GE Multilin 565 Instruction Manual
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GE Multilin 565 Instruction Manual

Feeder management relay
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CANADA
215 Anderson Avenue, Markham, Ontario, L6E 1B3
Tel: (905) 294-6222 Fax: (905) 294-8512
565/575
FEEDER MANAGEMENT RELAY
Instruction Manual
Software Rev: E2.73
Manual P/N: 1601-0017-E6
Copyright 1996 GE Multilin
USA
9746 Whithorn Dr., Houston, Texas, 77095
Tel: (713) 855-1000
®
Fax: (713) 859-1091

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  • Page 1 565/575 ® FEEDER MANAGEMENT RELAY Instruction Manual Software Rev: E2.73 Manual P/N: 1601-0017-E6 Copyright 1996 GE Multilin CANADA 215 Anderson Avenue, Markham, Ontario, L6E 1B3 9746 Whithorn Dr., Houston, Texas, 77095 Tel: (905) 294-6222 Fax: (905) 294-8512 Tel: (713) 855-1000...

  • Page 2: Table Of Contents

    AEG MODICON MODBUS PROTOCOL ....7-6 Setpoint Programming ..........1-1 Memory Map Information ......... 7-11 Inputs ................. 1-1 Metering Specification - 565 with MTM ....7-23 Outputs ..............1-1 SECTION 8: RELAY TESTING Memory Features ............1-1 Primary Injection Testing ..........8-1 Typical Applications ............

  • Page 3: Section 1: Introduction

    LCD display to guide Outputs the user. A “help” menu is available at all times. Six electromechanical output relays are included in the 565/ 575 Relay. These are named Trip, Close, Aux. 1, 2, 3, and 4. Relay Features These relays can be allocated various functions, by using the flexibility of the software programming.

  • Page 4: Ordering Information

    To order the Feeder Protection Relays you must specify it as Additional features may be available for special orders. Con- shown in Figure 1.1. tact GE MULTILIN for further details. Many features of the Relay are field programmable. Those Figure 1.1 Order Codes...

  • Page 5: Section 2: Installation

    The shipping container should contain your Relay and this 1. 90-260 VAC and 95-280 VDC manual. Inspect the unit and inform GE MULTILIN of any 2. 20-60 VDC damage. If re-shipment is required the original container and packing should be used.
  • Page 6 INSTALLATION Figure 2.1 Mounting Details...
  • Page 7 INSTALLATION Figure 2.2 Mounting Arrangement with Relay Collar...

  • Page 8: Breaker Status And Control Connections

    67. trip coil supervision. It is not programmable. After each 565/575 Relay is assigned a unique address, the master device (computer) can read measured values or Aux 4 Contacts store setpoints.

  • Page 9: Analog Output Terminals

    4-20 mA or 0-1 mA to correspond from zero to full scale. When terminals 39 and 40 are “open”, the 565/575 relay is operating in Local Mode. If this is the case, terminals 26, 27, Using the analog select terminals 19-22, and 71, outputs can and 28 will have no effect upon either the Close (terminals 42 be selected by placing a binary code on inputs A-D.

  • Page 10: Metering Transducer Module

    INSTALLATION Metering Transducer Module 1. Remove the 565/575 Relay inner chassis from the outer case. Failure to remove the relay from the outer case can cause failure of the relay. The Metering Transducer Module is an optional unit which gives the 565/575 additional functionality. The mounting ar- 2.
  • Page 11 68 ** MTM RS485 "+" 33 ** Access Switch "+" 69 ** MTM RS485 "-" 575 only 34 ** Access Switch "-" IRIG-B Voltage Input V1 Analog Select Common Voltage Input V2 Ext. Switch Common ** 565 requires Option Card...
  • Page 12 INSTALLATION Figure 2.5 565 Relay Typical Wiring...
  • Page 13 INSTALLATION Figure 2.6 Voltage Sensing Wire...
  • Page 14 INSTALLATION Figure 2.7A 565 with MTM CT and Open Delta VT Typical Wiring 2-10...
  • Page 15 INSTALLATION Figure 2.7B 565 with MTM CT and Wye VT Typical Wiring 2-11...
  • Page 16 INSTALLATION Figure 2.8A Open Delta VT and CT MTM Typical Wiring 2-12...
  • Page 17 INSTALLATION Figure 2.8B Wye VT and CT MTM Typical Wiring 2-13...
  • Page 18 INSTALLATION Figure 2.9 MTM Mounting Dimensions 2-14...
  • Page 19 INSTALLATION Figure 2.10 565 Rear Panel Layout 2-15...

  • Page 21: Section 4: Display And Keyboard

    In actual values mode, any of the parameters monitored by tion of the 565/575 Relay. the 565/575 Relay can be viewed by the user. The message lines in each page of this mode are shown and explained in the Actual Values Mode section of this manual.
  • Page 22 This display mode should be used whenever help is required access terminals, the following message will appear: in using the 565 relay. It is entered by pressing the HELP key while the display is on any line in any page. The HELP key can...
  • Page 23 DISPLAY AND KEYBOARD Figure 4.1 565 Relay Front Panel...
  • Page 24 As with the LINE keys, holding down the PAGE key will cause the pages to be displayed rapidly. The STORE key is used to store all new setpoints in the 565/575 Relay’s memory. When this key is pressed, the value being displayed will be stored as a new setpoint in the relay’s memory and the...
  • Page 25 DISPLAY AND KEYBOARD Number Name Description RESET IMPOSSIBLE ALARM PRESENT The HELP key provides the user with information on the function and use of each key on the keypad. It also provides information about the currently displayed actual values or setpoints message. If information is needed on the use of any of the keys on the keypad, use the LINE UP or PAGE key to display the first line of any page.
  • Page 26 The remaining curves can be viewed in the same way. The display will cycle through all the curves as the key is pressed. Note that the curve in use by the 565/575 Relay will not be changed by displaying the various choices. To change the curve in use, it must be displayed and stored. See the STORE key description.
  • Page 27 DISPLAY AND KEYBOARD Number Name Description The display is a 32 character alphanumeric type. This display visually shows in English all values, setpoints, and messages, through a series of lines within the pages of 3 display modes: Actual Values, Setpoints, and Help.

  • Page 29: Default Message Selection

    ACTUAL VALUES MODE All the messages displayed by the 565/575 Relay in the Default Message Selection actual values mode are listed and explained in this section. As already seen, the messages are laid out in book form with The default message is the message which will be displayed pages containing lines, each of which displays one message.

  • Page 30: Summary Of Actual Value Page Contents

    ACTUAL VALUES MODE Summary of Actual Value Page Contents Page Contents Page Contents Current Data. Demand Metering Data. Phase currents Peak demand amps Ground currents Peak KW demand Peak KVAR demand Analog Input Data. Metering Data. Analog input scaled values Power factor MTM frequency Maintenance Data.

