.3 - 149. G.703/704 communication scheme. Connector type: Weidmüller Impedance: 75/120 Ω Cable length: 50 m Interface type: G.703 1.544 Mbit/s (T1) or 2.048 Mbit/s (E1), selectable grounding © Arcteq Relays Ltd IM00075...

  • Page 191: Redundant Line Differential Comunication

    Redundant communication also supported by AQ 300 devices. The high speed 100Base-FX link is used as main channel and G.703.1 leased or dedicated line as backup link. An extra communication card needs to be added to the AQ 300 IED for this kind of redundancy, consult your nearest Arcteq representative for availability.

  • Page 192: Three Terminal Line Differential Communication

    IEDs can be implemented. Communication channel in this case is Ethernet 100Base-Fx. The three terminal line differential protection scheme can tolerate the link failure of one of the three communication channels between the devices. Figure. 7.5 - 152. Three terminal line differential communication scheme. © Arcteq Relays Ltd IM00075...

  • Page 193: System Integration

    The AQ L3x9 line protection IED communicates using IEC 61850, IEC 101, IEC 103, IEC 104, Modbus RTU, DNP3.0 and SPA protocols. For details of each protocol refer to respective interoperability lists. For IRIG-B time synchronization binary input module O12 channel 1 can be used. © Arcteq Relays Ltd IM00075...

  • Page 194: Block Diagrams

    - Glass and Plastic Fiber - RS-485 CPU+ 0001 Remote Comm 1 - IEC-61850 F.O. ST - Modbus TCP Remote - Modbus RTU Comm 2 - IEC-103 F.O. ST Service - SpaBus RJ-45 Local Panel Opt.Eth. AQ-L359_Min_Connection © Arcteq Relays Ltd IM00075...

  • Page 195: Protection Functions

    DI 9 Service - SpaBus DI 10 RJ-45 DI 11 Local DI 12 Panel Opt.Eth. AQ-L359_Full_Connection 9.2 Connection example NOTICE! TICE! While the connection example below is for AQ-L359, AQ-L399 is connected in the same way. © Arcteq Relays Ltd IM00075...
  • Page 196 A A Q Q -L3x9 -L3x9 9 Connections Instruction manual Version: 2.00 Figure. 9.2 - 155. Connection example of AQ-L359 line protection IED. © Arcteq Relays Ltd IM00075...

  • Page 197: Construction And Installation Tion

    10 Construction and installation 10.1 Construction The Arcteq AQ-L3x9 line protection IED consists of hardware modules. Due to its modular structure the optional positions for the slots can be user defined in the ordering of the IED to include I/O modules and other types of additional modules.

  • Page 198: Cpu Module

    Each processor has its own operative memory such as SDRAM and flash memories for configuration, parameter and firmware storage. CDSP’s operating system (uClinux) utilizes a robust JFFS flash file system, which enables fail-safe operation and the storage of disturbance record files, configuration and parameters. © Arcteq Relays Ltd IM00075...

  • Page 199: Power Supply Module

    • Efficiency: >70 %. • Passive heat sink cooling. • Early power failure indication signals to the CPU the possibility of power outage, thus the CPU has enough time to save the necessary data to non-volatile memory. © Arcteq Relays Ltd IM00075...

  • Page 200: Binary Input Module(S)

    • Rated input voltage: 110/220 V DC. • Clamp voltage: falling 0.75 Un, rising 0.78 Un. • Digitally filtered per channel. • Current drain approx.: 2 mA per channel. • 12 inputs. • IRIG-B timing and synchronization input. © Arcteq Relays Ltd IM00075...

  • Page 201: Binary Output Module(S)

    The binary output modules are: • Rated voltage: 250 V AC/DC. • Continuous carry: 8 A. • Breaking capacity, (L/R = 40 ms)at 220 V DC: 0.2 A • 8 contacts: 7 NO and 1 NC © Arcteq Relays Ltd IM00075...

  • Page 202: Tripping Module

    • Rated voltage: 110 V, 220 V DC. • Continuous carry: 8 A. • Making capacity: 0.5 s, 30 A. • Breaking capacity (L/R = 40 ms) at 220 V DC: 4A. • Trip circuit supervision for each trip contact. © Arcteq Relays Ltd IM00075...

  • Page 203: Voltage Measurement Module

    • Power consumption of voltage input: ≤1 VA at 200 V (with special CVT module the burden is < 50 mVA for VT4 channel). • Relative accuracy: ±0.5 %. • Frequency measurement range: ±0.01 % at Ux 25 % of rated voltage. • Measurement of phase angle: 0.5º Ux 25 % of rated voltage. © Arcteq Relays Ltd IM00075...