  • Page 31: Actual Values

    A 1.1 The actual values page 1 header. This page gives information on the ACTUAL VALUES feeder phase and ground currents being monitored by the 565 Relay. CURRENT A 1.2 This is the actual monitored RMS current flowing in phase A of the feeder.
  • Page 32 Location Message Line Description A 2.1 The actual values page 2 header. The 565/575 Relay can accept an analog ACTUAL VALUES signal from 4 to 20 mA from any device such as a temperature monitor, ANALOG INPUT and provide trip or alarm signals at a user programmed value. The value of this temperature, for example, is displayed in this page in whatever units you select in the setpoints mode.
  • Page 33 ACTUAL VALUES MODE - MAINTENANCE DATA Location Message Line Description A 3.1 The actual values page 3 header. This page allows the maintenance ACTUAL VALUES related data, which the Relay has collected, to be viewed. This data MAINTENANCE DATA remains in memory even if the control power is removed from the Relay. Information on the number of breaker trips and accumulated breaker trip current is stored on this page for use in scheduling breaker maintenance.
  • Page 34 10,000. If the maximum number of trips exceeds 10,000, *** will be displayed. A 4.2 This is the number of times that the feeder breaker controlled by the 565/ TIMED PHASE O/C 575 Relay has been tripped due to the current flowing through it exceeding TRIPS the timed phase overcurrent level set up in the setpoints mode.
  • Page 35 It also gives data on the PRE-TRIP DATA condition of the feeder when a trip was last initiated by the 565/575 Relay. This page can be viewed immediately after an alarm or trip to determine its cause.
  • Page 36 This display indicates that the trip was caused by the analog input to the ANALOG INPUT 565 Relay exceeding the limits specified in setpoints mode. If a name was TRANS WNDG TEMP assigned to this analog input in setpoints mode, then this name will appear in the message.
  • Page 37 Messages A 5.9 to 5.11 will only appear if an Open Delta system is chosen in Setpoints mode. A 5.9 This is the voltage between phases A and B when the 565 Relay caused PRE-TRIP VOLTAGE the feeder breaker to trip due to a system fault.
  • Page 38 ACTUAL VALUES MODE - PRE-TRIP DATA Location Message Line Description A 5.18 The last line of page 5, actual values. Press the PAGE key to view page 6. PRE-TRIP DATA END OF PAGE 4-10...
  • Page 39 Option Card is installed, see METERING DATA page in Actual Values for frequency reading. A 6.8 This is the frequency of the feeder voltage being monitored by the 565/575 FREQUENCY OF Relay. The frequency measurements are also enhanced. They are accu- FEEDER 60.1 Hz...
  • Page 40 This message shows an example of "other" event - Serial Trip. This SERIAL TRIP message is displayed if the breaker is closed when the 565/575 receives O 03/17/94 11:14 the Modbus Serial Trip command. If the breaker is open when this Serial Trip command is issued, it will be ignored.
  • Page 41 ACTUAL VALUES MODE - EVENT Location Message Line Description LINE DOWN key to continue to the next message. A 7.12 This message prompts the user to erase the event data displayed on this CLEAR EVENTS? page. A 7.13 This message shows users when events were last cleared. EVENTS CLEARED LAST:AUG 04,1992 A 7.14...
  • Page 42 DATA CLEARED LAST:AUG 04,1992 The following messages are only displayed if a Metering Transducer Module (MTM) has been connected to the 565/575, an Option Card has been installed in the 565, and the communications has been enabled. Message A 8.8 will appear only if the KW Demand feature has been disabled.
  • Page 43 ACTUAL VALUES MODE - DEMAND DATA Location Message Line Description Message A 8.12 will only appear if KVAR Demand has been disabled in setpoints. A 8.12 This message informs the user that KVAR Demand has been disabled. KVAR DEMAND DISABLED Message A 8.13 will only appear if the KVAR Demand feature has been enabled.
  • Page 44 The MWhrs should be cleared after 65,000 in order USED DATA? to ensure safe operation. MWh data on MTM can be cleared now by using 565/575 Relay's keypad or Modbus communication command. A 9.7 The last line of METERING DATA page. This is the last page of ACTUAL METERING DATA VALUES.

  • Page 45: Section 6: Setpoints Mode

    LCD display on When more than one relay is selected as shown, all the the front panel of the unit. The 565 Relay has two user levels, selected relays will be energized simultaneously. The con- “basic”...
  • Page 46 SETPOINTS MODE Maximum Minimum, or Minutes Moderately Milliseconds Metering Transducer Module Overcurrent OVERVOLT Overvoltage Power Factor Revision Secondary, or Second Switch UNDERVOLT Undervoltage VOLTS Voltage Voltage Transformer × P/U Multiple of Pickup Level ZERO SEQ Zero Sequence...

  • Page 47: Summary Of Setpoint Page Contents

    Analog output range Phase overcurrent trip relay Phase overcurrent alarm Phase instantaneous trip (565 only) Communications setpoints. Phase custom curve trip times (565 only) Phase HISET instantaneous trip (575 only) Relay address Phase autoblock HISET (575 only) Baud rate Phase LOSET instantaneous trip (575 only) Phase custom curves 1 trip times (575 only) Calibration Mode setpoints.
  • Page 48 SETPOINTS MODE Summary of Setpoint Page Contents Page Contents Page Contents MTM Metering setpoints. MTM communications alarm MTM CT select MTM CT primary rating Power factor alarm Power factor trip Frequency alarm Frequency trip MTM scaling factor Voltage reversal trip Auto Reclosure setpoints.
  • Page 49 Aux1, Aux2, and Aux1&2 (575: None, Aux1, Aux2, Aux1&2) Phase Inst Trips Enabled. Enabled/Disabled Phase Inst Trip Level 3.0 × P/U (565) 1 to 18 Phase Inst Trip Delay Inst. (565) 0 (Inst.) to 40 cycles 1 cycle Phase Inst Trip Relay Trip.
  • Page 50 External Trip #2 Disabled. Disabled, SW1 to SW8 External Trip #2 Relay Trip & Aux1. Trip, Aux1, Aux2, Trip&Aux1, Trip&Aux2, Aux1&2, and Trip&Aux1&2 (565) External Trip #2 Delay 0 cyc. 0 (Inst.) to 60 cycles 1 cyc External Trip #3 Disabled.
  • Page 51 Normally Open (inactive). Open/Closed Output Relay Operation. Trip Relay Pulsed. (565) Latched/Pulsed Trip Relay Pulse Time 0.6 Sec. (565) 0.1 to 0.6 sec 0.1 sec Aux1 Relay Unlatched. (Pulsed for 575) Latched, Unlatched, and Pulsed Aux1 Relay Pulse Time 0.6 Sec. (0.1 Sec. for 575) 0.1 to 0.6 sec...
  • Page 52 2400 BAUD. 1200, 2400, 4800, and 9600 Baud 8. Calibration Mode setpoints. Exercise Relay Trip. Trip, Aux1, Aux2, Aux3, and All (565) Trip, Aux1, Aux2, Aux3, Aux4, Block Tap Changer, and All (575) (Status of Switch Inputs) LCD Display Contrast 0 to 10 9.
  • Page 53 SETPOINTS MODE Location Message Line Description Amp Demand Alarm Relay Aux1. (Aux2 for 575) Aux1, Aux2, Aux1&2 (575: None, Aux1, Aux2, Aux1&2) KW Demand Enabled. Enabled/Disabled KW Demand Time Period 5 Min. 5 to 120 Min 1 Min KW Demand Alarm Disabled.
  • Page 54 SETPOINTS MODE Setpoint Name Factory Setpoint Range Step Phase Curve Change Disabled. Enabled/Disabled Switch to Curve 2 After Recls. 1 to 4 Phase O/C Curve 2 Shape EXTREM INV. MOD INV, NORMAL INV, VERY INV, EXTREM INV, and CUSTOM2 Phase O/C Time Dial 2 1 to 32 Trip Time 2 (sec) ×...