  • Page 204: Current Measurement Module

    • Thermal withstand: ◦ 20 A (continuously) ◦ 500 A (for 1 s) ◦ 1200 A (for 10 ms) • Relative accuracy: ±0.5 %. • Measurement of phase angle: 0.5º, Ix 10 % rated current. © Arcteq Relays Ltd IM00075...

  • Page 205: Installation And Dimensions

    A A Q Q -L3x9 -L3x9 10 Construction and installation Instruction manual Version: 2.00 10.9 Installation and dimensions Figure. 10.9 - 164. Dimensions of AQ-x35x IED. © Arcteq Relays Ltd IM00075...
  • Page 206 A A Q Q -L3x9 -L3x9 10 Construction and installation Instruction manual Version: 2.00 Figure. 10.9 - 165. Panel cut-out and spacing of AQ-x35x IED. Figure. 10.9 - 166. Dimensions of AQ-x39x IED. © Arcteq Relays Ltd IM00075...
  • Page 207 A A Q Q -L3x9 -L3x9 10 Construction and installation Instruction manual Version: 2.00 Figure. 10.9 - 167. Panel cut-out and spacing of AQ-x39x IED. © Arcteq Relays Ltd IM00075...

  • Page 208: Technic Echnical Da Al Data Ta

    Peak value calculation Fourier calculation Three-phase time overcurrent protection I> (50/51) Pick-up current inaccuracy < 2% Operation time inaccuracy ±5% or ±15ms Reset ratio 0.95 Minimum operating time with IDMT 35ms Reset time Approx 35ms Transient overreach © Arcteq Relays Ltd IM00075...
  • Page 209 Reset ratio 0.95 Minimum operating time with IDMT 35ms Reset time Approx 35ms Transient overreach Pickup time 25 – 30ms Angular inaccuracy <3° Residual directional overcurrent protection function I0Dir> (67N) Pick-up current inaccuracy < 2% © Arcteq Relays Ltd IM00075...
  • Page 210 Operate time inaccuracy + 15 ms Overfrequency protection function f> (81O) Operating range 40 - 60 Hz Operating range inaccuracy 30mHz Effective range inaccuracy 2mHz Minimum operating time 100ms Operation time inaccuracy + 10ms Reset ratio 0,99 © Arcteq Relays Ltd IM00075...
  • Page 211 Voltage effective range 2…110% of Un Operation inaccuracy (current & voltage) ±1% 0.1 – 200 Ohm (In =1A) Impedance effective range 0.1 – 40 Ohm (In = 5A) Impedance operation inaccuracy ±5% 48…52Hz Zone static range 49.5…50.5Hz © Arcteq Relays Ltd IM00075...

  • Page 212: Control Functions

    Voltage effective range 10-110 % of Un Voltage inaccuracy ±1% of Un Frequency effective range 47.5 – 52.5 Hz Frequency inaccuracy ±10mHz Phase angle inaccuracy ±3 ° Operate time inaccuracy ±3ms Reset time <50ms Reset ratio 0.95 © Arcteq Relays Ltd IM00075...

  • Page 213: Monitoring Functions

    Pick-up voltage inaccuracy Operation time inaccuracy <20ms Reset ratio 0.95 Trip logic (94) Impulse time duration accuracy <3ms 11.4 Hardware Power supply module 80-255VAC Input voltage 90-300VDC Nominal voltage 110VDC/220VDC Maximum interruption 100ms Maximum power consumption © Arcteq Relays Ltd IM00075...

  • Page 214: Binary Input Module

    ≤ 0.5 º at Ux ≥ 25% of rated voltage Binary input module Rated voltage Un 110 or 220Vdc (ordering option) Number of inputs per module 12 (in groups of 3) Current drain approx. 2mA per channel © Arcteq Relays Ltd IM00075...

  • Page 215: Tests And Environmental Conditions

    = 80….1000 MHz 10V /m class III) - Conducted RF field (According. to EN 61000-4-6, class III) f = 150 kHz….80 MHz 10V Voltage tests Insulation test voltage acc- to IEC 60255-5 2 kV, 50Hz, 1min © Arcteq Relays Ltd IM00075...

  • Page 216: Mechanical Tests

    IP 54 (with optional cover) 5kg net (AQ-x35x devices) 6kg net (AQ-x39x devices) Weight 6kg with package (AQ-x35x devices) 7kg with package (AQ-x39x devices) Environmental conditions Specified ambient service temp. range -10…+55°C Transport and storage temp. range -40…+70°C © Arcteq Relays Ltd IM00075...

  • Page 217: Ordering Inf Dering Informa Ormation Tion

    A A Q Q -L3x9 -L3x9 12 Ordering information Instruction manual Version: 2.00 12 Ordering information Visit https://configurator.arcteq.fi/ to build a hardware configuration, define an ordering code and get a module layout image. © Arcteq Relays Ltd IM00075...

  • Page 218: Contact And Reference Information

    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 IM00075...

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