  • Page 55: Setpoints

    Basic and Advanced. If the Basic level is chosen, then the user will only ADVANCED see those messages essential to the setup of the 565/575 relay. If the Advanced level is chosen, all the features of the relay will be made available to the user.
  • Page 56 S 1.9 This is a flash message that appears for two seconds to tell the user that NEW ACCESS CODE the new access code is now stored in the 565’s memory. STORED S 1.10 This is the last line of page 1, setpoints. Press PAGE to view page 2.

  • Page 57: Installation Of Security Feature

    SETPOINTS MODE Installation of Security Feature: Use of Access Code: STEP 1 : Display message S 1.3 “Security Feature”. Press STEP 1 : Display message S 1.4 “SETPOINT ACCESS”. NEXT CHOICE to display enabled and press store. Press NEXT CHOICE to display enabled and press STORE.
  • Page 58 For example, if 50% is entered here, then the 565/575 Relay will initiate a timed trip of the feeder breaker when at least one of the phase currents reaches 50% of the full CT rating entered in message S 2.2.
  • Page 59 1). 0.5 to 3 in steps of 0.1. If a value which is not an exact multiple of 0.1 or 0.5 is entered, the 565 Relay will select the closest number to the value entered, display and use it.
  • Page 60 RELAY TRIP&AUX1 (575) Messages S 2.15 to S 2.22 pertain to the 575 only. The remaining messages beginning at S 2.23 are for both the 565/575. S 2.15 This setpoint allows the user to enable or disable the phase autoblock PH AUTOBLK INST HISET feature.
  • Page 61 SETPOINTS MODE - PHASE CURRENT Location Message Line Description Message S 2.22 will only appear if ENABLED is selected in message S 2.21. S 2.22 Determines after which reclosure the PHASE LOSET INST TRIP will be PH AUTOBLK LOSET disabled (blocked). AFTER RECL.# Messages S 2.23 and S 2.24 will only appear if CUSTOM CURVE1 was selected in message S 2.4.
  • Page 62 CT rating. The range of values allowed is 5% to 150% in steps of 1%. This PICKUP 40% CT setpoint sets the level of current at which the 565 Relay initiates a timed trip of the feeder breaker according to the curve selected in message S 3.6.
  • Page 63 A level of 1 times pickup can be programmed. The LCD will then indicate when the Relay is operating above pickup. For example, if 0.5 is entered here, then the 565 Relay will initiate an alarm when the ground current reaches 50% of the pickup level entered in message S 3.5.
  • Page 64 RELAY TRIP&AUX1 (575) Messages S 3.17 to S 3.24 are specific to the 575 only. The remaining messages beginning with S 3.25 are for both the 565/ 575. S 3.17 This setpoint allows the user to enable or disable the ground autoblock GND AUTOBLK INST hiset feature.
  • Page 65 SETPOINTS MODE - GROUND CURRENT Location Message Line Description S 3.19 Set to ENABLED to enable loset ground element. GND LOSET INST TRIPS ENABLED Messages S 3.20 to S 3.24 will only appear if ENABLED is selected in message S 3.19. S 3.20 Same as GND HISET INST TRIP feature.
  • Page 66 (conducting) in the inactive state. This information must be given to the 565 Relay if it is to use these inputs. Other features such as the time and date are also setup on this page.
  • Page 67 S 4.10 The switch being configured can be used to activate one of the internal DEFINITE TIME #1 relays in the 565 Relay. This message is asking you to select the relay or RELAY AUX2 relays which the definite time function will activate. There are two relays to which the signal can be sent, called Aux.1 and 2.
  • Page 68 Location Message Line Description The following are messages specific to the 565; messages specific to the 575 will be indicated as required. S 4.16 This message asks for any time delay needed on the operation of the EXTERNAL TRIP #1 switch.
  • Page 69 S 4.26 This message allows the contact sense of the selected switch to be SW.1 CONTACT: entered into the 565 Relay’s memory. Determine whether the switch is NORMALLY OPEN normally open or normally closed from the manufacturer’s data or system (565/575) wiring diagram.
  • Page 70 When the fault current eventually drops below pick up, the 565 seal-in timer is initiated. After this 2.5 - 3.5 cycle seal-in delay elapses, the Trip relay de-energizes.
  • Page 71 Pulsed Operation If pulsed operation is selected, the Aux 1 relay is energized and the pulse timer is initiated upon a trip/alarm declaration. In order for the 565 to determine that the breaker has opened successfully, two conditions must be met. First, the fault current must be below pick up. Secondly, either the 52a contact must be detected as open or the 52b contact must be detected as closed.
  • Page 72 SETPOINTS MODE - CONFIGURATION Location Message Line Description OUTPUT FACEPLATE MODBUS READ EXCEPTION CONDITION AUX. 1 RELAY AUX. 1 LED STATUS NO ALARM DE-ENERGIZED ALARM PULSES (Alarm Level < Curr. < P/U) (Brkr. Open) ALARM ENERGIZED (Curr. > Alarm & P/U Level) ALARM DE-ENERGIZED (Curr.
  • Page 73 0.6 SEC minimum length of time that the relay will be energized. The range of (565) values for this setpoint is 0.1 to 0.6 seconds in steps of 0.1 seconds. Message S4.33 will only appear if pulsed operation is assigned to the Aux . 2 relay.
  • Page 74 SETPOINTS MODE - CONFIGURATION Location Message Line Description OUTPUT FACEPLATE MODBUS READ EXCEPTION CONDITION AUX. 2 RELAY AUX. 2 LED STATUS NO TRIP DE-ENERGIZED TRIPPED PULSES (Current > P/U) TRIPPED DE-ENERGIZED FLASHING (Current < P/U) KEYPAD RESET DE-ENERGIZED OUTPUT FACEPLATE MODBUS READ EXCEPTION CONDITION AUX.
  • Page 75 DELAY 1 mS breaker contacts. After the time delay specified, the 565/575 will begin to accumulate the KA value of the breaker interruption. Determine this quantity from the breaker manufacturer’s data of breaker opening time.
  • Page 76 The CLOSE relay was activated but the breaker remained open. A breaker discrepancy causes the reclosure scheme to immediately lockout. This message appears if ENABLED is selected in S 4.36 but the 565 does OPTION NOT not have the option card installed.
  • Page 77 SETPOINTS MODE - CONFIGURATION Location Message Line Description S 4.46 This message allows the user to enable or disable the Metering Transducer MTM COMM.: Module (MTM) communications. ** Available only with Option Card ** ENABLED S 4.47 The last line of page 4, setpoints. Press the PAGE key to view page 5. CONFIGURATION END OF PAGE 5-33...
  • Page 78 If this value is 50 degrees centigrade, for example, then set the minimum scale factor at 50. Now when a 4 mA input is presented to the 565 Relay it will display 50 indicating a temperature, which is more useful than a milliamp reading.
  • Page 79 This line allows the user to specify at what level of the input analog signal ANALOG IN TRIP the 565 Relay will initiate a trip of the feeder breaker. The level must be 16.00 UNITS entered within the range of the scaled values, see messages S 5.7 and 5.8.
  • Page 80 SETPOINTS MODE - ANALOG INPUT Location Message Line Description S 5.17 The last line of page 5, setpoints. Press the PAGE key to view page 6. ANALOG INPUT END OF PAGE 5-36...
  • Page 81 This message appears for two seconds to indicate that the analog output ANALOG OUTPUT parameter can now be specified. The 565 Relay is capable of sending out PARAMETER any one of 8 actual values as analog quantities from its Analog Out terminal on the rear of the unit.
  • Page 82 Description S 7.1 The setpoints page 7 header. This page contains setpoints which affect SETPOINTS how the 565 Relay communicates with other devices. COMMUNICATIONS S 7.2 This message is used to assign each relay a different address or number RELAY ADDRESS to distinguish it from all other relays being used in a serial communication link.
  • Page 83 S 8.1 The setpoints page 8 header. This page is used to test the operation of the SETPOINTS 565 switch inputs and output relays. As well, the LCD display contrast can CALIBRATION MODE be adjusted on this page. S 8.2 This message is used to test the operation of the output relay contacts.
  • Page 84 S 8.15 This message is used by ser vice personnel for calibration and service of SERVICE USE ONLY the 565 Relay. It is not intended for use by other than MULTILIN personnel. CODE S 8.16 The last line of page 8, setpoints. Press the PAGE key to view page 9.
  • Page 85 S 9.5 When enabled, this setpoint allows undervoltage alarms and trips to occur ZERO VOLTS with the 565/575 reading all phase voltages as zero. For the 565/575, zero DETECT ENABLED is when the voltage is below 48% of the nominal rating. When disabled, all phases reading below 48% are considered a normal no voltage condition.
  • Page 86 80 %VT drop in feeder voltage indicates a system fault. The 565/575 Relay monitors the phase voltages while the breaker is closed and provides a trip signal if the level drops to the value which you enter here. The range of possible settings for the undervoltage setpoint is 50% to 100% of the VT rating in steps of 1%.
  • Page 87 S 9.19 The overvoltage alarm level is entered here as a percentage of the VT OVERVOLT ALARM rating. The 565 Relay monitors the phase voltages and provides an alarm LEVEL 115 %VT if the level rises to the level which you enter here. The range of possible settings for the overvoltage alarm setpoint is 101% to 125% of the VT rating in steps of 1%.
  • Page 88 The peak demand amps is updated only when the demand window current average exceeds the previous stored peak value. The 565/575 also allows the user to select and store an alarm level for peak demand which can be assigned to an output relay.
  • Page 89 SETPOINTS MODE - DEMAND METERING Location Message Line Description Messages S 10.10 and S 10.11 will only appear if the Demand KW Alarm feature is enabled in message S 10.9. S 10.10 The kW Demand alarm level is specified here. The range is 100 to 65000 KW DEMAND ALARM kW in steps of 100 kW.
  • Page 90 The setpoints page 11 header. In this page the MTM related setpoints are SETPOINTS entered. MTM METERING This message appears if ENABLED is selected in S 11.1 but the 565 does OPTION NOT not have the option card installed. AVAILABLE The following messages will only be displayed if the Metering Transducer Module (MTM) has been enabled in page 4 of setpoints.
  • Page 91 SETPOINTS MODE - MTM METERING Location Message Line Description S 11.11 This message allows the user to enable or disable the trip feature for the POWER FACTOR Power Factor. TRIP DISABLED Messages S 11.12 to S 11.15 appear only if the Power Factor Trip feature has been enabled in message S 11.11. S 11.12 The leading trip level is chosen here.
  • Page 92 The 565/575 Relay provides only Trip Relay Output and Programmable Trip Delay. The Phase Reversal Trip of the 565/575 is independent of the Phase Reversal setpoint in the MTM/MTM Plus. This means that whether the setpoint is ENABLED or DISABLED in the MTM/MTM Plus, the 565/575 still polls for and receives report on phase reversals.
  • Page 93 SETPOINTS MODE - AUTORECLOSURE Auto-Reclosure Application for 575 nth reclosure attempt. For example, Phase Lowset Instanta- neous trips may be blocked after the nth reclosure to allow whatever is causing the fault to burn off at a higher fault current level than that allowed by the Phase Lowset setting. 1.
  • Page 94 SETPOINTS MODE - AUTORECLOSURE selected. The PHASE INST LOSET and/or GROUND INST contact closure here will cause the CLOSE LOSET trip feature can also be blocked after any reclosure output relay to activate for as long as the input as selected. remains shorted.
  • Page 95 SETPOINTS MODE - AUTORECLOSURE Location Message Line Description S 12.1 The setpoints page 12 header. All the setpoints required for Auto Reclosure SETPOINTS are entered in this page. AUTO RECLOSURE S 12.2 This setpoint determines whether the reclosure scheme is enabled or AUTO RECLOSURE disabled when LOCAL mode is selected.
  • Page 96 SETPOINTS MODE - AUTORECLOSURE Location Message Line Description S 12.10 Last line of Setpoints, page 12, autoreclosure. Use the PAGE key to view AUTO RECLOSURE page 13. END OF PAGE 5-52...
  • Page 97 SETPOINTS MODE - PHASE CURVES Location Message Line Description S 13.1 The setpoints page 13 header. Setpoints required to program an alternate SETPOINTS phase curve are entered here. PHASE CURVES S 13.2 This will enable the changing of the phase curve when enabled. PHASE CURVE CHANGE DISABLED...
  • Page 98 SETPOINTS MODE - GROUND CURVES Location Message Line Description S 14.1 The setpoints page 14 header. Setpoints required to program an alternate SETPOINTS ground curve are entered here. GROUND CURVES S 14.2 This will enable the changing of the ground curve. GROUND CURVE CHANGE DISABLED...

  • Page 99: Section 7: Feature Information

    Event Recording and Event Printing features. All events will be stored in a memory buffer of the 565 unit, and up to 40 events will accumulated. The buffer is operated in First-In-First-Out (FIFO) mode. If the buffer is full with 40 stored events, then as each new event occurs the (1.0) “Event”...
  • Page 100 FEATURE INFORMATION Cause of Event Displayed Message Phase A Timed O/C Trip PH-A TIME O/C Phase B Timed O/C Trip PH-B TIME O/C Phase C Timed O/C Trip PH-C TIME O/C Ground Timed O/C Trip GND TIMED O/C Phase A Inst Trip PH-A INST O/C Phase B Inst Trip PH-B INST O/C...
  • Page 101 Since there is a large variety of printers and it is - event reference number impossible to interface with all of them, the 565 feeder relays - cause of event are standardized to interface with EPSON FX-80 printers - date and time with serial input or other compatible printer.
  • Page 102 FEATURE INFORMATION The following lists all “Cause of Event” printout messages: Cause of Event Printout Message Phase A Timed Overcurrent Trip Phase A Timed O/C Trip Phase B Timed Overcurrent Trip Phase B Timed O/C Trip Phase C Timed Overcurrent Trip Phase C Timed O/C Trip Ground Timed Overcurrent Trip...
  • Page 103 FEATURE INFORMATION 29) Power Factor Alarm Power Factor Alarm 30) Frequency Alarm Frequency Alarm 31) Breaker Discrepancy Alarm Breaker Discrep. Alarm 32) Trip Coil Alarm Trip Coil Alarm 33) MTM Communications Alarm MTM Comm. Alarm 34) Phase Overcurrent Alarm Condition Reset Phase O/C Alarm Reset 35) Ground Overcurrent Alarm Condition Reset...

  • Page 104: Aeg Modicon Modbus Protocol

    One data frame of an asynchronous transmission to or from ues or setpoints, sent by the master to the slave or by the a 565 Feeder Management Relay consists of 1 star t bit, 8 slave to the master. data bits, and 1 stop bit. This produces a 10 bit data frame.
  • Page 105 (ie. all slaves start listening for a new transmission from the If a 565 Feeder Management Relay Modbus slave device master). Thus at 9600 baud a delay of greater than 3.5 × 1/ receives a transmission in which an error is indicated by the 9600 ×...
  • Page 106 ADDRESS FUNCTION START SETPOINT Operation CODE ADDRESS COUNT This function code allows the master to request the 565 Slave Response: Feeder Management Relay to perform specific operations. The operations that can be performed by the 565 Feeder HI LO HI LO...
  • Page 107 Modbus “registers” are 16 bit (two byte) values transmitted high order byte first. But all 565 Feeder Management Relay Message Format and Example setpoints are not made of two bytes. Some of them are four...
  • Page 108 02 - ILLEGAL DATA ADDRESS The address referenced in the data field transmitted by the master is not an allowable address for the 565 Feeder Management Relay, or requested number of registers does not match total length of referenced internal registers.
  • Page 109 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 0000 0000 PRODUCT I.D. MULTILIN PRODUCT DEVICE CODE 18 or 58 18 (565), 58 (575)
  • Page 110 PHASE TIMED O/C PICKUP 25 - 250 1.00 0261 0105 PHASE O/C CURVE SHAPE (565) or PH. O/C CURVE 1 SHAPE (575) 0 - 7 0263 0107 PHASE O/C TIME DIAL (565) or PHASE O/C TIME DIAL 1 (575) 1 - 32 1.00...
  • Page 111 GND INST TRIP LEVEL (565) or GND HISET INST TRIP LEVEL (575) 1.0 - 7.0 X P/U 0.10 0325 0145 GND INST TRIP 2 LEVEL (565) or GND HISET INST TRIP2 LEVEL (575 1.0 - 18.0 X P/U 0.10 0313 0139...
  • Page 112 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 0331 014B (565 Only) EXTERNAL TRIP #3 DELAY 0 - 60 1.00 0380 017C (575 Only)
  • Page 113 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 0444 01BC SWITCH NUMBER 4 STATUS 0 or 1 0471 01D7 SWITCH NUMBER 5 STATUS...
  • Page 114 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 0531 0213 KVAR DEMAND TIME PERIOD 5 - 120 1.00 0532 0214 KVAR DEMAND ALARM...
  • Page 115 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 1009 03F1 1.9 x PU = 0.1 - 1092.2 0.10 1010 03F2 2.0 x PU = 0.1 - 1092.2...
  • Page 116 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 1099 044B RESERVED 1100 044C CUSTOM GROUND 1.03 x PU = 0.1 - 1092.2 0.10...
  • Page 117 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 1171 0493 16.5 x PU = 0.1 - 1092.2 0.10 1172 0494 17.0 x PU = 0.1 - 1092.2...
  • Page 118 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 1261 04ED (575 Only) 11.5 x PU = 0.1 - 1092.2 0.10 1262 04EE (575 Only) 12.0 x PU =...
  • Page 119 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 1351 0547 (575 Only) 6.5 x PU = 0.1 - 1092.2 0.10 1352 0548 (575 Only) 7.0 x PU =...
  • Page 120 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 1815 0717 EVENT RECORD 14 1816 0718 EVENT RECORD 15 1835 072B EVENT RECORD 15...
  • Page 121 FEATURE INFORMATION 565/575 MEMORY MAP (REVISION E2.73) ADDRESS GROUP DESCRIPTION RANGE STEP UNITS SCALE FORMAT FACTORY (DEC) (HEX) CODE DEFAULT Actual Values - READ ONLY 2295 08F7 EVENT RECORD 38 2296 08F8 EVENT RECORD 39 2315 090B EVENT RECORD 39...
  • Page 122 16 bits 565/575 TRIP STATUS 0000 0000 0000 0000 (BIN) or 0000 (HEX) 0 (DEC) = 565/575 Not Tripped Since Last Reset 0000 0000 0000 0001 (BIN) or 0001 (HEX) 1 (DEC) = 565/575 Tripped Since Last Reset 16 bits...
  • Page 123 1.342 EXP 08 (DEC) = Ground Timed O/C 10 00 00 00 (HEX) 2.684 EXP 08 (DEC) = Phase A Inst. O/C (565), Phase A Hiset Overcurrent (575) 20 00 00 00 (HEX) 5.369 EXP 08 (DEC) = Phase B Inst. O/C (565), Phase B Hiset Overcurrent (575) 40 00 00 00 (HEX) 1.074 EXP 09 (DEC) = Phase C Inst.
  • Page 124 0000 0000 0000 0011 (BIN) or 0003 (HEX) 03 (DEC) = Extremely Inverse 0000 0000 0000 0100 (BIN) or 0004 (HEX) 04 (DEC) = Custom (565), Custom 1 or Custom 2 (575) 0000 0000 0000 0101 (BIN) or 0005 (HEX) 05 (DEC) = IEC A...
  • Page 125 0000 0000 0000 0011 (BIN) or 0003 (HEX) 03 (DEC) = Aux 3 0000 0000 0000 0100 (BIN) or 0004 (HEX) 04 (DEC) = All (565), Aux 4 (575) 0000 0000 0000 0101 (BIN) or 0005 (HEX) 05 (DEC) = Block Tap Change (575)
  • Page 126 (*) = Only Those Events Marked With An Asterisk Will Have Their Current And Voltage Parameters Recorded. (*) Phase A Timed Overcurrent Trip (565, 575) (*) Phase B Timed Overcurrent Trip (565, 575) (*) Phase C Timed Overcurrent Trip (565, 575)
  • Page 127 External Trip (575) Reclosable Trip (575) Programmable Trip (575) Power Factor Trip (565, 575) Frequency Trip (565, 575) Voltage Phase Reversal Trip (565, 575) Phase Overcurrent Alarm (565, 575) Ground Overcurrent Alarm (565, 575) Overvoltage Alarm (565, 575) Undervoltage Alarm (565, 575)

  • Page 128: Metering Specification - 565 With Mtm

    TRIP , AUX 1, 2, TRIP & AUX1, TRIP & AUX2, • Megawatthours (MWhr) AUX 1&2, and TRIP & AUX 1&2. Default AUX Various alarms and trip levels are set in the 565 for the above parameters as required. Frequency...
  • Page 129 Accuracy is ±2% of displayed. Resolution display is 1 kVAR. This measures average reactive power demanded over time. This value is supplied by the MTM but averaged by the 565. Signed Real and Reactive Power Readings Setpoints: If the 565/575 is communicating with a revision E MTM or MTM Plus, the kW and kvar readings sent to the 565/575 will Time period 5-120 min, in steps of 1 min.
  • Page 130 RECORD 1Ch — 81Ch 10h (*) Ground loset instantaneous trip RECORD 09h — 6A0h RECORD 1Dh — 830h 11h (*) Overvoltage trip 565/575 RECORD 0Ah — 6B4h RECORD 1Eh — 844h 12h (*) Undervoltage trip 565/575 RECORD 0Bh — 6C8h RECORD 1Fh —...
  • Page 131 FEATURE INFORMATION EVENT NO DESCRIPTION APPLICABLE TO Reclosure #3 Reclosure #4 Reclosure lockout Reclosure scheme reset Serial communication trip 565/575 Serial communication close 565/575 6-32...

  • Page 133: Overcurrent Protection

    If a pickup level of 150% is selected with a maxi- 5. IEC A mum of 20 times pickup then 150A will be flowing into the 565 6. IEC B relay. Therefore, an instantaneous trip must be selected for 7.
  • Page 134 CURVE INFORMATION AND TABLES NORMALLY INVERSE (PHASE) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.1 Normal Inverse Time/Phase Overcurrent Curves...
  • Page 135 CURVE INFORMATION AND TABLES MODERATELY INVERSE (PHASE) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.2 Moderately Inverse Time/Phase Overcurrent Curves...
  • Page 136 CURVE INFORMATION AND TABLES VERY INVERSE (PHASE) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.3 Very Inverse Time/Phase Overcurrent Curves...
  • Page 137 CURVE INFORMATION AND TABLES EXTREMELY INVERSE (PHASE) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.4 Extremely Inverse Time/Phase Overcurrent Curves...
  • Page 138 CURVE INFORMATION AND TABLES NORMALLY INVERSE (GROUND) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.5 Normal Inverse Time/Ground Overcurrent Curves...
  • Page 139 CURVE INFORMATION AND TABLES MODERATELY INVERSE (GROUND) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.6 Moderately Inverse Time/Ground Overcurrent Curves...
  • Page 140 CURVE INFORMATION AND TABLES VERY INVERSE (GROUND) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.7 Very Inverse Time/Ground Overcurrent Curves...
  • Page 141 CURVE INFORMATION AND TABLES EXTREMELY INVERSE (GROUND) 1000 TIME DIAL 0.01 MULTIPLE OF PICKUP CURRENT (PER UNIT) Figure 7.8 Extremely Inverse Time/Ground Overcurrent Curves...
  • Page 142 CURVE INFORMATION AND TABLES Figure 7.9 IEC A Curves 7-10...
  • Page 143 CURVE INFORMATION AND TABLES Figure 7.10 IEC B Curves 7-11...
  • Page 144 CURVE INFORMATION AND TABLES Figure 7.11 IEC C Curves 7-12...
  • Page 145 Number of trips per 65,535 cycles Pickup Current Theoretical Trip Time 13.5 × Since only integer numbers can be stored in the 565 look up Multiplier IEC B: − Actual Current tables, this value must be rounded off. Working backwards...
  • Page 146 CURVE INFORMATION AND TABLES multiplier in the formula and the selected time dial is as follows: Time Dial Multiplier = The additional overcurrent curve shapes are selectable with Modbus protocol communications. The following memory map registers reflect this change. Address Dec Hex Chapter Page...

  • Page 147: Curve: Normal Inverse

    CURVE INFORMATION AND TABLES Curve: Normal Inverse Curve#: × P/U Time to trip (seconds) 1.03 7.692 22.291 37.664 52.012 68.266 84.019 99.295 109.225 121.361 136.531 156.036 182.042 182.042 218.450 218.450 218.450 1.10 2.334 6.827 11.260 15.830 20.227 24.824 29.520 34.133 37.664 42.010 47.489 52.012 57.487 60.681 64.250 68.266 1.20 1.185 3.467...
  • Page 148 CURVE INFORMATION AND TABLES Curve: Normal Inverse Curve#: × P/U Time to trip (seconds) 9.50 0.061 0.178 0.295 0.413 0.530 0.647 0.764 0.882 0.998 1.116 1.233 1.350 1.468 1.585 1.701 1.820 10.00 0.059 0.174 0.288 0.402 0.517 0.631 0.746 0.860 0.974 1.088 1.203...
  • Page 149 CURVE INFORMATION AND TABLES Curve: Normal Inverse Curve#: × P/U Time to trip (seconds) 1.03 273.063 273.063 273.063 273.063 273.063 364.083 364.083 364.083 364.083 364.083 364.083 364.083 364.083 546.125 546.125 546.125 1.10 72.817 78.018 84.019 91.021 91.021 99.295 99.295 109.225 109.225 109.225 121.361 121.361 121.361 136.531 136.531 136.531 1.20 37.664 40.454 42.010 43.690 47.489 49.648 52.012 54.613 54.613 57.487 60.681 64.250 64.250 68.266 68.266 72.817 1.30...
  • Page 150 2.952 3.051 15.50 1.581 1.675 1.773 1.867 1.964 2.061 2.154 2.252 2.344 2.444 2.540 2.632 2.731 2.822 2.920 3.017 16.00 1.565 1.657 1.753 1.848 1.944 2.038 2.133 2.225 2.319 2.416 2.511 2.607 2.697 2.793 2.890 2.984 16.50 1.547 1.642 1.736 1.830...
  • Page 151 1.063 1.237 1.413 1.588 1.762 1.937 2.113 2.285 2.460 2.638 2.815 5.00 0.184 0.357 0.529 0.702 0.874 1.047 1.219 1.391 1.565 1.736 1.910 2.080 2.257 2.427 2.601 2.772 5.10 0.182 0.352 0.522 0.693 0.863 1.032 1.203 1.374 1.543 1.715 1.883 2.053...
  • Page 152 CURVE INFORMATION AND TABLES Curve: Moderately Inverse Curve#: × P/U Time to trip (seconds) 13.00 0.114 0.220 0.326 0.432 0.539 0.645 0.751 0.857 0.963 1.070 1.176 1.282 1.388 1.494 1.602 1.707 13.50 0.112 0.217 0.322 0.427 0.532 0.637 0.742 0.846 0.951 1.056 1.161...
  • Page 153 CURVE INFORMATION AND TABLES Curve: Moderately Inverse Curve#: × P/U Time to trip (seconds) 1.03 33.098 34.133 36.408 39.009 40.454 42.010 43.690 45.510 47.489 49.648 52.012 54.613 54.613 57.487 60.681 60.681 1.10 25.401 26.640 28.006 29.520 31.207 33.098 34.133 35.234 37.664 39.009 40.454 42.010 43.690 45.510 45.510 47.489 1.20 19.504 20.608 21.417 22.755 23.745 24.824 26.006 27.306 28.743 29.520 30.340 32.125 33.098 34.133 35.234 36.408 1.30...
  • Page 154 CURVE INFORMATION AND TABLES Curve: Moderately Inverse Curve#: × P/U Time to trip (seconds) 13.00 1.814 1.920 2.026 2.133 2.238 2.344 2.449 2.558 2.664 2.772 2.874 2.984 3.085 3.194 3.300 3.403 13.50 1.791 1.896 2.000 2.105 2.211 2.314 2.422 2.523 2.632 2.731 2.837...
  • Page 155 CURVE INFORMATION AND TABLES Curve: Very Inverse Curve#: × P/U Time to trip (seconds) 1.03 4.422 11.497 18.513 25.401 33.098 40.454 47.489 54.613 60.681 68.266 72.817 84.019 91.021 99.295 99.295 109.225 1.10 1.340 3.490 5.630 7.802 9.930 12.136 14.185 16.302 18.513 20.608 22.755 24.824 27.306 29.520 31.207 33.098 1.20 0.680 1.770...
  • Page 156 CURVE INFORMATION AND TABLES Curve: Very Inverse Curve#: × P/U Time to trip (seconds) 13.00 0.031 0.081 0.131 0.180 0.230 0.280 0.330 0.379 0.429 0.479 0.529 0.578 0.628 0.678 0.728 0.777 13.50 0.031 0.080 0.129 0.178 0.227 0.276 0.325 0.374 0.423 0.472 0.521...
  • Page 157 CURVE INFORMATION AND TABLES Curve: Very Inverse Curve#: × P/U Time to trip (seconds) 1.03 121.361 121.361 136.531 136.531 156.036 156.036 156.036 156.036 182.042 182.042 182.042 182.042 218.450 218.450 218.450 218.450 1.10 35.234 37.664 40.454 42.010 43.690 45.510 49.648 49.648 52.012 54.613 57.487 60.681 60.681 64.250 64.250 68.266 1.20 18.204 19.162 20.227 21.417 22.291 23.745 24.824 26.006 26.640 28.006 28.743 30.340 31.207 32.125 33.098 34.133 1.30...
  • Page 158 CURVE INFORMATION AND TABLES Curve: Very Inverse Curve#: × P/U Time to trip (seconds) 13.00 0.827 0.877 0.926 0.976 1.027 1.076 1.126 1.176 1.224 1.275 1.324 1.374 1.424 1.474 1.523 1.574 13.50 0.815 0.864 0.913 0.962 1.011 1.060 1.110 1.158 1.208 1.257 1.307...
  • Page 159 1.199 1.348 1.500 1.650 1.799 1.950 2.100 2.252 2.401 2.552 4.10 0.282 0.425 0.567 0.710 0.853 0.996 1.138 1.280 1.424 1.565 1.709 1.851 1.993 2.137 2.280 2.422 4.20 0.268 0.404 0.539 0.675 0.811 0.946 1.081 1.218 1.353 1.488 1.623 1.759 1.896...
  • Page 160 CURVE INFORMATION AND TABLES Curve: Extremely Inverse Curve#: × P/U Time to trip (seconds) 13.00 0.043 0.064 0.086 0.108 0.129 0.151 0.172 0.194 0.216 0.237 0.259 0.280 0.302 0.324 0.345 0.367 13.50 0.041 0.062 0.083 0.103 0.124 0.145 0.166 0.187 0.207 0.228 0.249...
  • Page 161 CURVE INFORMATION AND TABLES Curve: Extremely Inverse Curve#: × P/U Time to trip (seconds) 1.03 109.225 121.361 121.361 121.361 136.531 136.531 156.036 156.036 156.036 156.036 182.042 182.042 182.042 182.042 182.042 218.450 1.10 84.019 91.021 99.295 99.295 109.225 109.225 109.225 121.361 121.361 121.361 136.531 136.531 136.531 156.036 156.036 156.036 1.20 64.250 68.266 68.266 72.817 78.018 78.018 84.019 91.021 91.021 91.021 99.295 99.295 109.225 109.225 109.225 121.361 1.30...
  • Page 162 CURVE INFORMATION AND TABLES Curve: Extremely Inverse Curve#: × P/U Time to trip (seconds) 13.00 0.389 0.410 0.432 0.453 0.475 0.496 0.518 0.540 0.561 0.583 0.604 0.626 0.648 0.669 0.691 0.712 13.50 0.374 0.394 0.415 0.436 0.457 0.478 0.498 0.519 0.540 0.561 0.582...
  • Page 163 4.749 3.30 0.290 0.579 0.869 1.158 1.449 1.739 2.026 2.319 2.607 2.897 3.184 3.479 3.766 4.060 4.352 4.628 3.40 0.283 0.565 0.847 1.130 1.413 1.696 1.979 2.261 2.540 2.822 3.112 3.392 3.678 3.957 4.234 4.513 3.50 0.276 0.552 0.827 1.103 1.379...
  • Page 164 CURVE INFORMATION AND TABLES Curve: IEC A Curve #: x P/U Time to trip (seconds) 13.00 0.133 0.266 0.399 0.532 0.665 0.798 0.931 1.064 1.196 1.330 1.462 1.597 1.728 1.861 1.993 2.129 13.50 0.131 0.262 0.393 0.524 0.655 0.786 0.917 1.048 1.180 1.310...
  • Page 165 CURVE INFORMATION AND TABLES Curve: IEC A Curve #: x P/U Time to Trip (seconds) 1.03 218.450 218.450 218.450 218.450 273.063 273.063 273.063 273.063 273.063 273.063 364.083 364.083 364.083 364.083 364.083 364.083 1.10 60.681 64.250 68.266 72.817 78.018 78.018 84.019 91.021 91.021 99.295 99.295 99.295 109.225 109.225 109.225 121.361 1.20 32.125 34.133 36.408 37.664 40.454 42.010 43.690 45.510 47.489 49.648 52.012 54.613 54.613 57.487 60.681 60.681 1.30...
  • Page 166 CURVE INFORMATION AND TABLES Curve: IEC A Curve #: x P/U Time to Trip (seconds) 13.50 2.229 2.359 2.488 2.619 2.751 2.882 3.017 3.148 3.280 3.403 3.535 3.665 3.806 3.929 4.060 4.185 14.00 2.198 2.324 2.454 2.582 2.710 2.844 2.968 3.103 3.232 3.361...
  • Page 167 CURVE INFORMATION AND TABLES Curve: IEC B Curve #: x P/U Time to Trip (seconds) 1.03 22.291 45.510 68.266 91.021 109.225 136.531 156.036 182.042 218.450 218.450 273.063 273.063 273.063 364.083 364.083 364.083 1.10 6.742 13.485 20.227 27.306 34.133 40.454 47.489 54.613 60.681 68.266 72.817 84.019 91.021 91.021 99.295 109.225 1.20 3.371 6.742 10.113 13.485 16.804 20.227 23.745 27.306 30.340 34.133 37.664 40.454 43.690 47.489 49.648 54.613...
  • Page 168 CURVE INFORMATION AND TABLES Curve: IEC B Curve #: x P/U Time to Trip (seconds) 13.50 0.054 0.108 0.162 0.216 0.270 0.324 0.378 0.432 0.486 0.540 0.594 0.648 0.702 0.756 0.810 0.864 14.00 0.052 0.104 0.156 0.208 0.260 0.312 0.363 0.415 0.467 0.519...
  • Page 169 CURVE INFORMATION AND TABLES Curve: IEC B Curve #: x P/U Time to Trip (seconds) 1.03 364.083 364.083 364.083 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 1.10 109.225 121.361 121.361 136.531 136.531 156.036 156.036 156.036 182.042 182.042 182.042 182.042 182.042 218.450 218.450 218.450 1.20 57.487 60.681 64.250 68.266 72.817 72.817 78.018 84.019 84.019 91.021 91.021 91.021 99.295 99.295 109.225 109.225 1.30...
  • Page 170 CURVE INFORMATION AND TABLES Curve: IEC B Curve #: x P/U Time to Trip (seconds) 13.50 0.918 0.972 1.026 1.080 1.134 1.189 1.243 1.296 1.350 1.404 1.458 1.513 1.567 1.621 1.675 1.728 14.00 0.883 0.934 0.987 1.038 1.090 1.143 1.194 1.247 1.299 1.350...
  • Page 171 1.089 1.270 1.452 1.633 1.814 1.997 2.176 2.359 2.540 2.724 2.905 4.90 0.174 0.348 0.522 0.695 0.869 1.043 1.216 1.391 1.565 1.739 1.913 2.084 2.261 2.433 2.607 2.779 5.00 0.167 0.333 0.500 0.667 0.833 1.000 1.167 1.334 1.500 1.668 1.833 2.000...
  • Page 172 CURVE INFORMATION AND TABLES Curve: IEC C Curve #: x P/U TIme to Trip (seconds) 13.50 0.022 0.044 0.066 0.088 0.110 0.132 0.154 0.177 0.199 0.221 0.243 0.265 0.287 0.309 0.331 0.353 14.00 0.021 0.041 0.062 0.082 0.103 0.123 0.144 0.164 0.185 0.205...
  • Page 173 CURVE INFORMATION AND TABLES Curve: IEC C Curve #: x P/U Time to Trip (seconds) 1.03 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1092.250 1.10 364.083 364.083 364.083 364.083 364.083 364.083 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 546.125 1.20 156.036 156.036 182.042 182.042 182.042 218.450 218.450 218.450 218.450 218.450 273.063 273.063 273.063 273.063 273.063 273.063 1.30...
  • Page 174 CURVE INFORMATION AND TABLES Curve: IEC C Curve #: x P/U Time to Trip (seconds) 13.50 0.375 0.397 0.419 0.441 0.463 0.485 0.508 0.530 0.552 0.574 0.596 0.618 0.640 0.662 0.684 0.706 14.00 0.349 0.369 0.390 0.410 0.431 0.451 0.472 0.492 0.513 0.533...

  • Page 175: Section 8: Relay Testing

    Enter 0 for this setpoint. Press these test procedures. Note that these tests cannot be STORE to store the setpoint in the 565/575 Memory. Verify performed unless the correct access code is entered in page that INST is displayed by message S 2.13.
  • Page 176 RELAY TESTING Figure 8.1 Secondary Injection Test Setup...

  • Page 177: Ground Current Input Function Check

    Ground protection is tested by injecting a current at terminals check the time indicated on the test set timer. Refer to the 55 and 56 of the 565/575 Relay to simulate ground overcur- ground curve in use in Appendix D of this manual. Verify that rent conditions.

  • Page 178: Voltage Input Function Check

    Put the 565/575 Relay in Actual values when the relay normally open contacts close. Note that the mode, and read the phase voltage from messages A 6.2 to...

  • Page 179: Power Loss Check

    When the trip relay or other assigned relay is activated and the associated LED illumi- nated, remove all power and current from the 565/575 Relay. Leave it in this condition for a short time, say one minute.

  • Page 181: Section 9: Technical Specifications

    SPECIFICATIONS Technical Specifications Phase Overcurrent Protection: Phase Current Inputs: Timed overcurrent pickup: CT secondary: 1 Amp or 5 Amp. Range 25%-250% of CT in steps of 1%. Saturation: 20 Times CT. Time dial: 32 selections. CT primary: 10-5000 Amp in 5 Amp steps. Instantaneous overcurrent pickup: CT burden: Less than 0.2 VA per phase at 100% of CT.
  • Page 182 Storage Temperature: -30°C to +80°C -30°C to +80°C NOTE: At extremely low temperatures (below -20°C), the 565/575 LCD display exhibits very slow responses to alphanumeric changes. At high temperatures (60°C and above) the LCD display darkens, making it difficult to view displayed messages which indicate the relay’s status.

  • Page 183: Appendix A Customer Service

    For customer service and assistance contact your nearest MULTILIN agent or one of the MULTILIN offices listed below quoting the appropriate part number and the 565/575 Relay serial and revision number. Before shipping any parts either as part of a warranty claim or which have been damaged in transit, contact the nearest regional office or Multilin office to obtain a Return Authorization number (RA).

  • Page 185: Appendix B Troubleshooting Guide

    If all tests fail to isolate the fault, contact Multilin customer support. Note that before doing The 565/575 Relay is fully tested before leaving the factory. any tests, the access jumper (or keyswitch if installed) must...
  • Page 186 APPENDIX B MALFUNCTION ACTION REFERENCE 2. Check that the correct voltage transformer sens- Setpoints page 9 and relay ing system, secondary voltage and VT feeder wiring diagram. primary voltage have been entered in setpoints. Verify that all the voltage sensing wiring is correct. 3.
  • Page 187 APPENDIX B MALFUNCTION ACTION REFERENCE 3. Read the phase instantaneous trip delay and Setpoints page 2. verify that the overcurrent condition is present for longer than this time. 4. Ensure that the trip relay wiring to the breaker is Relay wiring diagram. correct at terminals 41 and 57.
  • Page 188 APPENDIX B MALFUNCTION ACTION REFERENCE 2. Check the ground fault instantaneous trip level Setpoints page 3. setpoint and verify that the current is exceeding this level. 3. Read the ground fault instantaneous trip delay Setpoints page 3. and verify that the overcurrent condition is present for longer than this time.
  • Page 189 20. Poor Open Delta voltage 1. Check and verify the secondary voltages meas- readings. ured at 565/575 terminals 35, 36, 37 and 38. 2. Check the wiring. See the following table for com- monly made errors. The correct nominal voltage in each example should be 4.16 kV.
  • Page 190 3. Check breaker position. Due to applications where the potential transformers are located on the local side of the breaker, the 565/575 must see the breaker closed at terminals 9, 10, and 11 before issuing an undervoltage trip. This prevents the relay from issuing an undervoltage trip each time the breaker is opened.

  • Page 191: Block Diagrams

    APPENDIX C Block Diagrams The figures on the following pages show the 565/575 Relay hardware block diagrams. The following shows the name and contents of each figures: Figure Contents System controller block diagram, part 1/2. System controller block diagram, part 2/2.
  • Page 192 APPENDIX C Figure C1. System Controller Block Diagram (1/2)
  • Page 193 APPENDIX C Figure C2. System Controller Block Diagram (2/2)
  • Page 195 565/575 Relay Typical Wiring ........................... 2-8 Figure 2.6 Voltage Sensing Wire ............................2-9 Figure 2.7A 565/575 with MTM CT and Open Delta VT Typical Wiring ................2-10 Figure 2.7B 565/575 with MTM CT and Wye VT Typical Wiring ..................2-11 Figure 2.8A Open Delta VT and CT MTM Typical Wiring ....................
  • Page 196 INTENT This manual describes the function, operation and use of the Multilin Model 565/575 Feeder Management Relays. REVISION HISTORY Manual Part No. Software Revision Release Date 1601-0017-E1 E2.2 02/26/92 1601-0017-E2 E2.3 05/28/92 1601-0017-E3 E2.4 09/17/92 1601-0017-E4 E2.4 03/28/93 (manual format changed) 1601-0017-E5 E2.4...
  • Page 197 In the event of a failure covered by warranty, GE Multilin will undertake to repair or replace the relay providing the warrantor determined that it is defective and it is returned with all transportation charges prepaid to an authorized service centre or the factory.

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